United States Air and Radiation EPA # 430-F-11-066
Environmental Protection Agency (6204J) December 2011
Documentation Supplement for EPA
Base Case v.4.10_MATS - Updates for
Final Mercury and Air Toxics Standards
(MATS) Rule
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This report is the third of three supplements to the August 2010 documentation for EPA Base Case
v.4.101. The previous two supplements presented the enhancements and updates that were made to the
Base Case for the Proposed Toxics Rule (March 2011)2 and the Cross-State Air Pollution Rule or CSAPR
(June 2011)3. The current supplement presents the enhancements and updates that were made for the
final Toxics Rule, now designated the Mercury and Air Toxics Standards (MATS).
The 3 documentation supplements are cumulative in nature. Previous documented features not
addressed here were retained in the MATS Base Case as described in the most recent previous
documentation. Figure 1 attempts to provide a graphical representation of the cumulative structure. The
March 2011 documentation supplement for the Proposed Toxics Rule is highlighted in Figure 1 because
the Base Case for MATS represents an extension of the Base Case for the Proposed Toxics Rule.
Dae v.41O
(Aug 2010}
Doc Sup -
PTOX
(March
2011)
Doc Sup —
PFTransport
[June 2O11)
DocSup —
MATS
(Dec2Oll)
Figure 1. Relationship of Current Report to Previous Documentation for EPA Base Case v.4.10 Variants
The current report consists of two parts: Part A briefly summarizes the changes found in the EPA Base
1 The formal title of the August 2010 documentation report is Documentation for EPA Base Case v.4.10
Using the Integrated Planning Model (EPA #430-R-10-010), August 2010. It is available for viewing and
downloading atwww.epa.gov/airmarkets/progsregs/epa-ipm/transport.html.
2 The formal title of the March 2011 documentation supplement is Documentation Supplement for
EPA Base Case v4.10_PTox - Updates for Proposed Toxics Rule (EPA #430-R-11 -006 ), March 2011. It
is available for viewing and downloading atwww.epa.gov/airmarkets/progsregs/epa-
ipm/docs/su ppdoc.pdf
3 The formal title of the June 2011 documentation supplement is Documentation Supplement for EPA
Base Case v.4.10_FTransport - Updates for Final Transport Rule (EPA #430-K-11 -004). June 2011. It is
available for viewing and downloading atwww.epa.gov/airmarkets/progsregs/epa-
ipm/CSAPR/docs/DocSuppv410_FTransport.pdf.
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Case v.4.10 for the MATS. To facilitate cross-references to the previous documentation reports, the topics
in Part A are covered in the same categories and in the same order as covered in the previous
documentation reports. At the end of Part A there a listing of corrections to errors in previous
documentation and enhancements to previous documentation items. The items in this section of Part A
do not represent changes in the base case itself but in the documentation describing features included in
the base case.
Part B of this report gives detailed information on these changes and takes the form of a supplement to
the previous documentation, using redline and strike-out highlights to show provisions that changed and
building upon the section numbering in the previous documentation to show where new enhancements fit
into the modeling structure.
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Part A
Summary of Key Changes
in the EPA Base Case v.4.10
for the MATS
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Power System Operations Assumptions
(Chapter 3 in previous documentation)
Cross-State Air Pollution Rule (CSAPR): Since issuing the Documentation Supplement for the
Proposed Toxics Rule in March of 2011, the EPA Administrator on July 6, 2011 signed a Notice of Final
Rulemaking for the Cross-State Air Pollution Rule (CSAPR). As a result of this regulatory action, the SO2
and NOx provisions of CSAPR were incorporated in the EPA Base Case v.4.10_MATS. Part B Cross-
Reference: For an indication of previous provisions removed and details of the representation of
CASAPR provisions in the final MATS base case (including tables of key CSAPR provisions, state
budgets, and a map of affected states), see the new redlined text in Section 3.9 in Part B.
Colorado RPS: Part B Cross-Reference: For a summary of the Colorado RPS included see the redlined
additions to Section 3.9.3 in Part B.)
Colorado Clean Air - Clean Jobs Act: Due to timing, previous versions of EPA Base Case v.4.10 did
not include this state regulation, which was enacted in April 2011. Part B Cross-Reference: For a
summary of the modeled provisions of the Colorado Clean Air- Clean Jobs Act, see the new redlined
additions to Section 3.9.4 in Part B.)
Handling of State Mercury Regulations in MATS Base and Policy Cases: State mercury regulations
(as shown in Appendix 3-2 in the Documentation Supplement for Proposed Toxics Rule) were not
modeled in the MATS base or policy cases. Part B Cross-Reference: For an explanation of reasons why
state mercury regulations were not included in the MATS base or policy cases, see the new text that
appears at the end of Section 3.9.4 ("State Specific Environmental Regulations") in Part B.
NIPSCO and TVA NSR Settlements: Between the last previously released EPA Base Case v.4.10 (for
CSAPR) and the base case for MATS, provisions of the NSR settlements with Northern Indiana Public
Service Company (NIPSCO) and Tennessee Valley Authority (TVA) were announced. See
www.epa.gov/compliance/resources/cases/civil/caa/nipsco.html and
www.epa.gov/compliance/resources/cases/civil/caa/tvacoalfired. The NIPSCO settlement and the
system-wide TVA SO2 limit, which were not previously included, are now represented in the Base Case
v.4.10_MATS. Part B Cross-Reference: Fora summary of the modeled provisions of the NIPSCO and
TVA NSR settlements see the appropriate entries in the updated version of Appendix 3-3 ("New Source
Review (NSR) Settlements in EPA Base Case v.4.10_MATS.
Handling of Existing ACI Controls in MATS Base and Policy Cases: Certain existing ACI controls
(shown in the NEEDS database) were not included in EPA Base Case v.4.10_MATS but were included in
the MATS policy case. Part B Cross-Reference: For an explanation of reasons and a listing of existing
ACI controls that were not included in the MATS Base Case but were included in the MATS policy case
see new sub-section 3.9.7 ("Unit-Level Control Assumptions") and 3.9.7.1 ("Existing ACI Controls in
MATS Base and Policy Cases") in Part B.
Unit-Specific Assumptions on Emissions. Emission Controls, and Fuels:
Unit specific assumptions were adopted for
• Big Sandy Units 1 and 2,
• Monroe Units 1 and 2
• Dunkirk Units 3 and 4,
• C R Huntley Units 7 and 8
• Coal Units in Washington State, including the retirements at
- Centralia
- Boardman
• D B Wilson plant
• Revised coal assignments at various plants to improve consistency with EIA Form 923
Part B Cross-Reference: For details of these changes, see new documentation sub-section 3.9.7 ("Unit-
Level Control, Emission and Fuel Assumptions") in Part B.
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Generation Resources
(Chapter 4 in previous documentation)
Revised Capital Cost Structure for New Nuclear Units: The capital cost for new nuclear capacity was
updated to $5,000/kWfrom $4,621 (in 2007$). The life extension costs for existing nuclear units were
revised to be consistent with the new nuclear plant capital costs.
Part B Cross-Reference: The changes noted here are shown in Table 4-13 in Part B.
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Emission Control Technologies
(Chapter 5 in previous documentation)
Filterable Particulate Matter (PM) Compliance Technologies for Existing Units: In the MATS policy
case all coal units with a capacity greater than 25 MW must meet the filterable PM compliance
requirement. Units that have an existing fabric filter are assumed to meet the requirement. Depending on
the incremental filterable PM reduction needed to bring a unit into compliance, uncontrolled units and
units with electrostatic precipitators (ESPs) for PM control that do not currently meet their compliance
requirement are assigned either a fabric filter or one of three tiered ESP upgrades to bring them into
compliance. The determination of the appropriate option is an off-line calculation and the assignment of
that option is performed in setting up a run, not in the course of the run. Part B Cross-Reference: See
new section 5.6 for details of the procedure used to determine the appropriate compliance technology.
Updated FGD Removal Rate Assumptions for Petroleum Coke: Based on the performance
capabilities indicated in the 2010 ICR, a 93% mercury removal rate is assumed when FGD is present on
units that burn petroleum coke. Part B Cross-Reference: The previous sentence should be appended as
a note under Table 5-13 ("Mercury Emission Modification Factors Used in EPA Base Case
v.4.10_MATS") in section 5.4.3 ("Mercury Control Capabilities") of the August 2010 documentation for
EPA Base Case v.4.10. (This is not reproduced in Part B.)
Revised ACI VOM Cost for Units with Certain Particulate Control Configurations: For certain
particulate control configurations the variable operating and maintenance (VOM) cost of activated carbon
injection (ACI) retrofits is assumed to be 81 percent lower due the presence of pre-existing particulate
controls. Part B Cross-Reference: See the redlined addition to section 5.4.3 ("Mercury Control
Capabilities") for the specific configurations affected by this VOM cost revision.
Revised HCI Emissions from Lignite and Subbituminous Coals Reflecting Impact of Ash
Chemistry: To account for the effect of ash chemistry on HCI emissions, the HCI content of lignite and
subbituminous coals is reduced by 75%. Part B Cross-Reference: For a fuller explanation of these
changes see additional redlined text at end of Section 5.5.1 ("Chlorine Content of Fuels") in Part B
FGD Upgrade Assumptions in MATS Policy Case: In setting up the MATS policy runs, it is assumed
that the most cost effective approach for units with pre-existing FGD that do not meet the 94% HCI
removal requirement is to upgrade their FGD to bring the unit into compliance. Part B Cross-Reference:
For the specifics of the FGD upgrade see the new redlined text in Section 5.5.3.1 ("Wet and Dry FGD") in
PartB.
Dry Scrubber Removal Assumptions for Waste Coal and Petroleum Coke Units in MATS Policy
Case: In setting up the Base Case v.4.10_MATS, waste coal and petroleum coke fired FBC units without
an existing FGD were mistakenly not provided with a scrubber retrofit option. To make up for this
oversight, in run year 2015 a dry scrubber and its associated capital cost (applied through and FOM
adder) are assigned to these units when setting up the MATS policy case. Part B Cross-Reference: For
further details on these revisions see new redlined text in Section 5.5.3.1 ("Wet and Dry FGD").
Revisions to DSI cost and performance assumptions in the Base Case for MATS: A number of
additional assumptions were made regarding DSI in the Base Case v.4.10_MATS. Part B Cross-
Reference: : See the redlined addition to section 5.5.3.2 ("Dry Sorbent Injection") in Part 2 for a
discussion of the specific assumptions.
Assumed Air-to-Cloth Ratio in the Cost Equations for the DSI + Fabric Filter Retrofit Option: Based
on public comments and engineering assessments, an air-to-cloth ratio of 4.0, rather than 6.0, was used
in MATS to provide a conservative projection of the requirements and cost of sorbent removal. Part B
Cross-Reference: New redlined text was added to the "Capital Cost" write-up in Section 5.5.4 ("Fabric
Filter (Baghouse) Cost Development") to reflect this assumption. This addition is shown in Part B.
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Other Fuels and Fuel Emission Factor Assumptions
(Chapter 11 in previous documentation)
Correction of Error in Mercury Emission Factor (EMF) for Petroleum Coke: A previous computational
error in the mercury emission factor for petroleum coke as presented in Table 6-3 of the EPA report titled
Control of Mercury Emissions from Coal-fired Electric Utility Boilers: Interim Report Including Errata, 3-21-
02 was corrected (from 23.18 Ibs/TBtu to 2.66 Ib/TBtu) based on re-examination of the 1999 ICR data for
petroleum coke and implementation of a procedure for flagging and excluding outlier values above the 95
percentile value. Part B Cross-Reference: This correction is reflected in the update of Table 11-4 that
appears in Part B.
Mercury Removal Assumption for Waste Coal Units: Based on 2010 ICR data waste coal units in the
Base Case for MATS were assumed to achieve 99% mercury removal. Part B Cross-Reference: This
revision is reflected in new footnote under Table 11 -4 that appears in Part B.
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Errata and Enhancements of Previous Documentation
Below is a listing of corrections to errors in previous documentation and enhancements to previous
documentation items. The items below do not represent changes in the base case itself but in the
documentation describing features included in the base case.
SCR Cost Equations: The following editorial corrections should be made to the Sargent & Lundy paper,
SCR Cost Development Methodology (atwww.epa.gov/airmarkets/progsregs/epa-
ipm/docs/v410/Appendix52A.pdf:
a) on pages 5 and 6, change the formula text for "NOx Removal Factor" (L) to: K/80
b) on page 6, add the following formula text for "Variable O&M costs for catalyst replacement &
disposal" (VOMW):
VOMW ($/MWh) = 0.3*(G)A2.9*(L)A0.71/8760/J*100*S
Fabric Filter (FF) Costs Include Ash Handling: The following clarifying text should be added to the
Sargent & Lundy paper, Particulate Control Cost Development Methodology (at
www.epa.gov/airmarkets/progsregs/epa-ipm/docs/append5 5.pdf):
a) on page 4, to the list of capital cost items included, add: "interconnecting piping, etc, to existing fly
ash handling system"
SNCR Removal Rates in Table 5-7: The removal rates in the last column of Table 5-7 did not correctly
reflect the implementation in EPA Base Case v.4.10_MATS. Table 5-7 ("Summary of Retrofit NOx
Emission Control Performance Assumptions") is located in section 5.2 ("Nitrogen Oxides Control
Technology") of the previous documentation. Part B Cross-Reference: Using redline and strike-out
highlights, the corrections to Table 5-7 are shown in Part B.
ACI Cost Equations: The following editorial corrections should be made to the Sargent & Lundy paper,
Mercury Control Cost Development Methodology (at www.epa.gov/airmarkets/progsregs/epa-
ipm/docs/append5_3.pdf):
a) on pages 12-16 change the formula text for capital cost component "BMB" to:
if(J = Not Added then 0, J = 6.0 Air-to-Cloth then 422, J = 4.0 Air-to-Cloth then 476)*B*LA0.81
10
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PartB
Detailed Information on Changes in
EPA Base Case v.4.10_MATS
(Using Mark-Up of Previous Documentation
Reports)
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Chapter 3: Power System Operation Assumptions
3.9 Existing Environmental Regulations
This section describes the existing federal, regional, and state SO2, NOX, mercury, and CO2 emissions
regulations that are represented in the EPA Base Case v.4.10_MATS. The first three subsections
discuss national and regional regulations. The next two subsections describe state level environmental
regulations and a variety of legal settlements. The last subsection presents emission assumptions for
potential units.
Note on Clean Air Interstate Rule (CAIR): In December 2008 the U.S. Court of Appeals for the District
of Columbia Circuit remanded CAIR to EPA to correct legal flaws in the proposed regulations as cited in
the Court's July 2008 ruling. Until EPA's work was completed, CAIR, which includes a cap-and-trade
system for SO2 and NOX emissions, was temporarily reinstated. However, although CAIR's provisions
were still in effect when EPA Base Case v.4.10 was released, it is not included in the base case to allow
EPA Base Case v.4.10 to be used to analyze the regulations proposed to replace CAIR.
Note on Cross-State Air Pollution Rule (CSAPR): Since issuing the Documentation Supplement for the
Proposed Toxics Rule in March of 2011, the EPA Administrator on July 6, 2011 signed a Notice of Final
Rulemaking for the Cross-State Air Pollution Rule (CSAPR). As a result of this regulatory action, the SO2
and NOx provisions of CSAPR were incorporated in the EPA Base Case v.4.10_MATS. Below are a map
of affected states and state budget tables listing the key CSAPR provisions.
States controlled for both fine particles (annual SO? and NOx) and ozone (ozone season NOx) (21 States)
States controlled for fine particles only (annual SO2 and NOx) (2 States)
States controlled for ozone only (ozone season NOx) (5 States)
States not covered by the Cross-State Air Pollution Rule
*Thl» map IncludM otatM covered In tha •upptamantal notice of prapoMd rutamaklng.
Figure 3.1. CSAPR States
12
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Table3. 1. a) SO2
Emissions
In 1000 tons
Alabama
Georgia
Illinois
Indiana
Iowa
Kansas
Kentucky
Maryland
Michigan
Minnesota
Missouri
Nebraska
New Jersey
New York
North Carolina
Ohio
Pennsylvania
South Carolina
Tennessee
Texas
Virginia
West Virginia
Wisconsin
Budget
2012
216.033
158.527
234.889
285.424
107.085
41.528
232.662
30.12
229.303
41.981
207.466
65.052
5.574
27.325
136.881
310.23
278.651
88.62
148.15
243.954
70.82
146.174
79.48
2014
213.258
95.231
124.123
161.111
75.184
41.528
106.284
28.203
143.995
41.981
165.941
65.052
5.574
18.585
57.62
137.077
112.021
88.62
58.833
243.954
35.057
75.668
40.126
Variability Limit
2012
38.886
28.535
42.28
51.376
19.275
7.475
41.879
5.422
41.275
7.557
37.344
11.709
1.003
4.919
24.639
55.841
50.157
15.952
26.667
43.912
12.748
26.311
14.306
2014
38.386
17.142
22.342
29
13.533
7.475
19.131
5.077
25.919
7.557
29.869
11.709
1.003
3.345
10.372
24.674
20.164
15.952
10.59
43.912
6.31
13.62
7.223
Table 3.1. b) Ozone Season NOx
Emissions
In 1000 tons
Alabama
Arkansas
Florida
Georgia
Illinois
Indiana
Iowa
Kansas
Kentucky
Louisiana
Maryland
Budget
2012
31.746
15.037
27.825
27.944
21.208
46.876
16.532
13.536
36.167
13.432
7.179
2014
31.499
15.037
27.825
18.279
21.208
46.175
16.207
10.998
32.674
13.432
7.179
Variability Limit
2012
6.667
3.158
5.843
5.868
4.454
9.844
3.472
2.843
7.595
2.821
1.508
2014
6.615
3.158
5.843
3.839
4.454
9.697
3.403
2.31
6.862
2.821
1.508
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Michigan
Mississippi
Missouri
New Jersey
New York
North Carolina
Ohio
Oklahoma
Pennsylvania
South Carolina
Tennessee
Texas
Virginia
West Virginia
Wisconsin
25.752
10.16
22.762
3.382
8.331
22.168
40.063
21.835
52.201
13.909
14.908
63.043
14.452
25.283
13.704
24.727
10.16
21.073
3.382
8.331
18.455
37.792
21.835
51.912
13.909
8.016
63.043
14.452
23.291
13.216
5.408
2.134
4.78
0.71
1.75
4.655
8.413
4.585
10.962
2.921
3.131
13.239
3.035
5.309
2.878
5.193
2.134
4.425
0.71
1.75
3.876
7.936
4.585
10.902
2.921
1.683
13.239
3.035
4.891
2.775
Table 3.1. c) Annual NOx
Emissions
In 1000 tons
Alabama
Georgia
Illinois
Indiana
Iowa
Kansas
Kentucky
Maryland
Michigan
Minnesota
Missouri
Nebraska
New Jersey
New York
North Carolina
Ohio
Pennsylvania
South Carolina
Tennessee
Texas
Virginia
West Virginia
Budget
2012
72.691
62.01
47.872
109.726
38.335
30.714
85.086
16.633
60.193
29.572
52.374
26.44
7.266
17.543
50.587
92.703
119.986
32.498
35.703
133.595
33.242
59.472
2014
71.962
40.54
47.872
108.424
37.498
25.56
77.238
16.574
57.812
29.572
48.717
26.44
7.266
17.543
41.553
87.493
119.194
32.498
19.337
133.595
33.242
54.582
Variability Limit
2012
13.084
11.162
8.617
19.751
6.9
5.529
15.315
2.994
10.835
5.323
9.427
4.759
1.308
3.158
9.106
16.687
21.597
5.85
6.427
24.047
5.984
10.705
2014
12.953
7.297
8.617
19.516
6.75
4.601
13.903
2.983
10.406
5.323
8.769
4.759
1.308
3.158
7.48
15.749
21.455
5.85
3.481
24.047
5.984
9.825
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Wisconsin
31.628 30.398
5.693
5.472
"Dispatchable" Controls Operate in CSAPR Covered States: After the Clean Air Interstate Rule (CAIR)
was remanded to EPA by the Court for revision, existing emission controls for SO2 and NOx that had
been installed in anticipation of CAIR were modeled as "dispatchable." (see Documentation Supplement
for EPA Base Case v.4.10_FTransport - Updates for Final Transport Rule (EPA #430-K-11 -004). June
2011, page 54, available at www.epa.gov/airmarkets/progsregs/epa-
ipm/CSAPR/docs/DocSuppv410_FTransport.pdf.)
Since Base Case v.4.10_MATS includes CASPR, which EPA recently promulgated to replace CAIR,
"dispatchable" controls in states covered by CASPR are operated in this scenario.
Table 3.2.a) List of Units Operating "Dispatchable" FGD Retrofits in Base Case v4.10 for MATS
Plant Name
Cayuga
E W Brown
E W Brown
Ghent
Ghent
Ghent
Ghent
Elmer Smith
Elmer Smith
Paradise
Kenneth C Coleman
Kenneth C Coleman
Kenneth C Coleman
HMP&L Station Two
Henderson
HMP&L Station Two
Henderson
Dickerson
Dickerson
Dickerson
Monroe
Monroe
Monroe
Monroe
Sioux
Sioux
B L England
B L England
AES Cayuga
AES Cayuga
C R Huntley Generating Station
UniquelD
1001_B_2
1355 B 1
1355 B 2
1356_B_1
1356 B 2
1356 B 3
1356_B_4
1374_B_1
1374 B 2
1378 B 3
1381_B_C1
1381 B C2
1381 B C3
1382 B HI
1382 B H2
1572_B_1
1572_B_2
1572 B 3
1733 B 1
1733_B_2
1733 B 3
1733 B 4
2107_B_1
2107_B_2
2378 B 1
2378_B_2
2535_B_1
2535 B 2
2549 B 67
Unit ID
2
1
2
1
2
3
4
1
2
3
Cl
C2
C3
HI
H2
1
2
3
1
2
3
4
1
2
1
2
1
2
67
State Name
Indiana
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Maryland
Maryland
Maryland
Michigan
Michigan
Michigan
Michigan
Missouri
Missouri
New Jersey
New Jersey
New York
New York
New York
Capacity (MW)
473
94.0
160
475
469
478
478
132
261
977
150
150
155
153
159
182
182
182
770
785
795
775
497
497
129
155
152
153
190
15
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C R Huntley Generating Station
Dunkirk Generating Station
Dunkirk Generating Station
E C Gaston
Miami Fort
Miami Fort
Niles
Hamilton
Barry
Homer City Station
Keystone
Keystone
PPL Brunner Island
PPL Brunner Island
PPL Brunner Island
PPLMontour
PPLMontour
Hatfields Ferry Power Station
Hatfields Ferry Power Station
Hatfields Ferry Power Station
WSLee
Wateree
Wateree
Williams
W A Parish
Yorktown
Fort Martin Power Station
Fort Martin Power Station
Harrison Power Station
Harrison Power Station
Harrison Power Station
Genoa
Charles R Lowman
James H Miller Jr
Brandon Shores
Killen Station
Gibson
Gibson
2549_B_68
2554 B 3
2554 B 4
26_B_5
2832_B_7
2832 B 8
2861 B 1
2917_B_9
3 B 5
3122 B 3
3136_B_1
3136_B_2
3140 B 1
3140 B 2
3140_B_3
3149 B 1
3149 B 2
3179_B_1
3179_B_2
3179 B 3
3264 B 3
3297 B WAT1
3297 B WAT2
3298 B WIL1
3470 B WAP6
3809_B_1
3943 B 1
3943 B 2
3944_B_1
3944_B_2
3944 B 3
4143_B_1
56_B_1
6002 B 1
602 B 1
6031_B_2
6113 B 1
6113 B 2
68
3
4
5
7
8
1
9
5
3
1
2
1
2
3
1
2
1
2
3
3
WAT1
WAT2
WIL1
WAP6
1
1
2
1
2
3
1
1
1
1
2
1
2
New York
New York
New York
Alabama
Ohio
Ohio
Ohio
Ohio
Alabama
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
South
Carolina
South
Carolina
South
Carolina
South
Carolina
Texas
Virginia
West Virginia
West Virginia
West Virginia
West Virginia
West Virginia
Wisconsin
Alabama
Alabama
Maryland
Ohio
Indiana
Indiana
190
185
185
861
500
500
109
51.0
750
650
850
850
335
387
754
761
757
530
530
530
170
350
350
615
650
159
552
555
652
642
651
356
86.0
684
643
615
630
628
16
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Gibson
Fayette Power Project
Fayette Power Project
Gorgas
Gorgas
Gorgas
Cheswick
Coffeen
Coffeen
Havana
Harding Street
Petersburg
6113_B_3
6179 B 1
6179 B 2
8_B_10
8_B_8
8 B 9
8226 B 1
861_B_01
861 B 02
891 B 9
990_B_70
994_B_3
3
1
2
10
8
9
1
01
02
9
70
3
Indiana
Texas
Texas
Alabama
Alabama
Alabama
Pennsylvania
Illinois
Illinois
Illinois
Indiana
Indiana
628
598
598
690
165
175
580
340
560
487
435
540
Table 3.2.b) List of Units Operating "Dispatchable" SCR Retrofits in Base Case v4.10 for MATS
Plant Name
Lansing
AES Deepwater
Seminole
Seminole
St Johns River Power Park
St Johns River Power Park
W A Parish
W A Parish
W A Parish
W A Parish
Edgewater
John P Madgett
Crystal River
Crystal River
Deerhaven Generating Station
Sandow
CDMclntoshJr
UniquelD
1047 B 4
10670_B_AAB001
136_B_1
136 B 2
207_B_1
207_B_2
3470 B WAP5
3470 B WAP6
3470_B_WAP7
3470 B WAP8
4050 B 5
4271_B_B1
628_B_4
628 B 5
663 B B2
6648_B_4
676_B_3
Unit ID
4
AAB001
1
2
1
2
WAP5
WAP6
WAP7
WAP8
5
Bl
4
5
B2
4
3
State Name
Iowa
Texas
Florida
Florida
Florida
Florida
Texas
Texas
Texas
Texas
Wisconsin
Wisconsin
Florida
Florida
Florida
Texas
Florida
Capacity (MW)
261
140
658
658
626
626
645
650
565
600
414
398
722
721
228
545
342
3.9.3 CO2 Regulations and Renewable Portfolio Standards
The Regional Greenhouse Gas Initiative (RGGI) is a year-round CO2 cap and trade program affecting
fossil fired electric power plants 25 MWor larger in Connecticut, Delaware, Maine, New Hampshire, New
Jersey, New York, Vermont, Rhode Island, Massachusetts, and Maryland.
EPA Base Case v.4.10_MATS incorporated the following updated targets to reflect Colorado RPS:
- 12% of its retail electricity sales in Colorado for the years 2011-2014;
- 20% of its retail electricity sales in Colorado for the years 2015-2019; and
17
-------
- 30% of its retail electricity sales in Colorado for the years 2020 and later.
Renewable Portfolio Standards (RPS) generally refer to various state-level policies that require the
addition of renewable generation to meet a specified share of state-wide generation In EPA Base Case
v.4.10 the state RPS requirements are represented at a regional level utilizing the aggregate regional
representation of RPS requirements that is implemented in AEO 20104 as shown in Appendix 3-6. This
appendix shows the RPS requirements that apply to the NEMS (National Energy Modeling System)
regions used in AEO. The RPS requirement for a particular NEMS region applies to all IPM regions that
are predominantly contained in that NEMS region.
3.9.4 State Specific Environmental Regulations
EPA Base Case v.4.10 represents laws and regulations in 25 states affecting emissions from the
electricity sector. The laws and regulations had to either be on the books or expected to come into force.
Appendix 3-2 summarizes the provisions of state laws and regulations that are represented in EPA Base
Case 4.10.
EPA Base Case v.4.10_MATS incorporated the following provisions of the Colorado Clean Air-Clean
Jobs Act (HB 1365, passed in April 2010):
Table 3-9-4. Changes Incorporated in EPA Base Case v.4.10_MATS in Response to Provisions
of the Colorado Clean Air-Clean Jobs Act (HB 1365, passed in April 2010)
Plant
Name
Arapahoe
Arapahoe
Cameo
Cameo
Cherokee
Cherokee
Cherokee
Cherokee
Valmont
W N Clark
W N Clark
UniquelD
465 B 3
465_B_4
468_B_1
468 B 2
469_B_1
469 B 2
469 B 3
469_B_4
477_B_5
462 B 55
462 B 59
ORIS Plant
Code
465
465
468
468
469
469
469
469
477
462
462
Unit
ID
3
4
1
2
1
2
3
4
5
55
59
Modeled In v.4.1 0_FMATS
Unit retired, effective in 2015 run year
Unit forced to convert to natural gas,
effective in 2015 run year
Retired in NEEDS
Retired in NEEDS
Unit retired, effective in 2012 run year
Unit retired, effective in 2012 run year
Unit retired, effective in 2020 run year
Unit forced to convert to natural gas,
effective in 2020 run year
Unit retired, effective in 2020 run year
Unit retired, effective in 2015 run year
Unit retired, effective in 2015 run year
State Mercury Regulations in MATS Base and Policy Cases: Consistent with the mercury risk
deposition modeling for MATS, EPA did not model non-federally enforceable mercury-specific emissions
reduction rules (as shown in Appendix 3-2 in the Documentation Supplement for Proposed Toxics Rule)
in the base case or MATS policy case (see preamble section III.A)
3.9.5 New Source Review (NSR) Settlements
The New Source Review, (NSR) settlements refer to legal agreements with companies resulting from the
Energy Information Administration, U.S. Department of Energy, Assumptions to Annual Energy Outlook
2010: Renewable Fuels Module (DOE/EIA-0554(2010)), April 9, 2010, Table 13.4 "Aggregate Regional
RPS Requirements, www.eia.doe.qov/oiaf/aeo/assumption/renewable.html and
www.eia.doe.qov/oiaf/aeo/assumption/pdf/renewable tbls.pdf
18
-------
permitting process under the CAAA which requires industry to undergo an EPA pre-construction review of
proposed environmental controls either on new facilities or as modifications to existing facilities where
there would result a "significant increase" in a regulated pollutant. EPA Base Case v.4.10_MATS includes
more than 20 NSR settlements with electric power companies. EPA Base Case v.4.10_MATS includes
provisions of the recently announced NSR settlements with Northern Indiana Public Service Company
(NIPSCO) and Tennessee Valley Authority (TVA). See
www.epa.gov/compliance/resources/cases/civil/caa/nipsco.html and
www.epa.gov/compliance/resources/cases/civil/caa/tvacoalfired. An updated summary of the units
affected and how the settlements were all the NSR settlements that are modeled in Base Case
v.4.10_MATS can be found in Appendix 3-3.
Seven state settlements and five citizen settlements are also represented in EPA Base Case v.4.10.
These are summarized in Appendices 3-4 and 3-5 respectively.
3.9.7 Unit-Level Control, Emission and Fuel Assumptions (new)
The following unit specific assumptions were adopted in EPA Base Case v.4.10 for MATS:
3.9.7.1 Existing ACI Controls in MATS Base and Policy Cases: As indicated above in section 3.9.4,
EPA did not model non-federally enforceable mercury-specific emissions reduction rules. Units which
were online before 2008 with existing ACI controls installed were therefore assumed not to operate those
controls in EPA Base Case v.4.10_MATS, but were assumed to operate the existing ACI in the MATS
policy case. Units that commenced operation after 2007 were assumed to operate existing ACI because
these units are required under section 112(g) to meet HAP limitations (including Hg) for new units.
3.9.7.2 Monroe Units 1 and 2 and Big Sandy Units 1 and 2: The flue gas desulfurization (FGD) for
SO2 control at Monroe units 1 and 2 are assumed not to run in 2012. This restriction was not imposed
after 2012. Big Sandy Units 1 and 2 had dispatchable controls in the Proposed MATS. This flexibility was
not offered in Final MATS, the controls were implemented as non-dispatchable.
3.9.7.3 Dunkirk Units 3 and 4. C R Huntley Units 7 and 8: The SO2 removal rates were adjusted to
reflect DSI technology instead of FGD that was assumed in the previous versions.
DSI FGD
Dunkirk Units 3 and 4 70% 95.9%
CR Huntley Units 7 and 8 70% 92.3%
3.9.7.4 Coal Units in Washington State (including retirement of Centralia Units 1 and 2 and the
Boardman Units: Due to the approval of the Washington State Senate bill (formally known as Senate
Bill 5769), new base load coal generation in Washington is subjected to 1,100 Ibs/MWh CO2 rate limit
and Centralia Units 1 and 2 and the Boardman units are retired in 2021, 2026 and 2021 years
respectively.
3.9.7.5 D B Wilson plant: Based on a comment received bituminous coal in addition to petroleum coke
was provided as a fuel option for D B Wilson (unique ID 6823_B_W1). In previous base cases its fuel
choice had been exclusively petroleum coke. To make the additional fuel choice possible, this plant was
assigned to coal demand region IBB3 instead of PCOK
3.9.7.6 Revised Coal Assignments to Improve Consistency with EIA Form 923: The following table
shows revisions in coal assignments that were made to improve the consistency between the coal
assignments in EPA Base Case v.4.10_MATS and the coal consumption reported in EIA Form 923 for
2008.
19
-------
Table 3-9-7-5. Changes in Coal Assignments in EPA Base Case v.4.10_MATS to Improve
Consistency with Information Reported in EIA Form 923 (2008)
Plant Name
C P Crane
C P Crane
Herbert A
Wagner
Herbert A
Wagner
PSEG Hudson
Generating
Station
R E Burger
R E Burger
Willow Island
Willow Island
UniquelD
1 552_B_1
1 552_B_2
1 554_B_2
1 554_B_3
2403_B_2
2864_B_5
2864_B_6
3946_B_1
3946_B_2
ORIS
Plant
Code
1552
1552
1554
1554
2403
2864
2864
3946
3946
Unit
ID
1
2
2
3
2
5
6
1
2
Modeled Fuels In
v.4.10_FTransport
Subbituminous
Subbituminous
Subbituminous
Subbituminous
Bituminous
Bituminous
Bituminous
Bituminous
Bituminous
Modeled Fuels In
v.4.10 MATS
Subbituminous,
Bituminous
Subbituminous,
Bituminous
Subbituminous,
Bituminous
Subbituminous,
Bituminous
Subbituminous,
Bituminous
Subbituminous,
Bituminous
Subbituminous,
Bituminous
Subbituminous
Subbituminous
Notes
Coal demand
region
changed from
NE2to PE1 to
provide both
coal ranks.
20
-------
Appendix 3-3 New Source Review (NSR) Settlements in EPA Base Case v.4.10_MATS
Company and
Plant
State
Unit
Settlement Actions
Retire/Repower
Action
Alabama Power
James H. Miller
Alabama
Units
3&4
Effective
Date
SO2 control
Equipment
Percent
Removal
or Rate
Effective
Date
NOX Control
Equipment
Rate
Effective
Date
PM or Mercury Control
Equipment
Rate
Effective
Date
Allowance
Retirement
Retirement
Allowance
Restriction
Restriction
Effective
Date
Reference
Install and
operate
FGD
continuously
95%
12/31/11
Operate
existing
SCR
continuously
0.1
05/01/08
0.03
12/31/06
With 45
days of
settlement
entry, ARC
must retire
7,538S02
emission
allowances.
APC shall not
sell, trade, or
otherwise
exchange any
Plant Miller
excess SO2
emission
allowances
outside of the
APC system
1/1/21
http://www.e
pa.gov/comp
ces/cases/ci
vil/caa/alaba
mapower.ht
ml
Minnkota Power Cooperative
Beginning 1/01/2006, Minnkota shall not emit more than 31
shall not exceed 8,500.
Milton R. Young
Minnesota
Unitl
Unit 2
,000 tons of SO2/year, no more than 26, 000 tons beginn ng 2011, no more than 11,500 tons beginning 1/01/2012. If Units is not operational by 12/31/2015, then beginning 1/01/2014, the plant wide emission
Install and
continuously
operate
FGD
Design,
upgrade,
and
continuously
operate
FGD
95% if
wet
FGD,
90% if
dry
90%
12/31/11
12/31/10
Install and
continuously
operate
Over-fire
AIR, or
equivalent
technology
with
emission
rate < .36
Install and
continuously
operate
over-fire
AIR, or
equivalent
technology
emission
rate < 36
0.36
0.36
12/31/09
12/31/07
0.03 if
wet
FGD,
.01 5 if
dry FGD
0.03
Before
2008
Plant will
surrender
4,346
allowances
for each
year 2012-
2015, 8,693
allowances
for years
2016-
2018,
12,170
allowances
for year
2019, and
14,886
allowances/
year
thereafter if
Units 1 -3
are
operational
by
12/31/2015.
If only Units
1 and 2 are
operational
by1 2/31/201
5, the plant
shall retire
17,886 units
in 2020 and
thereafter.
Minnkota shall
not sell or trade
NOX allowances
allocated to
Units 1, 2, or 3
that would
otherwise be
available for
sale or trade as
a result of the
actions taken by
the settling
defendants to
comply with the
requirements
http://www.e
pa.gov/comp
ces/cases/ci
vil/caa/minnk
ota. htm I
21
-------
SIGECO
FB Culley
Indiana
Unitl
Unit 2
Units
Repower
to
natural
gas (or
retire)
12/31/06
Improve and
continuously
operate
existing
FGD
(shared by
Units 2 and
3)
Improve and
continuously
operate
existing
FGD
(shared by
Units 2 and
3)
95%
95%
06/30/04
06/30/04
Operate
Existing
SCR 0. 1
Continuousl
y
PSEG FOSSIL
Bergen
Hudson
New Jersey
New Jersey
Unit 2
Unit 2
Repower
to
combine
d cycle
12/31/02
Install Dry
FGD (or
approved
alt.
technology)
and
continually
operate
0.15
12/31/06
09/01/03
Install and
continuously - -,,-
operate a
Baghouse
Install SCR
(or approved
tech) and 0.1
continually
operate
05/01/07
06/30/07
The
provision did
not specify
an amount
of S02
allowances
to be
surrendered.
It only
provided
that excess
allowances
resulting
from
compliance
with NSR
settlement
provisions
must be
retired.
http://www.epa.gov/compli
ance/resources/cases/civil
/caa/sigecofb.html
Install
Baghouse „„_
(or approved U'Ulb
technology)
12/31/06
The
provision did
not specify
an amount
of S02
allowances
to be
surrendered.
It only
provided
that excess
allowances
resulting
from
compliance
with NSR
settlement
provisions
must be
retired.
http://www.epa.gov/compli
ance/resources/cases/civil
/caa/psegllc.html
22
-------
Mercer
New Jersey
1 &2
Install Dry
FGD (or
technology)
continually
operate
0.15
12/31/10
Install SCR
(or approved
tech) and
continually
operate
0.13
05/01/06
TECO
Big Bend
Gannon
Florida
Florida
Units
1 &2
Units
Unit 4
units
Retire all
six coal
units and
repower
550 MW
to
natural
gas
12/31/04
Existing
Scrubber
(shared by
Units 1 & 2)
Existing
Scrubber
(shared by
Units 3 & 4)
Existing
Scrubber
(shared by
Units 3 & 4)
95%
(95% or
93% if
Units 3 &
4 are
operating
93% if
Units 3 &
4 are
operating
09/1/00
(01/01/1
3)
2000
(01/01/1
06/22/05
Install SCR
Install SCR
Install SCR
0.1
0.1
0.1
05/01/09
05/01/09
07/01/07
The
provision did
not specify
an amount
of S02
allowances
to be
surrendered.
It only
provided
from
compliance
with NSR
settlement
provisions
must be
retired.
http://www.epa.gov/compli
ance/resources/cases/civil
/caa/teco.html
WEPCO
WEPCO shall comply with the following system wide average NOX emisson rates and total NOX tonnage permissible: by 1/1/2005 an emission rate of 0.27 and 31,500 tons, by 1/1/2007 an emission rate
of 0.1 9 and 23, 400 tons, and by 1/1/2013 an emission rate of 0.17 and 17, 400 tons. For SO2 emissions, WEPCO will comply with: by 1/1/2005 an emission rate of 0.76 and 86,900 tons, by 1/1/2007 an
emission rate of 0.61 and 74, 400 tons, by 1/1/2008 an emission rate of 0.45 and 55, 400 tons, and by 1/1/201 3 an emssion rate of 0.32 and 33, 300 tons.
Presque Isle
Pleasant Prairie
Wisconsin
Wisconsin
Units
1 -4
5&6
Units
7 & 8
Unit 9
1
Retire or
install
SO2 and
NOX
controls
12/31/12
Install and
continuously
operate
FGD (or
approved
equiv. tech)
Install and
continuously
operate
FGD (or
95% or
0.1
95% or
0.1
12/31/12
12/31/06
Install SCR
(or approved
tech) and
continually
operate
Install and
operate low
NOX burners
Operate
existing low
NOX burners
Operate
existing low
NOX burners
Install and
continuously
operate
SCR (or
0.1
0.1
12/31/12
12/31/03
12/31/05
12/31/06
12/31/06
Install
Install
Baghouse
http://www.epa.gov/compliance/resources/cases/civil/caa/wepco
The
provision did
not specify
an amount
of SO2
allowances
to be
surrendered.
It only
provided
that excess
allowances
resulting
from
compliance
with NSR
settlement
provisions
must be
retired.
23
-------
Oak Creek
Port Washington
Valley
Wisconsin
Wisconsin
Wisconsin
2
Units
5&6
Unit/
Units
Units
Boiler
s1 -
4
Retire
12/31/04
for Units
1 -3.
Unit 4 by
entry of
consent
decree
approved
control tech)
Install and
continuously
operate
FGD (or
approved
control tech)
Install and
continuously
operate
FGD (or
approved
control tech)
Install and
continuously
operate
FGD (or
approved
control tech)
Install and
continuously
operate
FGD (or
approved
control tech)
95% or
0.1
95% or
0.1
95% or
0.1
95% or
0.1
12/31/07
12/31/12
12/31/12
12/31/12
approved
tech)
Install and
continuously
operate
SCR (or
approved
tech)
Install and
continuously
operate
SCR (or
approved
tech)
Install and
continuously
operate
SCR (or
approved
tech)
Install and
continuously
operate
SCR (or
approved
tech)
Operate
existing low
NOX burner
0.1
0.1
0.1
0.1
12/31/03
12/31/12
12/31/12
12/31/12
30 days
after
entry of
consent
decree
VEPCO
The Total Permissible NOx Emissions (in tons) from VEPCO system are: 1 04,000 in 2003, 95,000 in 2004, 90,000 in 2005, 83,000 in 2006, 81 ,000 in 2007, 63,000 in 2008 - 201 0, 54,000 in 201 1 ,
50,000 in 2012, and 30, 250 each year there after. Beginning 1/1/2013 they will have a system wide emission rate no greater then 0.15 Ib/MMBtu.
Mount Storm
Chesterfield
West
Virginia
Virginia
Units
1 -3
Unit 4
Units
Unite
Construct or
improve
FGD
Construct or
improve
Construct or
improve
FGD
95% or
0.15
95% or
0.13
95% or
0.13
01/01/05
10/12/12
01/01/10
Install and
continuously
operate
SCR
continuously
operate
SCR
Install and
continuously
operate
SCR
Install and
continuously
operate
SCR
0.11
0.1
0.1
0.1
01/01/08
01/01/13
01/01/12
01/01/11
http://www.epa.gov/compliance/resources/cases/civil/caa/vepco
.html
On or before
March 31 of
every year
201 3 and
continuing
thereafter,
VEPCO
shall
surrender
45,000 SO2
24
-------
Chesapeake
Energy
Clover
Possum Point
Santee Cooper
Cross
Winyah
Grainger
Jeffries
Virginia
Virginia
Virginia
Units
3&4
Units
1 &2
Units
3&4
Retire
and
re power
to
natural
gas
05/02/03
Improve
FGD
95% or
0.13
09/01/03
Install and
continuously
operate
SCR
0.1
01/01/13
Santee Cooper shall comply with the following system wide averages for NOX emission rates and combined tons for emission of: by 1/01/2005 facility shall comply with an emission rate of 0.3 and 30,000 tons, by 1/1/2007 an
emission rate of 0.18 and 25,000 tons, by 1/1/2010 and emission rate of 0.15 and 20,000 tons. For SO2 emission the company shall comply with system wide averages of: by 1/1/2005 an emission rate of 0.92 and 95,000 tons, by
1/1/2007 and emission rate of 0.75 and 85, 000 tons, by 1/1/2009 an emission rate of 0.53 and 70 tons, and by 1/1/2011 and emission rate of 0.5 and 65 tons.
South
Carolina
South
Carolina
South
Carolina
South
Carolina
Unitl
Unit 2
Unitl
Unit 2
Units
Unit 4
Unitl
Unit 2
Units
3,4
Upgrade
and
continuously
operate
FGD
Upgrade
and
continuously
operate
FGD
Install and
continuously
operate
FGD
Install and
continuously
operate
FGD
Upgrade
and
continuously
operate
existing
FGD
Upgrade
and
continuously
operate
existing
FGD
95%
87%
95%
95%
90%
90%
06/30/06
06/30/06
12/31/08
12/31/08
12/31/08
12/31/07
Install and
continuously
operate
SCR
Install and
Continuousl
y operate
SCR
Install and
continuously
operate
SCR
Install and
continuously
operate
SCR
Install and
continuously
operate
SCR
Install and
continuously
operate
SCR
Operate low
NOX burner
or more
stringent
technology
Operate low
NOX burner
or more
stringent
technology
Operate low
NOX burner
or more
stringent
technology
0.1
0.11/0.1
0.11/0.1
0.12
0.14/0.12
0.13/0.12
05/31/04
05/31/04
and
05/31/07
11/30/04
and
11/30/04
11/30/04
11/30/20
05 and
11/30/08
11/30/05
and
11/30/08
06/25/04
05/01/04
06/25/04
The
provision did
not specify
an amount
of SO2
allowances
to be
surrendered.
It only
provided
that excess
allowances
resulting
from
compliance
with NSR
settlement
provisions
must be
retired.
http://vwvw.e
pa.gov/comp
liance/resour
ces/cases/ci
vil/caa/sante
ecooper.html
Ohio Edison
25
-------
Ohio Edison shall achieve reductions of 2,483 tons NOX between 7/1/2005 and 12/31/2010 using any combination of: 1) low sulfur coal at Burger Units 4 and 5, 2) operating SCRs currently installed at
Mansfield Units 1-3 during the months of October through April, and/or 3) emitting fewer tons than the Plant-Wide Annual Cap for NOX required for the Sammis Plant. Ohio Edison must reduce 24,600
tons system-wide of SO2 by 12/31/2010.
http://www.epa.gov/compliance/resources/cases/civil/caa/ohioe
No later than 8/11/2005, Ohio Edison shall install and operate lowNOx burners on Sammis Units 1 - 7 and overfired air on Sammis Units 1,2,3,6, and 7. No later than 12/1/2005, Ohio Edison shall install advanced combustion control optimization with software to minimize
NOX emissions from Sammis Units 1-5.
W.H. Sammis
Plant
Mansfield Plant
Ohio
Pennsylvan
Unitl
Unit 2
Units
Unit 4
Units
Unite
Unit 7
Unitl
Install
Induct
Scrubber (or
approved
equiv.
control tech)
Install
Induct
Scrubber (or
approved
equiv.
control tech)
Install
Induct
Scrubber (or
approved
equiv.
control tech)
Install
Induct
Scrubber (or
approved
equiv.
control tech)
Install Flash
Dryer
Absorber
or ECO2 (or
approved
equiv.
control tech)
&
operate
continuously
Install FGDd
(or
approved
equiv.
control tech)
&
operate
continuously
Install FGD
(or
approved
equiv.
control tech)
&
operate
continuously
Upgrade
existing
FGD
50%
removal
or 1.1
Ib/MMBt
u
50%
removal
or 1.1
Ib/MMBt
50%
removal
or 1.1
Ib/MMBt
u
50%
removal
or 1.1
Ib/MMBt
u
50%
removal
or 1.1
Ib/MMBt
u
95%
or 0.13
Ib/MMBt
95%
removal
or 0.13
Ib/MMBt
u
95%
12/31/08
12/31/08
12/31/08
06/30/09
06/29/09
06/30/1 1
06/30/1 1
12/31/05
Install
SNCR
(or approved
alt. tech) &
operate
continuously
Operate
existing
SNCR
continuously
Operate low
NOX burners
and overfire
air by
12/1/05;
install SNCR
(or approved
alt. tech) &
operate
continuously
by 12/31/07
Install
SNCR
(or approved
alt. tech) &
operate
continuously
Install
SNCR
(or approved
alt. tech) &
Operate
Continuousl
y
Install
SNCR
(or approved
alt. tech) &
operate
continuously
Operate
existing
SNCR
Continuousl
y
0.25
0.25
0.25
0.25
0.29
"Minimum
Extent
Practicabl
e"
"Minimum
Extent
Practicabl
e"
10/31/07
02/15/06
12/01/05
and
10/31/07
10/31/07
03/31/08
06/30/05
08/11/05
Operate
Existing
ESP
Continuously
Operate
Existing
ESP
Continuously
0.03
0.03
01/01/10
01/01/10
Beginning on
1/1/2006, Ohio
Edison may
use, sell or
transfer any
restricted SO2
only to satisfy
the Operational
Needs at the
Sammis, Burger
and Mansfield
Plant, or new
units within the
FirstEnergy
System that
comply with a
96% removal
for SO2. For
calendar year
2006 through
2017, Ohio
Edison may
accumulate
SO2 allowances
for use at the
Sammis,
Burger, and
Mansfield
plants, or
FirstEnergy
units equipped
with SO2
Emission
Control
Standards.
Beginning in
2018, Ohio
Edison shall
surrender
unused
restricted SO2
allowances.
26
-------
Eastlake
Burger
Ohio
Ohio
Unit 2
Units
Units
Unit 4
Units
Repower
with at
least
80%
biomass
fuel, up
to 20%
low
sulfur
coal.
12/31/11
12/31/11
Upgrade
existing
FGD
Upgrade
existing
FGD
95%
95%
12/31/06
10/31/07
Install low
NOX
burners,
over-fired
air and
SNCR&
operate
continuously
"Minimize
Emission
s to the
Extent
Practicabl
e"
12/31/06
Mirantl1-6
System-wide NOX Emission Annual Caps: 36,500 tons 2004; 33,840 tons 2005; 33,090 tons 2006; 28,920 tons 2007; 22,000 tons 2008; 19,650 tons 2009; 16,000 tons 2010 onward. System-wide NOX
Emission Ozone Season Caps: 14, 700 tons 2004; 13, 340 tons 2005; 12,590 tons 2006; 10,190 tons 2007; 6,150 tons 2008 -2009; 5,200 tons 2010 thereafter. Beginning on 5/1/2008, and continuing for
each and every Ozone Season thereafter, the Mirant System shall not exceed a System-wide Ozone Season Emission Rate of 0.150 Ib/MMBtu NOX.
Potomac River
Plant
Morgantown
Plant
Virginia
Maryland
Unitl
Unit 2
Units
Unit 4
Units
Unitl
Install low
NOX
burners (or
more
effective
tech) &
operate
continuously
Install low
NOX
burners (or
more
effective
tech) &
operate
continuously
Install low
NOX
burners (or
more
effective
tech) &
operate
continuously
Install SCR
(or approved
alt. tech) &
operate
continuously
0.1
05/01/04
05/01/04
05/01/04
05/01/07
http://www.epa.gov/compliance/resources/cases/civil/caa/mirant
.html
27
-------
Chalk Point
Maryland
Unit 2
Unitl
Unit 2
Install and
continuously
operate
FGD (or
equiv.
technology)
Install and
continuously
operate
FGD (or
equiv.
technology)
95%
95%
06/01/10
06/01/10
Install SCR
(or approved
alt. tech) &
operate
continuously
0.1
05/01/08
For each year
after Mirant
commences
FGD operation
at Chalk Point,
Mirant shall
surrender the
number of SO2
Allowances
equal to the
amount by
which the SO2
allocated to the
Units at the
Chalk Point
Plant are
greater than the
total amount of
SO2 emissions
allowed under
this Section
XVIII.
Illinois Power
System-wide NOx Emission Annual Caps: 15,000 tons 2005; 14,000 tons 2006; 13,800 tons 2007 onward. System-wide SO2 Emisson Annual Caps: 66,300 tons 2005 - 2006; 65,000 tons 2007;
62,000 tons 2008 - 201 0; 57,000 tons 201 1 ; 49,500 tons 201 2; 29,000 tons 201 3 onward.
Baldwin
Havana
Hennepin
Illinois
Illinois
Illinois
Units
1 &2
Units
Unite
Unitl
Install wet
or dry FGD
(or
approved
equiv. alt.
tech) &
operate
continuously
Install wet
or dry FGD
(or
approved
equiv. alt.
tech) &
operate
continuously
Install wet
or dry FGD
(or
approved
equiv. alt.
tech) &
operate
continuously
0.1
0.1
1.2
Ib/MMBt
u until
12/30/20
12; 0.1
Ib/MMBt
u from
12/31/20
12
onward
1.2
12/31/11
12/31/11
08/11/05
and
12/31/12
07/27/05
Operate
OFA &
existing
SCR
continuously
Operate
OFA and/or
low NOX
burners
Operate
OFA and/or
low NOX
burners &
operate
existing
SCR
continuously
Operate
OFA
and/or low
NOX burners
0.1
0.12 until
12/30/12;
0.1 from
12/31/12
0.1
"Minimum
Extent
Practicabl
e"
08/11/05
08/11/05
and
12/31/12
08/11/05
08/11/05
Install &
continuously
operate
Baghouse
Install &
continuously
operate
Baghouse
Install &
continuously
operate
Baghouse,
then install
ESP or alt.
PM equip
Install ESP
(or equiv. alt.
tech) &
continuously
0.015
0.015
For Bag-
house:
0.015
Ib/MMBt
u; For
ESP:
0.03
Ib/MMBt
U
0.03
12/31/10
12/31/10
For
Baghous
e:
12/31/12;
For ESP:
12/31/05
12/31/06
http://www.epa.gov/compliance/resources/cases/civil/caa/illinois
power.html
By year end
2008, Dynergy
will surrender
1 2,000 S02
emission
allowances, by
year end 2009 it
will surrender
18,000, by year
end 2010 it will
surrender
24,000, any by
year end 2011
and each year
thereafter it will
surrender
30 000
allowances. If
the surrendered
allowances
result in
insufficient
remaining
allowances
allocated to the
units
comprising the
DMG system,
DMG can
request to
surrender fewer
SO2
allowances.
28
-------
Vermilion
Wood River
Illinois
Illinois
Unit 2
Units
1 &2
Units
4&5
1.2
1.2
1.2
07/27/05
01/31/07
07/27/05
Operate
OFA
and/or low
NOX burners
Operate
OFA
and/or low
NOX burners
Operate
OFA
and/or low
NOX burners
"Minimum
Extent
Practicabl
e"
"Minimum
Extent
Practicabl
e"
"Minimum
Extent
Practicabl
e"
08/11/05
08/11/05
08/11/05
operate
ESPs
Install ESP
(or equiv. alt.
tech) &
continuously
operate
ESPs
Install ESP
(or equiv. alt.
tech) &
continuously
operate
ESPs
Install ESP
(or equiv. alt.
tech) &
continuously
operate
ESPs
0.03
0.03
0.03
12/31/06
12/31/10
12/31/05
Kentucky Utilities Company
EW Brown
Generating
Station
Kentucky
Units
Install FGD
97% or
0.100
12/31/10
Install and
continuously
operate
SCR by
12/31/2012,
continuously
operate low
NOX boiler
and OFA.
0.07
12/31/12
Continuously
operate ESP
0.03
12/31/10
Salt River Project Agricultural Improvement and Power District (SRP)
Coronado
Generating
Station
Arizona
Unitl
or
Unit 2
Unitl
or
Unit 2
Immediately
begin
continuous
operation of
existing
FGDs on
both units,
install new
FGD.
Install new
FGD
95% or
0.08
95% or
0.08
New
FGD
installed
by
1/1/2012
01/01/13
Install and
continuously
operate low
NOX burner
and SCR
Install and
continuously
operate low
NOX burner
0.32 prior
to SCR
installatio
n, 0.080
after
0.32
LNBby
06/01/20
09, SCR
by
06/01/20
14
06/01/11
Optimization
and
continuous
operation of
existing
ESPs.
0.03
Optimiza
tion
begins
immediat
ely, rate
limit
begins
01/01/12
(date of
new
FGD
installatio
n)
Optimiza
tion
begins
immediat
ely, rate
limit
begins
01/01/13
(date of
53,000 S02
allowances of
2008 or earlier
vintage by
March 1 , 2009.
All surplus NOX
allowances
surrendered
through 2020.
SO2 and NOX
allowances may
not be used for
compliance,
and emissions
decreases for
purposes of
complying with
the Consent
Decree do not
earn credits.
/resources
/cases/civ i
mpanv.ht
Beginning in
2012, all
surplus SO2
allowances for
both Coronado
and
Springerville
Unit 4 must be
surrendered
through 2020.
The allowances
limited by this
condition may,
however, be
used for
compliance at a
prospective
future plant
using BACT
and otherwise
specified in par.
54 of the
SO2 and NOX
allowances may
not be used for
compliance,
and emissions
decreases for
purposes of
complying with
the Consent
Decree do not
earn credits.
ompliance
/cases/civ i
l/caa/srp.h
trnl
29
-------
new
FGD
installatio
n)
American Electric Power
Eastern System-Wide
At least 600MW
from various
units
Amos
West
Virginia
Virginia
Indiana
West
Virginia
West
Virginia
Spor
n
1 -4
Clinc
h
River
1 -3
ers
Cree
k
1 -3
1 -3
Unitl
Retire,
retrofit,
12/31/18
Install and
continuously
operate
FGD
Annual
Cap
(tons)
450,000
450,000
420,000
350,000
340,000
275,000
260,000
235,000
184,000
174,000
Year
2010
2011
2012
2013
2014
2015
2016
2017
201 9 and
thereafte
12/31/09
Install and
continuously
operate
SCR
Annual
Cap
(tons)
96,000
92,500
92,500
85,000
85,000
85,000
75,000
72,000
Year
2009
2010
2011
2012
2013
2014
2015
2016 and
thereafte
r
01/01/08
consent decree.
NOX and SO2
allowances that
would have
been made
available by
emission
reductions
pursuant to the
Consent
Decree must be
surrendered.
NOX and SO2
not be used to
of the limits
Consent
Consent
a formula for
calculating
excess NOX
allowances
relative to the
CAIR
Allocations, and
restricts the use
of some. See
par. 74-79 for
details.
Reducing
emissions
below the
Eastern
System- Wide
Annual
Tonnage
Limitations for
NOX and SO2
earns super
compliance
allowances.
http://www
.epa.gov/c
ompliance
/resources
/cases/civ i
l/caa/amer
icanelectri
cpowerlO
07.html
_
30
-------
Big Sandy
Cardinal
Clinch River
Conesville
Kentucky
Ohio
Virginia
Ohio
Unit 2
Units
Unitl
Unit 2
Unitl
Unit 2
Units
Units
1 -3
Unit 1
Unit 2
Retire,
retrofit,
or re-
power
Retire,
retrofit,
or re-
power
Date of
entry
Date of
entry
Install and
continuously
operate
FGD
Install and
continuously
operate
FGD
Burn only
coal with no
more than
1.75
Ib/MMBtu
annual
average
Install and
continuously
operate
FGD
Install and
continuously
operate
FGD
Install and
continuously
operate
FGD
Install and
continuously
operate
FGD
Plant-
wide
annual
cap:
21,700
tons from
2010 to
2014,
then
16,300
after
1/1/2015
12/31/10
12/31/09
Date of
entry
12/31/15
12/31/08
12/31/08
12/31/12
2010-
2014,
201 5 and
thereafte
r
Install and
continuously
operate
SCR
Install and
continuously
operate
SCR
Continuousl
y operate
low NOX
burners
Install and
continuously
operate
SCR
Install and
continuously
operate
SCR
Install and
continuously
operate
SCR
Install and
continuously
operate
SCR
Continuousl
y operate
low NOX
burners
01/01/09
01/01/08
Date of
entry
01/01/09
01/01/09
01/01/09
01/01/09
Date of
entry
Continuously
operate ESP
Continuously
operate ESP
0.03
0.03
12/31/09
12/31/09
_
_
-
_
_
_
"
"
31
-------
Gavin
Glen Lyn
Kammer
Kanawha River
Mountaineer
Muskingum
River
Ohio
Virginia
West
Virginia
West
Virginia
West
Virginia
West
Virginia
Ohio
Units
Unit 4
Units
Unite
Unitl
Unit 2
Units
1 -3
Units
5, 6
Units
1 -3
Units
1,2
Unitl
Unit 2
Unitl
Units
1 -4
Retire,
'
power
Retire,
retrofit,
or re-
power
12/31/12
12/31/15
Install and
continuously
operate
FGD
Upgrade
existing
FGD
existing
Install and
continuously
operate
FGD
Install and
continuously
operate
FGD
Burn only
coal with no
more than
1 75
Ib/MMBtu
annual
average
Burn only
coal with no
more than
1.75
Ib/MMBtu
average
Install and
continuously
operate
FGD
Install and
continuously
operate
FGD
Install and
continuously
operate
FGD
95%
95%
Plant-
wide
annual
cap:
35,000
12/31/10
12/31/09
12/31/09
Date of
entry
Date of
entry
Date of
entry
01/01/10
Date of
entry
12/31/07
12/31/07
12/31/07
Install and
continuously
operate
SCR
Continuousl
y operate
low NOX
burners
Continuousl
y operate
low NOX
burners
Install and
continuously
operate
SCR
Install and
continuously
operate
SCR
Continuousl
y operate
low NOX
burners
Continuousl
y operate
over-fire air
Continuousl
y operate
low NOX
burners
Install and
continuously
operate
SCR
Install and
continuously
operate
SCR
Install and
continuously
operate
SCR
12/31/10
Date of
entry
Date of
entry
01/01/09
01/01/09
Date of
entry
Date of
entry
Date of
entry
01/01/09
01/01/09
01/01/08
"
_
_
_
_
-
-
-
_
_
_
32
-------
Picway
Rockport
Sporn
Tanners Creek
Ohio
Indiana
West
Virginia
Indiana
Units
Unit 9
Unitl
Unit 2
Units
Units
1 -3
Unit 4
Retire,
retrofit,
or re-
power
12/31/13
Install and
continuously
operate
FGD
Install and
continuously
operate
FGD
Install and
continuously
operate
FGD
Burn only
coal with no
more than
1.2
Ib/MMBtu
annual
average
Burn only
coal with no
more than
1.2% sulfur
content
annual
average
12/31/15
12/31/17
12/31/19
Date of
entry
Date of
entry
Install and
continuously
operate
SCR
Continuousl
y operate
low NOX
burners
Install and
continuously
operate
SCR
Install and
continuously
operate
SCR
Continuousl
y operate
low NOX
burners
Continuousl
y operate
over-fire air
01/01/08
Date of
entry
12/31/17
12/31/19
Date of
entry
Date of
entry
Continuously
operate ESP
0.03
12/31/02
East Kentucky Power Cooperative Inc.
-
-
-
-
-
-
-
By 12/31/2009, EKPC shall choose whether to: 1) install and continuously operate NOX controls at Cooper 2 by 12/31/2012 and SO2 controls by 6/30/2012 or 2) retire Dale 3 and Dale 4 by 12/31/2012.
System- wide
System-
wide 1 2-
month
rolling
tonnage
limits apply
12-
month
rolling
limit
(tons)
57,000
40,000
Start of
12-
month
cycle
10/01/08
07/01/11
All units
must
operate low
NOX boilers
12-month
rolling
limit
(tons)
11,500
8,500
Start of
12-
month
cycle
01/01/08
01/01/13
PM control
devices must
be operated
continuously
system- wide,
ESPs must
be optimized
within 270
days of entry
date, or
0.03
1 year
from
entry
date
All surplus SO2
allowances
must be
surrendered
each year,
beginning in
2008.
SO2 and NOX
allowances may
not be used to
comply with the
Consent
Decree. NOX
allowances that
would become
available as a
result of
http://www
.epa.gov/c
ompliance
/resources
/cases/civ i
l/caa/neva
dapower.h
tml
33
-------
Spurlock
Kentucky
Unitl
Install and
continuously
operate
FGD
28,000
95% or
0.1
01/01/13
6/30/201
1
Continuousl
y operate
SCR
8,000
0.1 2 for
Unitl
until
01/01/201
3, at
which
point the
unit limit
drops to
0.1. Prior
to
01/01/201
3, the
combined
average
when
both units
are
operating
must be
no more
than 0.1
01/01/15
60 days
after
entry
EKPC may
choose to
submit a PM
Pollution
Control
Upgrade
Analysis.
compliance with
the Consent
Decree may not
be sold or
traded. SO2
and NOX
allowances
allocated to
EKPC must be
used within the
EKPC system.
Allowances
made available
due to super
compliance
may be sold or
traded.
34
-------
Dale Plant
Cooper
Kentucky
Kentucky
Unit 2
Unitl
Unit 2
Units
Unit 4
Unitl
Unit 2
EKPC
may
choose
to retire
Dale 3
and 4 in
lieu of
installing
controls
in
Cooper 2
12/31/20
1 2
Install and
continuously
operate
FGDby
10/1/2008
If EKPC
opts to
install
controls
rather than
retiring
Dale, it must
install and
continuously
operate
FGDor
equiv.
technology
95% or
0.1
95% or
0.10
1/1/2009
Continuousl
y operate
SCR and
OFA
Install and
continuously
operate low
NOX burners
by
10/31/2007
Install and
continuously
operate low
NOX burners
by
10/31/2007
If EKPC
elects to
install
controls, it
must
continuously
operate
SCR or
install equiv.
technology
0.1 for
Unit 2,
0.1
combined
average
when
both units
are
operating
0.46
0.46
0.08 (or
90% if
non-SCR
technolog
y is used)
60 days
after
entry
01/01/08
01/01/08
12/31/12
Nevada Power Company
Beginning 1/1/2010, combined NOX emissions from Units 5,6,7, and 8 must be no more than 360 tons per year.
Clark Generating
Station
Nevada
Units
Units
may only
fire
natural
Increase
water
injection
immediately,
5ppm 1-
hour
average
12/31/08
(ULNB
installatio
n),
EKPC must
surrender 1,000
NOX allowances
immediately
under the ARP,
and 3, 107
under the NOX
SIP Call. EKPC
must also
surrender
15,311 S02
allowances.
Date of
entry
http://www
.epa.gov/c
ompliance
/resources
/cases/civ i
l/caa/eastk
entuckypo
wer-
dale0907.
html
Allowances
may not be
used to comply
with the
http://www
ompliance
/resources
35
-------
Unite
Unit 7
Units
gas
then install
and operate
ultra- low
NO); burners
(ULNBs) or
equivalent
technology.
In 2009,
Units 5 and
8 may not
emit more
than 180
tons
combined
5ppm 1-
hour
average
5ppm 1-
hour
average
5ppm 1-
hour
average
01/30/09
(1-hour
average)
12/31/09
(ULNB
installatio
n),
01/30/10
(1-hour
average)
12/31/09
(ULNB
installatio
n),
01/30/10
(1-hour
average)
12/31/08
(ULNB
installatio
n),
01/30/09
(1-hour
average)
Dayton Power & Light
Non-EPA Settlement of 10/23/2008
Stuart
Generating
Station
Ohio
Static
n-
wide
Complete
installation
of FGDs on
each unit.
96% or
0.10
82%
including
data
from
periods
of
malfuncti
ons
82%
including
data
from
periods
of
malfuncti
ons
07/31/09
7/31/09
through
7/30/1 1
after
7/31/11
Owners may
not
purchase
any new
catalyst with
SO2 to SO3
conversion
rate greater
than 0.5%
Install
control
technology
on one unit
0.17
station-
wide
0.17
station-
wide
0.10 on
any
single
unit
0.15
station-
wide
0.10
station-
wide
30 days
after
entry
60 days
after
entry
date
12/31/12
07/01/12
12/31/14
0.030 Ib
per unit
Install
rigid-
type
electro-
des in
each
unit's
ESP
07/31/09
1 2/31/1 5
PSEG FOSSIL, Amended Consent Decree of November 2006
Kearny
New Jersey
Unit 7
Retire
01/01/07
Consent
Decree, and no
allowances
made available
due to
compliance with
the Consent
Decree may be
traded or sold.
/cases/civ i
l/caa/neva
dapower.h
tml
NOX and SO2
allowances may
not be used to
comply with the
monthly rates
specified in the
Consent
Decree.
Courtlink
document
provided
by EPA in
email
Allowances
allocated to
Kearny,
Hudson, and
Mercer may
only be used for
the operational
http://www
.epa.gov/c
ompliance
/resources
/decrees/a
mended/p
segfossil-
36
-------
Hudson
Mercer
New Jersey
New Jersey
Units
Unit 2
Units
1 &2
Retire
unit
01/01/07
Install Dry
FGD (or
approved
alt.
technology)
and
continually
operate
Install Dry
FGD (or
approved
alt.
technology)
and
continually
operate
0.15
Annual
Cap
(tons)
5,547
5,270
5,270
5,270
0.15
12/31/10
Year
2007
2008
2009
2010
12/31/10
Install SCR
(or approved
tech) and
continually
operate
Install SCR
(or approved
tech) and
continually
operate
0.1
Annual
Cap
(tons)
3,486
3,486
3,486
3,486
0.1
12/31/10
Year
2007
2008
2009
2010
01/01/07
Baghouse
(or approved
technology)
Install
Baghouse
(or approved
technology)
0.015
0.015
12/31/10
12/31/10
needs of those
units, and all
surplus
must be
surrendered.
Within 90 days
of amended
Consent
Decree, PSEG
must surrender
1,230 NOx
Allowances and
8,568 SO2
Allowances not
already
generated by
the units listed
here. Kearny
allowances
must be
surrendered
with the
shutdown of
those units.
amended-
cd.pdf
Westar Energy
Jeffrey Energy
Center
Kansas
All
units
Units 1 , 2, and 3 have a total annual
limit of 6,600 tons of SO2 and an
annual rate limit of 0.07 Ibs/MMBtu
starting 2012
Units 1 , 2, and 3 must all install FGDs
by 201 1 and operate them
continuously.
FGDs must maintain a 30-Day Rolling
Average Unit Removal Efficencyfor
SO2 of at least 97% or a 30-Day
Rolling Average Unit Emiss on Rate for
SO2 of no greater than 0.070
Units 1-3 must continuously operate Low
NOx Combustion Systems by 2012 and
achieve and maintain a 30-Day Rolling
Average Unit Emission Rate for NOx of
no greater than 0.180 Ib/MMBtu.
One of the three units must install an
SCR by 2015 and operate it
continuously to maintain a 30-Day
Rolling Average Unit Emission Rate for
NOx of no greater than 0.080 Ib/MMBtu.
By 201 3 Westar shall elect to either (a)
install a second SCR on one of the other
JEC Units by 2017 or (b) meet a 0.100
Ib/MMBtu Plant-Wide 12-Month Rolling
Average Emission Rate and 9.6 MTons
annual cap for NOx by 2015
Units 1 , 2, and 3 must operate each
ESP and FGD system continuously by
2011 and maintain a 0.030 Ib/MMBtu
PM Emissions Rate.
Units 1 and 2's ESPs must be rebuilt by
2014 in order to meet a 0.030 Ib/MMBtu
PM Emissions Rate
Duke Energy
Gallagher
Indiana
1 & 3
Retire or
re power
as
natural
gas
1/1/2012
37
-------
Units
2&4
Install Dry
sorbent
injection
technology
80%
1/1/2012
American Municipal Power
Gorsuch Station
Ohio
Units
2&3
Units
1 &4
Elected to Retire Dec
15, 2010 (must retire
by Dec 31, 2012)
http://am
.orq/new
sroom/a
mp-to-
retire-
qeneratin
a-station/
Hoosier Energy Rural Electric Cooperative
Ratts
Merom
Indiana
Indiana
Units
1 &2
Unitl
Unit 2
Continually
run current
FGD for
90%
removal and
update FGD
for 98%
removal by
2012
Continually
run current
FGD for
90%
removal and
update FGD
for 98%
removal by
2014
98%
98%
2012
2014
Install &
continually
operate
SNCRS
Continuously
operate
existing
SCRs
0.25
0.12
12/31/20
11
Continuously operate ESP
Continuously operate ESP and achieve
PM rate no greater than 0.007 by
6/1/12
Continuously operate ESP and achieve
PM rate no greater than 0.007 by
6/1/13
Annually surrender any NOx and SO2 allowances
that Hoosier does not need in order to meet its
regu atory obligations
http://ww
v/complia
urces/ca
ses/civil/
ier.html
Northern Indiana Public Service Co.
System-wide NOX Emission Caps n Tons: 15,537 in 2012, if NIPSCO chooses NOx Option 1: 15,247 n 2013, 14,959 in 2014, 14,365 in 2015, 11,704 in 2016 - 2018, if NIPSCO chooses NOx option A: 11,704 in 2019 & onwards, if NIPSCO chooses NOx option B: 10,300
in 2019 & onwards; if NIPSCO chooses NOx Option 2: 13,752 in 2013, 13,464 in 2014, 12,870 in 2015 - 2018, if NIPSCO chooses NOx option A: 12,870 in 2019 & onwards, if NIPSCO chooses NOx option B: 11,470 in 2019 & onwards. System-wide SO2 Emission Caps
in Tons: 50,200 in 2012 - 2013,10,200 35,900 in 2014 & 2015, 25,300 in 2016-2018, if NIPSCO chooses SO2 option 1: 10,200 in 2019 & onwards, if NIPSCO chooses SO2 option 2: 11,600 in 2019 & onwards.
Bailly
Michigan City
Indiana
Indiana
Units
7&8
Unit
12
Upgrade
existing
FGD
FGD
95% by 01/01/11
97% by 01/01/1 4 (95%
if low sulfur coal only
is burned)
0.1
Ib/MMBt
u
12/31/20
18
OFA&SCR
OFA&SCR
0.15lb/MMBtu by
12/31/10
0.13 Ib/MMBtu by
12/31/13
0.12 Ib/MMBtu by
12/31/15
0.14 Ib/MMBtu by
12/31/10
0.12 Ib/MMBtu by
12/31/11
0.10 Ib/MMBtu by
12/31/13
0.3
Ib/MMBt
u (0.015
if a
baghous
e is
installed
)
0.3
Ib/MMBt
u (0.015
if a
baghous
e is
installed
)
12/31/20
10
12/31/20
18
38
-------
Schahfer
Dean H Mitchell
Indiana
Indiana
Indiana
Indiana
Unit
14
Unit
15
Units
17&
18
Units
4,5,
6, &
11
Retire
12/31/20
10
FGD
FGD
Upgrade
existing
FGD
0.08
Ib/MMBt
u
0.08
Ib/MMBt
u
97%
12/31/20
13
12/31/20
15
1/31/201
1
OFA&SCR
LNB/OFA
SCR
LNB/OFA
0.14lb/MMBtu by
12/31/10
0.12lb/MMBtu by
12/31/12
0.10lb/MMBtu by
12/31/14
0.16
0.08
0.2
3/31/201
1
12/31/20
15
3/31/201
1
0.3
Ib/MMBt
u (0.015
if a
baghous
e is
installed
)
0.3
Ib/MMBt
u (0.015
if a
baghous
e is
installed
)
0.3
Ib/MMBt
u (0.015
if a
baghous
e is
installed
)
12/31/20
13
12/31/20
15
12/31/20
10
Tennessee Valley Authority
System-wide NOx Emission Caps in Tons: 100,600 in 2012, 90,791 in 201 3, 86,842 in 2014, 83,042 in 2015, 70,667 in 2016, 64,951 n2017, 52,000 in 2018 & onwards. System-wide SO2 Em ssion Caps in Tons: 285,000 in 2012, 235,518 in 2013, 228,107 in 2014,
220,631 in 2015, 175,626 in 2016, 164,257 in 2017, 121,699 in 2018, 100,000 in 2019 & onwards.
Colbert
Widows Creek
Paradise
Shawnee
Allen
Bull Run
Alabama
Alabama
Kentucky
Kentucky
Tennessee
Tennessee
Units
1-4
Units
Units
1 -6
Unit 7
Units
Units
1 &2
Units
Units
1 &4
Units
5-10
Units
1 -3
Unitl
Retire 2 unts 7/31/1 3
Retire 2 unts 7/31/1 4
Retire 2 unts 7/31/1 5
FGD
FGD
Upgrade
FGD
Wet FGD
FGD
FGD
Wet FGD
93%
1.2
1.2
6/30/201
6
12/31/15
12/31/12
Effective
Date
12/31/17
Effective
Date
12/31/18
Effective
Date
SCR
SCR
SCR
SCR
SCR
SCR
SCR
6/30/201
6
Effective
Date
Effective
Date
Effective
Date
Effective
Date
Effective
Date
12/31/17
0.3
0.3
12/31/18
Effective
Date
Shall surrender
all calendar
year NOx and
SO2
Allowances
allocated to
TVA that are
not needed for
compliance with
its own CAA
reqts.
Allocated
allowances may
be used for
TVA's own
compliance with
CAA reqts.
Shall not use
NOx or SO2
Allowances to
comply with any
requirement of
the Consent
Decree,
Nothing
prevents TVA
from purchasing
or otherwise
obtaining NOx
and S02
allowances
from other
sources for its
compliance with
CAA reqts.
TVA may sell,
bank, use,
trade, or
transfer any
NOx and SO2
"Super-
Compliance"
Allowances
resulting from
2011
http://www
/resources
/cases/civi
IE
fired.html
39
-------
Cumberland
John Sevier
Kingston
Tennessee
Tennessee
Tennessee
Units
1 &2
Units
1 -4
Units
1 &2
Units
3&4
Units
1 -10
Units
1 -9
Retire 2 Units
12/31/12 and 12/31/15
Retire 6 Units
12/31/15
Retire 4 Units
12/31/17
WetFGD
FGD
FGD
Effective
Date
12/31/15
Effective
Date
SCR
SCR
12/31/15
Effective
Date
0.3
Effective
Date
meeting
System-wide
limits. Except
that reductions
used to support
new CC/CT will
not be Super
Allowances in
that year and
thereafter.
1) Updates to the EPA Base Case 4.10 Final from EPA Base Case 4.10 include the additions of the American Municipal Power settlement, the Hoosier Energy Rural Electric Cooperative settlement, a modification to the control requirements on the Mercer plant under the
PSEG Fossil settlement, and an update to the SO2 emission modeling on Jeffrey Energy Center as part of the Westar settlement.
2) This summary table describes New Source Review settlement actions as they are represented in EPA Base Case. The settlement actions are simplified for representation in the model. This table is not intended to be a comprehensive description of all elements of the
actual settlement agreements.
3) Settlement actions for which the required emission limits will be effective by the time of the first mapped run year (before 1/1/2012) are built into the database of units used in EPA Base Case ("hardwired"). However, future actions are generally modeled as individual
constraints on emission rates in EPA Base Case, allowing the modeled economic situation to dictate whether and when a unit would opt to install controls versus retire.
4) Some control installations that are required by these NSR settlements have already been taken by the affected companies, even if deadlines specified in their settlement haven't occurred yet. Any controls that are already in place are built into EPA Base Case
5) If a settlement agreement requires installation of PM controls, then the controls are shown in this table and reflected in EPA Base Case. If settlement requires optimization or upgrade of existing PM controls, those actions are not included in EPA Base Case.
6) For units for which an FGD is modeled as an emissions constraint in EPA Base Case, EPA used the assumptions on removal efficiencies that are shown in the latest emission control technologies documentation
7) For units for which an FGD is hardwired in EPA Base Case, unless the type of FGD is specified in the settlement, EPA modeling assumes the most cost effective FGD (wet or dry) and a corresponding 95% removal efficiency for wet and 90% for dry.
8) For units for which an SCR is modeled as an emissions constraint or is hardwired in EPA Base Case, EPA assumed an emissions rate equal to 10% of the unit's uncontrolled rate, with a floor of .06 Ib/MMBtu or used the emission limit if provided.
9) The applicable low NOx burner reduction efficiencies are shown in Table A 3-1:3 in the Base Case documentation materials.
10) EPA included in EPA Base Case the requirements of the settlements as they existed on January 1, 2011.
11) Some of the NSR settlements require the retirement of SO2 allowances. For Base Case, EPA estimates the amount of allowances to be retired from these settlements and adjusted the total Title IV allowances accordingly.
40
-------
Chapter 4. Generating Resources
Table 4-13. Performance and Unit Cost Assumptions for Potential (New) Capacity from Conventional Technologies in EPA Base Case v4.10_MATS
Size (MW)
First Year
Available
Lead Time (Years)
Vintage #1
(years covered)
Availability
Advanced
Combined
Cycle
560
2015
3
2012-
2054
87%
Advanced
Combustion
Turbine
170
2012
2
2012-2054
92%
Nuclear
1350
2017
6
2012-
2054
90%
Integrated
Gasification
Combined
Cycle -
Bituminous
600
2013
4
201 2 - 2054
85%
Integrated
Gasification
Combined Cycle
-Subbituminous
600
2013
4
2012-2054
85%
Advanced
Coal with
Carbon
Capture-
Bituminous1
500
2015
4
201 2 - 2054
85%
Advanced Coal
with Carbon
Capture -
Subbituminous1
500
2015
4
201 5 - 2054
85%
Supercritical
Pulverized
Coal - Wet
Bituminous
600
2013
4
201 2 - 2054
85%
Supercritical
Pulverized
Coal - Dry
Sub-
Bituminous
600
2013
4
2012-2054
85%
Vintage #1
Heat Rate
(Btu/kWh)
Capital2
(2007$/kW)
Fixed O&M
(2007$/kW/yr)
Variable O&M
(2007$/MWh)
6,810
976
14.4
2.57
10,720
698
12.3
3.59
1 0,400
A CO-1
5,000
92.4
0.77
8,424
3,265
47.9
1.32
8,062
3,310
48.2
1.15
10,149
4,720
60.5
1.67
9,713
4,785
61.0
1.46
8,874
2,918
28.9
3.43
8,937
3,008
28.6
2.27
Notes:
1ForThe term "Advanced Coal with Carbon Capture" is used here and in the output files for EPA Base Case v.4.10_MATS to represent a variety
of technologies that are expected to provide carbon capture capabilities. These include both supercritical steam generators with carbon capture
and integrated gasification combined cycle (IGCC) with carbon capture. Although IGCC with carbon capture was used to define the cost and
performance parameters that are implemented in EPA Base Case v.4.10_MATS, projections of "Advanced Coal with Carbon Capture" in EPA
Base Case v.4.10_MATS are not limited to this technology.
2Capital cost represents overnight capital cost.
41
-------
Chapter 5: Emission Control Technologies
5.2 Nitrogen Oxides Control Technology
Table 5-7. Summary of Retrofit NOx Emission Control Performance Assumptions
Control
Performance
Assumptions
Unit Type
Percent Removal
Size Applicability
Costs (2007$)
Selective Catalytic Reduction
(SCR)
Coal
90% down to 0.06
Ib/MMBtu
Units > 25 MW
See Table 5-8*
Oil/Gas
80%
Units > 25 MW
Table 5-9*
Selective Non-Catalytic
Reduction
(SNCR)
Coal
Pulverized Coal: 35%
25% with a NOx rate floor of
0.1 Ibs/MMBtu
Fluidized Bed: 50%
with a NOx rate floor of
0.08lbs/MMBtu
Units > 25 MW
Table 5-8*
* Tables in EPA Base Case v.4.10 (EPA #430-R-10-010), August 2010 at
www.epa.gov/airmarkets/progsregs/epa-ipm/transport.html.
5.4.3 Mercury Control Capabilities
[Insert the following text at the end of section 5.4.3 as it appears in the Documentation Supplement for the
Proposed Toxics Rule (March 2011)]
Revisions to ACI VOM Cost in Base Case v.4.10 MATS: For coal units that have a FF embedded in LSD
or DSI+FF retrofits, the variable operating and maintenance (VOM) cost of activated carbon injection
(ACI) retrofits is assumed to be 81 percent lower due to the presence of pre-existing particulate controls.
• • •
5.5.1 Chlorine Content of Fuels
HCI emissions from the power sector result from the chlorine content of the coal that is combusted by
electric generating units. Data on chlorine content of coals had been collected as part EPA's 1999
"Information Collection Request for Electric Utility Steam Generating Unit Mercury Emissions Information
Collection Effort" (ICR 1999) described above in section 5.4.1 To provide the capability for EPA Base
Case v4.10_MATS to account for HCI emissions, this data had to be incorporated into the model. The
procedures used for this are presented in the updated text in section 9.1.3 below.
To account for the effect of ash chemistry on HCI emissions, the HCI content of lignite and subbituminous
coals is reduced by 75%.
In the IPM modeling runs done in support of the proposed MATS, 100 % of the coal chlorine was
assumed to convert to HCI and be present in the flue gas at the point of injection of the dry sorbent. This
was the assumption for all coal ranks and types. After MATS proposal a team of EPA and DOE engineers
and control technology specialists met regularly to further evaluate the application of DSI. One of the
outcomes of that collaboration was recognition that western sub-bituminous coal (such as that mined in
42
-------
the Powder River Basin) and lignites contain natural alkalinity in the form of non-glassy calcium oxide
(CaO) and other alkaline and alkaline earth oxides. This fly ash (classified as 'Class C' fly ash) has a
natural pH of 9 and higher and the natural alkalinity can effectively neutralize much of the HCI in the flue
gas stream prior to the primary control device.
Eastern bituminous coals, by contrast, tend to produce fly ash with lower natural alkalinity. Though
bituminous fly ash (classified as 'Class F' fly ash) may contain calcium, it tends to be present in a glassy
matrix and unavailable for acid-base neutralization reactions.
In order to assess the extent of expected natural neutralization, the 2010 ICR data was examined. It was
observed that some of the subbituminous coals contained chlorine levels in such low quantities that users
should expect to meet the HCI emission limit with no additional controls. It was also noted that some
other units burning subbituminous or lignite coals with higher levels of Cl were achieving 50-85 % HCI
control with only cold-side ESP (i.e., with no flue gas desulfurization or other acid gas control technology).
We examined the Cl content of the sub-bituminous coals that are modeled in IPM and compared those to
the ICR results. From that analysis we believe that those coals can expect to achieve approximately 75 %
natural HCI neutralization from the alkaline fly ash.
5.5.3 HCI Retrofit Emission Control Options
Table 5-20 Summary of HCI Emission Control Technology
Assumptions in EPA Base Case v4.10_PTox
(Proposed Toxics Rule)
HCI Control Technology
Options
Limestone Forced Oxidation
(LSFO) Scrubber
Lime Spray Dryer (LSD)
DrySorbent Injection (DSI)
Scrubber upgrade
adjustment
Applicability
Base case and policy case
Base case and policy case
Base case and policy case
To existing coal steam units with
FGD in policy cases analyzed for
MATS Rulemaking
All the retrofit options for HCI emission control are summarized in Table 5-20. The scrubber upgrade
adjustment was discussed above in 5.5.2. The other options are discussed in detail in the following
sections.
5.5.3.1 Wet and Dry FGD
In addition to providing SO2 reductions, wet scrubbers (Limestone Forced Oxidation, LSFO) and dry
scrubbers (Lime Spray Dryer, LSD) reduce HCI as well. For both LSFO and LSD the HCI removal rate is
assumed to be 99% with a floor of 0.0001 Ibs/MMBtu. This is summarized in columns 2-5 of Table 5-21.
43
-------
FGD Upgrade Assumptions in MATS Policy Case: In setting up the MATS policy case, all scrubbed unit
that do not currently achieve an SO2 removal rate of 94% are assigned a capital cost of $100/kW (2009$)
for an FGD upgrade that will improve their HCI removal rates to 99% and bring any unit whose SO2
removal rate was below 90% up to 90%.
Dry Scrubber Removal Assumptions for Waste Coal and Petroleum Coke Units in MATS Policy
Case: In setting up the Base Case v.4.10_MATS, waste coal and petroleum coke units without an
existing FGD were mistakenly not provided with a scrubber retrofit option. To make up for this oversight,
in run year 2015 a dry scrubber and an associated capital cost of $748/kW (applied through and FOM
adder) are assigned to these units when setting up the MATS policy case. (The $748/kW capita I cost was
calculated using the procedures described in section 5.1.1 and, illustrated in Appendix 5-1 for a 100 MW
unit with an average heat rate of the waste coal units.) The removal rates obtained by the dry FGD ( 92%
for SO2 and 99% for HCI) are incremental to existing FBC removals. In addition, petroleum coke units
with dry FGD are assigned a mercury emission modification factor (EMF) of 0.07.]
5.5.3.2 Dry Sorbent Injection
[Insert the following text at the end of section 5.5.3.2 as it appears in the Documentation Supplement for
the Proposed Toxics Rule (March 2011)]
Revisions to DSI Cost and Performance Assumptions in Base Case v.4.10 MATS: The following
additional assumptions were made with respect to DSI in the Base Case v.4.10_MATS
(a) Since fabric filters are a pre-requisite for a DSI retrofit, the DSI retrofit VOM cost incurred by units
with no pre-existing fabric filter is reduced by 35% to reflect the non-contamination of fly ash and
the resulting savings in fly ash disposal costs from the forced installation of a fabric filter.
(b) The cost of the pre-requisite fabric filter is implemented as adders to the FOM and capital cost of
the DSI installation.
5.5.4 Fabric Filter (Baghouse) Cost Development
Fabric filters are not endogenously modeled as a separate retrofit option in EPA Base Case v4.10_PTox,
but are accounted for as a cost adder where they are required for particulate matter (PM), mercury, or
HCI emission control. In EPA Base Case v4.10_PTox, an existing or new fabric filter particulate control
device is a pre-condition for installing a DSI retrofit. In the v4.10_PTox policy case any unit that was
retrofit by the model with DSI and did not have an existing fabric filter incurred the cost of installing a
fabric filter. This cost was added to the DSI costs discussed in section 5.5.3.2. This section describes
the methodology used by Sargent & Lundy to derive the cost of a fabric filter.
The engineering cost analysis is based on a pulse-jet fabric filter which collects particulate matter on a
fabric bag and uses air pulses to dislodge the particulate from the bag surface and collect it in hoppers for
removal via an ash handling system to a silo. This is a mature technology that has been operating
commercially for more than 25 years. "Baghouse" and "fabric filters" are used interchangeably to refer to
such installations.
Capital Cost: Two governing variables are used to derive the bare module capital cost of a fabric filter.
The first of these is the "air-to-cloth" (A/C) ratio. The major driver of fabric filter capital cost, the A/C ratio
is defined as the volumetric flow, (typically expressed in Actual Cubic Feet per Minute, ACFM) of flue gas
entering the baghouse divided by the areas (typically in square feet) of fabric filter cloth in the baghouse.
The lower the A/C ratio, e.g., A/C = 4.0 compared to A/C = 6.0, the greater the area of the cloth required
and the higher the cost for a given volumetric flow.
44
-------
Note: Based on public comments and engineering assessments, an air-to-cloth ratio or 4.0, rather than
6.0, was used in modeling for MATS to provide a conservative projection of the requirements and cost of
sorbent removal.
The other determinant of capital cost is the flue gas volumetric flow rate (in ACFM) which is a function of
the type of coal burned and the unit's size and heat rate.
5.6 Filterable Particulate Matter (PM) Compliance
When the MATS policy case is modeled off the v.4.10_MATS Base Case, it is assumed that all coal
burning generating units with a capacity of 25 MW or greater will comply with the filterable PM
requirements through the operation of either electrostatic precipitator (ESP) or fabric filter (FF) particulate
controls. The decision of whether an upgrade of existing controls will be needed to meet the requirement
is not modeled endogenously but supplied as an input when setting up the run.
Units with existing fabric filters are assumed to be able to meet the filterable PM compliance requirement.
For units with existing ESPs the following procedure is used to determine if they already meet the
filterable PM requirement, can meet it by one of three possible ESP upgrades, or can only meet it by
installing a FF.
First, PM emission rate data derived either from 2005 EIA Form 767 or (where available) from EPA's
2010 Information Collection Requests are compared to the applicable filterable PM compliance
requirement. If the unit's emission rate is equal to or less than the compliance requirement, adequate
controls are assumed already to be in place and no additional upgrade costs are imposed. For units that
do not meet the filterable PM compliance requirement, the incremental reduction needed (in Ibs/mmBtu)
is calculated by subtracting the filterable PM compliance standard from the reported emission rate.
Depending on the magnitude of the incremental reduction needed, the unit is assigned one of three ESP
upgrade costs (designated ESP1, ESP2, and ESPS) or the cost of a FF installation (designated ESP4), if
the required incremental reduction cannot be achieved by an ESP upgrade. Table 5-25 shows the four
levels of ESP upgrades (column 1), the key technologies included in each upgrade (column 2), trigger
points for the upgrades (column 3), the capital cost of each upgrade (column 4), and the percent increase
in collection efficiency provided by the upgrade, differentiated according to the rank (subbituminous,
bituminous, or lignite) of coal burned.
When setting up a model run, the capital costs for the ESP upgrades that are shown in Table 5-25 are
converted into annual fixed operating and maintenance (FOM) charges which are added to the other
FOM costs incurred by a particular generating unit. To obtain the FOM adder for the ESP upgrades, the
values shown in Table 5-25 are multiplied by 11.3%, the capital charge rate for environmental retrofits.
(For a discussion of all the capital charge rates in the model runs built upon the EPA base case
v.4.10_MATS, see Chapter 8 ("Financial Assumptions") in Documentation for EPA Base Case
v.4.10_MATS Using the Integrated Planning Model, August 2010, EPA #430-R-10-010.) To prevent
double counting of PM control costs, the FOM adder described here is removed if a represented
generating unit had previously had an ESP4 fabric filter upgrade, or if, in the course of a model run, was
retrofit with dry flue gas desulfurization (FGD), DSI, or ACI plus TOXECON — each of which includes
particulate controls in its capital cost.
The percentage improvements in collection efficiency shown in column 5 in Table 5-25 are additive in the
sense that the values shown in this column are added to the pre-upgrade collection efficiency to obtain
the after-upgrade collection efficiency.
5 2005 EIA Form 767 is the last year where the data was reported in the format of Ib/MMBtu, which is compatible
with this analysis. Since any changes to facilities since 2005 would likely have improved (reduced) emissions, the
use of this data is conservative. More recent 2010 ICR test data is used where available.
45
-------
Table 5-25. Electrostatic Precipitator (ESP) Upgrades as Implemented in EPA Base Case for MATS — Characteristics, Trigger Points,
Associated Costs, and Performance Improvements
Upgrade
Level
Key Technologies Employed in
Upgrade
Trigger Points for ESP
Upgrade
(Expressed in terms of
incremental reduction
needed (Ibs/mmBtu) to
meet the filterable PM
Compliance Standard)
Capital Cost
Additive Percent Improvement in
Collection Efficiency as a Result of
the Upgrade (differentiated by the
rank of coal combusted)
High Frequency transformer-rectifier
(TR) sets
> 0.0 to < 0.005
$55/kW1
0.12 for subbituminous
0.05 for bituminous
0.01 for lignite
High frequency transformer-rectifier
(TR) sets
+
New internals (rigid electrodes,
increased plate spacing, increased
plate height)
> 0.005 to < 0.01
$80/kW2
0.25 for subbituminous
0.10 for bituminous
0.02 for lignite
High frequency transformer-rectifier
(TR) sets
+
New internals (rigid electrodes,
increased plate spacing, increased
plate height)
+
Additional field
> 0.01 to < 0.02
SlOO/kW3
0.50 for subbituminous
0.20 for bituminous
0.05 for lignite
Replacement with fabric filter
(baghouse)
> 0.02
Use capital cost
equations for a
fabric filter4
(Not Applicable)
1Assumes upgrading the specific collection area (SCA) to 250 square-feet/1000 afm (actual feet per minute).
2Assumes upgrading the specific collection area (SCA) to 300 square-feet/1000 afm (actual feet per minute).
3Assumes upgrading the existing specific collection area (SCA) by 100 square-feet/1000 afm (actual feet per minute), a 20% height increase, and
additional field.
4The cost equations for fabric filters are described in Section 5.5.4 ("Fabric Filter (Baghouse) Cost Development") with calculations illustrated in
Tables 1 and 2 in Appendix 5-5 ("Example Cost Calculation Worksheets for Fabric Filters") in Documentation Supplement for EPA Base Case
v4.10_PTox - Updates for Proposed Toxics Rule (EPA #430-R-11-006). This documentation supplement is available on the web at
ww.epa.gov/airmarkets/progsregs/epa-ipm/docs/suppdoc.pdf.
5The percentage improvement due to the ESP upgrade as shown in this column is added to the pre-upgrade collection efficiency to obtain the
after-upgrade collection removal efficiency.
46
-------
Appendix 5-6 contains a complete listing of coal generating units with either cold- or hot-side ESPs but no
fabric filters. For each generating unit the table in Appendix 5-6 shows the incremental reductions
needed to meet the PM filterable compliance requirement and the corresponding ESP upgrade (if any)
assigned to the unit to enable it to meet that requirement. A filterable PM limit of 0.279 Ib/mmBtu was
used in this analysis. This value is roughly 10% below the limit in the final MATS rule, therefore resulting
in a conservative estimate of the need to upgrade existing ESPs
47
-------
Appendix 5-6. ESP Upgrade Provided to Existing Units without Fabric Filters so that They Meet Their Filterable PM Com
Plant Name
A B Brown
AES Beaver Valley
Partners Beaver Valley
AES Beaver Valley
Partners Beaver Valley
AES Beaver Valley
Partners Beaver Valley
AES Cayuga
AES Cayuga
AES Deepwater
AES Somerset LLC
Albright
Albright
Albright
Allen Steam Plant
Allen Steam Plant
Allen Steam Plant
Alloy Steam Station
Alma
Alma
Ames Electric Services
Power Plant
Ames Electric Services
Power Plant
Apache Station
Apache Station
Unit ID
2
2
3
4
1
2
AABOO
1
1
1
2
3
1
2
3
BLR4
B4
B5
7
8
2
3
State Name
Indiana
Pennsylvani
a
Pennsylvani
a
Pennsylvani
a
New York
New York
Texas
New York
West
Virginia
West
Virginia
West
Virginia
Tennessee
Tennessee
Tennessee
West
Virginia
Wisconsin
Wisconsin
Iowa
Iowa
Arizona
Arizona
UniquelD
6137 B 2
10676 B 2
10676 B 3
10676 B 4
2535 B 1
2535 B 2
10670 B AABO
01
6082 B 1
3942 B 1
3942 B 2
3942 B 3
3393 B 1
3393 B 2
3393 B 3
50012 B BLR4
4140 B B4
4140 B B5
1122 B 7
1122 B 8
160 B 2
160 B 3
Capacit
y(MW)
245
43
43
43
150
151
139
681
73
73
137
245
245
245
38
51
77
33
70
175
175
OnLineYe
ar
1986
1943
1943
1943
1955
1958
1986
1984
1952
1952
1954
1959
1959
1959
1950
1957
1960
1968
1982
1979
1979
Firing
wall
wall
wall
wall
tangential
tangential
vertical
wall
wall
wall
tangential
cyclone
cyclone
cyclone
wall
wall
wall
tangential
wall
wall
wall
Botto
m
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
wet
wet
dry
dry
dry
dry
dry
dry
dry
Dry
Scrubb
er
Installe
d
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Current
Filterable
PM
Emission
(Ibs/MMBt
u)
0.0100
0.0500
0.0700
0.0300
0.0200
0.0200
0.0100
0.0200
0.0696
0.0100
0.0500
0.0100
0.0200
0.0100
0.0400
0.0200
0.0900
0.0200
0.0200
0.0100
0.0100
Filterable
PM Limit
(Ibs/MMBt
u)
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
Complian
ce with
the
Filterable
PM Limit?
Yes
No
No
No
Yes
Yes
Yes
Yes
No
Yes
No
Yes
Yes
Yes
No
Yes
No
Yes
Yes
Yes
Yes
pliance Requirement
Final
Filterable
Emission
(Ib/MMBt
u)
0.0100
0.0279
0.0279
0.0279
0.0200
0.0200
0.0100
0.0200
0.0279
0.0100
0.0279
0.0100
0.0200
0.0100
0.0279
0.0200
0.0279
0.0200
0.0200
0.0100
0.0100
Increment
al
Filterable
Reduction
Needed
(Ib/MMBtu
)
0.0000
0.0221
0.0421
0.0021
0.0000
0.0000
0.0000
0.0000
0.0417
0.0000
0.0221
0.0000
0.0000
0.0000
0.0121
0.0000
0.0621
0.0000
0.0000
0.0000
0.0000
Level of
ESP
Upgrade
Required
to Meet
Filterable
PM
Requireme
nt
ESP-4
ESP-4
ESP-1
ESP-4
ESP-4
ESP-3
ESP-4
...
48
-------
Armstrong Power Station
Armstrong Power Station
Asbury
Asheville
Asheville
Ashtabula
Austin Northeast
Avon Lake
Avon Lake
B C Cobb
B C Cobb
B L England
B L England
Bailly
Bailly
Barry
Barry
Barry
Barry
Barry
Bay Shore
Bay Shore
Bay Shore
Belews Creek
Belews Creek
Belle River
1
2
1
1
2
7
NEPP
10
12
4
5
1
2
7
8
1
2
3
4
5
2
3
4
1
2
1
Pennsylvani
a
Pennsylvani
a
Missouri
North
Carolina
North
Carolina
Ohio
Minnesota
Ohio
Ohio
Michigan
Michigan
New Jersey
New Jersey
Indiana
Indiana
Alabama
Alabama
Alabama
Alabama
Alabama
Ohio
Ohio
Ohio
North
Carolina
North
Carolina
Michigan
3178 B 1
3178 B 2
2076 B 1
2706 B 1
2706 B 2
2835 B 7
1961 B NEPP
2836 B 10
2836 B 12
1695 B 4
1695 B 5
2378 B 1
2378 B 2
995 B 7
995 B 8
3 B 1
3 B 2
3 B 3
3 B 4
3 B 5
2878 B 2
2878 B 3
2878 B 4
8042 B 1
8042 B 2
6034 B 1
172
171
213
191
185
244
29
93
616
156
156
126
152
160
320
138
137
249
362
740
138
142
215
1115
1115
698
1958
1959
1970
1964
1971
1958
1971
1949
1970
1956
1957
1962
1964
1962
1968
1954
1954
1959
1969
1971
1959
1963
1968
1974
1975
1984
wall
wall
cyclone
wall
wall
tangential
wall
tangential
wall
tangential
tangential
cyclone
cyclone
cyclone
cyclone
tangential
tangential
tangential
tangential
tangential
vertical
wall
wall
cell
cell
wall
dry
dry
wet
dry
dry
dry
dry
dry
dry
dry
dry
wet
wet
wet
wet
dry
dry
dry
dry
dry
wet
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0400
0.0100
0.1300
0.0030
0.0036
0.0100
0.0300
0.0100
0.0200
0.1000
0.0620
0.0300
0.0300
0.0300
0.0300
0.0300
0.0400
0.0200
0.0200
0.0200
0.3200
0.3200
0.3200
0.0500
0.0200
0.0300
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
Yes
No
Yes
Yes
Yes
No
Yes
Yes
No
No
No
No
No
No
No
No
Yes
Yes
Yes
No
No
No
No
Yes
No
0.0279
0.0100
0.0279
0.0030
0.0036
0.0100
0.0279
0.0100
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0200
0.0200
0.0200
0.0279
0.0279
0.0279
0.0279
0.0200
0.0279
0.0121
0.0000
0.1021
0.0000
0.0000
0.0000
0.0021
0.0000
0.0000
0.0721
0.0341
0.0021
0.0021
0.0021
0.0021
0.0021
0.0121
0.0000
0.0000
0.0000
0.2921
0.2921
0.2921
0.0221
0.0000
0.0021
ESP-3
...
ESP-4
...
...
ESP-1
ESP-4
ESP-4
ESP-1
ESP-1
ESP-1
ESP-1
ESP-1
ESP-3
ESP-4
ESP-4
ESP-4
ESP-4
...
ESP-1
49
-------
Belle River
Big Bend
Big Bend
Big Bend
Big Bend
Big Cajun 2
Big Cajun 2
Big Cajun 2
Big Sandy
Big Sandy
Black Dog
Black Dog
Blount Street
Blount Street
Blue Valley
Boardman
Bowen
Bowen
Bowen
Bowen
Brayton Point
Bremo Bluff
Bremo Bluff
Bruce Mansfield
Buck
Buck
2
BB01
BB02
BB03
BB04
2B1
2B2
2B3
BSU1
BSU2
3
4
8
9
3
1SG
1BLR
2BLR
3BLR
4BLR
3
3
4
3
5
6
Michigan
Florida
Florida
Florida
Florida
Louisiana
Louisiana
Louisiana
Kentucky
Kentucky
Minnesota
Minnesota
Wisconsin
Wisconsin
Missouri
Oregon
Georgia
Georgia
Georgia
Georgia
Massachuse
tts
Virginia
Virginia
Pennsylvani
a
North
Carolina
North
Carolina
6034 B 2
645 B BB01
645 B BB02
645 B BB03
645 B BB04
6055 B 2B1
6055 B 2B2
6055 B 2B3
1353 B BSU1
1353 B BSU2
1904 B 3
1904 B 4
3992 B 8
3992 B 9
2132 B 3
6106 B 1SG
703 B 1BLR
703 B 2BLR
703 B 3BLR
703 B 4BLR
1619 B 3
3796 B 3
3796 B 4
6094 B 3
2720 B 5
2720 B 6
698
391
391
364
447
580
575
588
259
789
94
165
49
48
51
585
713
718
902
929
607
71
156
830
38
38
1985
1970
1973
1976
1985
1981
1982
1983
1963
1969
1955
1960
1957
1961
1965
1980
1971
1972
1974
1975
1969
1950
1958
1979
1941
1941
wall
wall
wall
wall
tangential
wall
wall
wall
wall
wall
wall
wall
wall
wall
tangential
wall
tangential
tangential
tangential
tangential
wall
wall
wall
wall
tangential
tangential
dry
wet
wet
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0100
0.0300
0.0200
0.0200
0.0100
0.0200
0.0200
0.0200
0.0300
0.0300
0.0400
0.0400
0.1200
0.0900
0.0300
0.0100
0.0800
0.0800
0.0500
0.0500
0.0100
0.0200
0.0200
0.0800
0.0400
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
Yes
No
Yes
Yes
Yes
Yes
Yes
Yes
No
No
No
No
No
No
No
Yes
No
No
No
No
Yes
Yes
Yes
No
No
Yes
0.0100
0.0279
0.0200
0.0200
0.0100
0.0200
0.0200
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0100
0.0279
0.0279
0.0279
0.0279
0.0100
0.0200
0.0200
0.0279
0.0279
0.0200
0.0000
0.0021
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0021
0.0021
0.0121
0.0121
0.0921
0.0621
0.0021
0.0000
0.0521
0.0521
0.0221
0.0221
0.0000
0.0000
0.0000
0.0521
0.0121
0.0000
ESP-1
___
ESP-1
ESP-1
ESP-3
ESP-3
ESP-4
ESP-4
ESP-1
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-3
...
50
-------
Buck
Buck
Buck
Bull Run
Burlington
C D Mclntosh Jr
Canadys Steam
Canadys Steam
Cane Run
Cane Run
Cane Run
Cape Fear
Cape Fear
Carbon
Carbon
Cardinal
Cardinal
Cardinal
Cayuga
Cayuga
Chalk Point LLC
Chalk Point LLC
Chamois
Charles R Lowman
Charles R Lowman
Charles R Lowman
7
8
9
1
1
3
CAN1
CAN2
4
5
6
5
6
1
2
1
2
3
1
2
1
2
2
1
2
3
North
Carolina
North
Carolina
North
Carolina
Tennessee
Iowa
Florida
South
Carolina
South
Carolina
Kentucky
Kentucky
Kentucky
North
Carolina
North
Carolina
Utah
Utah
Ohio
Ohio
Ohio
Indiana
Indiana
Maryland
Maryland
Missouri
Alabama
Alabama
Alabama
2720 B 7
2720 B 8
2720 B 9
3396 B 1
1104 B 1
676 B 3
3280 B CAN1
3280 B CAN2
1363 B 4
1363 B 5
1363 B 6
2708 B 5
2708 B 6
3644 B 1
3644 B 2
2828 B 1
2828 B 2
2828 B 3
1001 B 1
1001 B 2
1571 B 1
1571 B 2
2169 B 2
56 B 1
56 B 2
56 B 3
38
128
128
881
209
340
105
116
155
168
240
144
172
67
105
600
600
621
479
466
341
342
49
85
238
238
1942
1953
1953
1967
1968
1982
1962
1964
1962
1966
1969
1956
1958
1954
1957
1967
1967
1977
1970
1972
1964
1965
1960
1969
1979
1980
tangential
tangential
tangential
tangential
tangential
wall
tangential
tangential
wall
wall
tangential
tangential
tangential
tangential
tangential
cell
cell
wall
tangential
tangential
wall
wall
cyclone
wall
wall
wall
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0300
0.0200
0.0300
0.0100
0.1000
0.0736
0.2600
0.0140
0.0257
0.0113
0.0700
0.0700
0.0600
0.0200
0.0600
0.0114
0.0114
0.0114
0.0700
0.0700
0.0200
0.0200
0.0900
0.0100
0.0300
0.0300
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
Yes
No
Yes
No
No
No
Yes
Yes
Yes
No
No
No
Yes
No
Yes
Yes
Yes
No
No
Yes
Yes
No
Yes
No
No
0.0279
0.0200
0.0279
0.0100
0.0279
0.0279
0.0279
0.0140
0.0257
0.0113
0.0279
0.0279
0.0279
0.0200
0.0279
0.0114
0.0114
0.0114
0.0279
0.0279
0.0200
0.0200
0.0279
0.0100
0.0279
0.0279
0.0021
0.0000
0.0021
0.0000
0.0721
0.0457
0.2321
0.0000
0.0000
0.0000
0.0421
0.0421
0.0321
0.0000
0.0321
0.0000
0.0000
0.0000
0.0421
0.0421
0.0000
0.0000
0.0621
0.0000
0.0021
0.0021
ESP-1
...
ESP-1
ESP-4
ESP-4
ESP-4
...
ESP-4
ESP-4
ESP-4
___
ESP-4
ESP-4
___
ESP-4
ESP-1
ESP-1
51
-------
Chesapeake
Chesapeake
Chesapeake
Chesapeake
Chesterfield
Chesterfield
Chesterfield
Cliffside
Cliffside
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clinch River
Clinch River
Clinch River
Coal Creek
Coal Creek
Coffeen
Coffeen
Colbert
Colbert
Colbert
Colbert
1
2
3
4
3
4
5
5
6
1
2
3
4
5
6
1
2
3
1
2
01
02
1
2
3
4
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
Virginia
North
Carolina
North
Carolina
Indiana
Indiana
Indiana
Indiana
Indiana
Indiana
Virginia
Virginia
Virginia
North
Dakota
North
Dakota
Illinois
Illinois
Alabama
Alabama
Alabama
Alabama
3803 B 1
3803 B 2
3803 B 3
3803 B 4
3797 B 3
3797 B 4
3797 B 5
2721 B 5
2721 B 6
983 B 1
983 B 2
983 B 3
983 B 4
983 B 5
983 B 6
3775 B 1
3775 B 2
3775 B 3
6030 B 1
6030 B 2
861 B 01
861 B 02
47 B 1
47 B 2
47 B 3
47 B 4
111
111
155
216
98
164
310
550
800
214
214
214
214
214
214
234
234
234
554
560
335
551
177
177
177
173
1953
1954
1959
1962
1952
1960
1964
1972
2011
1955
1955
1955
1955
1955
1956
1958
1958
1961
1979
1981
1965
1972
1955
1955
1955
1955
tangential
tangential
wall
tangential
tangential
tangential
tangential
tangential
tangential
wall
wall
wall
wall
wall
wall
vertical
vertical
vertical
tangential
tangential
cyclone
cyclone
wall
wall
wall
wall
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
wet
wet
wet
wet
wet
dry
dry
dry
dry
dry
wet
wet
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0100
0.0100
0.0300
0.0100
0.0300
0.0200
0.0300
0.0200
0.0300
0.0100
0.0100
0.0100
0.0500
0.0500
0.0500
0.0531
0.0300
0.0300
0.0047
0.0035
0.0600
0.0600
0.0100
0.0500
0.0114
0.0240
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
Yes
Yes
No
Yes
No
Yes
No
Yes
No
Yes
Yes
Yes
No
No
No
No
No
No
Yes
Yes
No
No
Yes
No
Yes
Yes
0.0100
0.0100
0.0279
0.0100
0.0279
0.0200
0.0279
0.0200
0.0279
0.0100
0.0100
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0047
0.0035
0.0279
0.0279
0.0100
0.0279
0.0114
0.0240
0.0000
0.0000
0.0021
0.0000
0.0021
0.0000
0.0021
0.0000
0.0021
0.0000
0.0000
0.0000
0.0221
0.0221
0.0221
0.0252
0.0021
0.0021
0.0000
0.0000
0.0321
0.0321
0.0000
0.0221
0.0000
0.0000
ESP-1
ESP-1
ESP-1
...
ESP-1
ESP-4
ESP-4
ESP-4
ESP-4
ESP-1
ESP-1
...
ESP-4
ESP-4
ESP-4
52
-------
Colbert
Columbia
Columbia
Conemaugh
Conemaugh
Conesville
Conesville
Conesville
Conesville
Cooper
Cooper
Coronado
Coronado
Crawford
Crawford
Crist
Crist
Crist
Crist
Cross
Cross
Cross
Cross
Crystal River
Crystal River
Crystal River
5
1
2
1
2
3
4
5
6
1
2
U1B
U2B
7
8
4
5
6
7
1
2
3
4
1
2
4
Alabama
Wisconsin
Wisconsin
Pennsylvani
a
Pennsylvani
a
Ohio
Ohio
Ohio
Ohio
Kentucky
Kentucky
Arizona
Arizona
Illinois
Illinois
Florida
Florida
Florida
Florida
South
Carolina
South
Carolina
South
Carolina
South
Carolina
Florida
Florida
Florida
47 B 5
8023 B 1
8023 B 2
3118 B 1
3118 B 2
2840 B 3
2840 B 4
2840 B 5
2840 B 6
1384 B 1
1384 B 2
6177 B U1B
6177 B U2B
867 B 7
867 B 8
641 B 4
641 B 5
641 B 6
641 B 7
130 B 1
130 B 2
130 B 3
130 B 4
628 B 1
628 B 2
628 B 4
459
546
551
850
850
165
780
375
375
116
221
395
388
212
318
78
78
300
472
620
540
580
600
379
491
718
1965
1975
1978
1970
1971
1962
1973
1976
1978
1965
1969
1979
1980
1958
1961
1959
1961
1970
1973
1995
1984
2007
2009
1966
1969
1982
wall
tangential
tangential
tangential
tangential
wall
tangential
tangential
tangential
wall
wall
wall
wall
tangential
tangential
tangential
tangential
wall
wall
wall
tangential
wall
wall
tangential
tangential
wall
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0200
0.0400
0.0300
0.0100
0.0200
0.0491
0.0300
0.0300
0.0300
0.1700
0.1700
0.0100
0.0100
0.0570
0.0560
0.0100
0.0100
0.0100
0.0100
0.0140
0.0160
0.0300
0.0300
0.1470
0.0100
0.1000
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
Yes
No
No
Yes
Yes
No
No
No
No
No
No
Yes
Yes
No
No
Yes
Yes
Yes
Yes
Yes
Yes
No
No
No
Yes
No
0.0200
0.0279
0.0279
0.0100
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0100
0.0100
0.0279
0.0279
0.0100
0.0100
0.0100
0.0100
0.0140
0.0160
0.0279
0.0279
0.0279
0.0100
0.0279
0.0000
0.0121
0.0021
0.0000
0.0000
0.0212
0.0021
0.0021
0.0021
0.1421
0.1421
0.0000
0.0000
0.0291
0.0281
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0021
0.0021
0.1191
0.0000
0.0721
ESP-3
ESP-1
...
ESP-4
ESP-1
ESP-1
ESP-1
ESP-4
ESP-4
ESP-4
ESP-4
___
...
ESP-1
ESP-1
ESP-4
ESP-4
53
-------
Crystal River
Cumberland
Cumberland
D B Wilson
Dale
Dale
Dale
Dale
Dallman
Dallman
Dallman
Dan E Karn
Dan E Karn
Danskammer Generating
Station
Danskammer Generating
Station
Dave Johnston
Dave Johnston
Dolet Hills
Dolphus M Grainger
Dolphus M Grainger
Dubuque
Dubuque
Duck Creek
E C Gaston
E C Gaston
E C Gaston
5
1
2
W1
1
2
3
4
31
32
33
1
2
3
4
BW41
BW42
1
1
2
1
5
1
1
4
5
Florida
Tennessee
Tennessee
Kentucky
Kentucky
Kentucky
Kentucky
Kentucky
Illinois
Illinois
Illinois
Michigan
Michigan
New York
New York
Wyoming
Wyoming
Louisiana
South
Carolina
South
Carolina
Iowa
Iowa
Illinois
Alabama
Alabama
Alabama
628 B 5
3399 B 1
3399 B 2
6823 B W1
1385 B 1
1385 B 2
1385 B 3
1385 B 4
963 B 31
963 B 32
963 B 33
1702 B 1
1702 B 2
2480 B 3
2480 B 4
4158 B BW41
4158 B BW42
51 B 1
3317 B 1
3317 B 2
1046 B 1
1046 B 5
6016 B 1
26 B 1
26 B 4
26 B 5
717
1232
1233
420
27
27
75
75
86
87
199
255
260
133
236
106
106
650
85
85
35
30
335
254
256
849
1984
1973
1973
1986
1954
1954
1957
1960
1968
1972
1978
1959
1961
1987
1987
1959
1961
1986
1966
1966
1959
1952
1976
1960
1962
1974
wall
cell
cell
wall
wall
wall
wall
wall
cyclone
cyclone
tangential
tangential
wall
tangential
tangential
wall
wall
wall
wall
wall
wall
wall
wall
wall
wall
tangential
dry
dry
dry
dry
dry
dry
dry
dry
wet
wet
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0200
0.0100
0.0100
0.0100
0.0700
0.0700
0.1300
0.1300
0.0200
0.0200
0.1000
0.0100
0.0400
0.0200
0.0200
0.0500
0.0100
0.0300
0.3600
0.1300
0.0500
0.0500
0.0033
0.0100
0.0200
0.0300
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
Yes
Yes
Yes
Yes
No
No
No
No
Yes
Yes
No
Yes
No
Yes
Yes
No
Yes
No
No
No
No
No
Yes
Yes
Yes
No
0.0200
0.0100
0.0100
0.0100
0.0279
0.0279
0.0279
0.0279
0.0200
0.0200
0.0279
0.0100
0.0279
0.0200
0.0200
0.0279
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0033
0.0100
0.0200
0.0279
0.0000
0.0000
0.0000
0.0000
0.0421
0.0421
0.1021
0.1021
0.0000
0.0000
0.0721
0.0000
0.0121
0.0000
0.0000
0.0221
0.0000
0.0021
0.3321
0.1021
0.0221
0.0221
0.0000
0.0000
0.0000
0.0021
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-3
...
ESP-4
ESP-1
ESP-4
ESP-4
ESP-4
ESP-4
ESP-1
54
-------
E D Edwards
E D Edwards
E D Edwards
E W Brown
E W Brown
E W Brown
Eagle Valley
Eagle Valley
Eagle Valley
Eagle Valley
Earl F Wisdom
East Bend
Eastlake
Eastlake
Eastlake
Eastlake
Eastlake
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Edge Moor
Edge Moor
Edgewater
Edgewater
1
2
3
1
2
3
3
4
5
6
1
2
1
2
3
4
5
1
2
3
4
5
6
3
4
3
4
Illinois
Illinois
Illinois
Kentucky
Kentucky
Kentucky
Indiana
Indiana
Indiana
Indiana
Iowa
Kentucky
Ohio
Ohio
Ohio
Ohio
Ohio
Michigan
Michigan
Michigan
Michigan
Michigan
Michigan
Delaware
Delaware
Wisconsin
Wisconsin
856 B 1
856 B 2
856 B 3
1355 B 1
1355 B 2
1355 B 3
991 B 3
991 B 4
991 B 5
991 B 6
1217 B 1
6018 B 2
2837 B 1
2837 B 2
2837 B 3
2837 B 4
2837 B 5
1831 B 1
1831 B 2
1831 B 3
1831 B 4
1831 B 5
1831 B 6
593 B 3
593 B 4
4050 B 3
4050 B 4
112
273
364
92
158
420
43
56
62
99
38
600
132
132
132
240
597
40
42
41
69
69
67
86
174
76
321
1960
1968
1972
1957
1963
1971
1951
1953
1953
1956
1960
1981
1953
1953
1954
1956
1972
1954
1958
1961
1964
1968
1970
1957
1966
1951
1969
wall
wall
wall
wall
tangential
tangential
tangential
tangential
tangential
tangential
wall
wall
tangential
tangential
tangential
tangential
wall
wall
tangential
tangential
wall
wall
wall
tangential
tangential
cyclone
cyclone
dry
dry
dry
dry
dry
dry
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
wet
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
1
0
0
0.1300
0.0700
0.0400
0.1400
0.0200
0.0200
0.0500
0.0500
0.0800
0.0800
0.0200
0.0087
0.0057
0.0100
0.0056
0.0200
0.0200
0.1000
0.0300
0.1400
0.0400
0.0400
0.0400
0.0500
0.0500
0.0500
0.0400
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
No
No
No
Yes
Yes
No
No
No
No
Yes
Yes
Yes
Yes
Yes
Yes
Yes
No
No
No
No
No
No
No
No
No
No
0.0279
0.0279
0.0279
0.0279
0.0200
0.0200
0.0279
0.0279
0.0279
0.0279
0.0200
0.0087
0.0057
0.0100
0.0056
0.0200
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.1021
0.0421
0.0121
0.1121
0.0000
0.0000
0.0221
0.0221
0.0521
0.0521
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0721
0.0021
0.1121
0.0121
0.0121
0.0121
0.0221
0.0221
0.0221
0.0121
ESP-4
ESP-4
ESP-3
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-1
ESP-4
ESP-3
ESP-3
ESP-3
ESP-4
ESP-3
55
-------
Edgewater
Elmer Smith
Elmer Smith
Elrama
Elrama
Elrama
Elrama
Endicott Station
Erickson Station
Fair Station
Fayette Power Project
Fayette Power Project
Fayette Power Project
Fisk Street
Flint Creek
Fort Martin Power Station
Fort Martin Power Station
Frank E Ratts
Frank E Ratts
G F Weaton Power Station
G F Weaton Power Station
GG Allen
GG Allen
GG Allen
GG Allen
5
1
2
1
2
3
4
1
1
2
1
2
3
19
1
1
2
1SG1
2SG1
BLR1
BLR2
1
2
3
4
Wisconsin
Kentucky
Kentucky
Pennsylvani
a
Pennsylvani
a
Pennsylvani
a
Pennsylvani
a
Michigan
Michigan
Iowa
Texas
Texas
Texas
Illinois
Arkansas
West
Virginia
West
Virginia
Indiana
Indiana
Pennsylvani
a
Pennsylvani
a
North
Carolina
North
Carolina
North
Carolina
North
Carolina
4050 B 5
1374 B 1
1374 B 2
3098 B 1
3098 B 2
3098 B 3
3098 B 4
4259 B 1
1832 B 1
1218 B 2
6179 B 1
6179 B 2
6179 B 3
886 B 19
6138 B 1
3943 B 1
3943 B 2
1043 B 1SG1
1043 B 2SG1
50130 B BLR1
50130 B BLR2
2718 B 1
2718 B 2
2718 B 3
2718 B 4
412
130
257
93
93
103
171
55
152
41
590
590
445
325
528
545
547
122
121
56
56
162
162
260
275
1985
1964
1974
1952
1953
1952
1952
1982
1973
1967
1979
1980
1988
1959
1978
1967
1968
1970
1970
1957
1957
1957
1957
1959
1960
wall
cyclone
tangential
vertical
vertical
vertical
wall
wall
wall
wall
tangential
tangential
tangential
tangential
wall
tangential
wall
wall
wall
tangential
tangential
tangential
tangential
tangential
tangential
dry
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0300
0.0147
0.0147
0.0184
0.0184
0.0184
0.0184
1 .7300
0.0100
0.0300
0.0300
0.0300
0.0300
0.0780
0.0300
0.0500
0.0500
0.3400
0.3000
0.0200
0.0100
0.0400
0.1400
0.0041
0.0041
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
Yes
Yes
Yes
Yes
Yes
Yes
No
Yes
No
No
No
No
No
No
No
No
No
No
Yes
Yes
No
No
Yes
Yes
0.0279
0.0147
0.0147
0.0184
0.0184
0.0184
0.0184
0.0279
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0200
0.0100
0.0279
0.0279
0.0041
0.0041
0.0021
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
1 .7021
0.0000
0.0021
0.0021
0.0021
0.0021
0.0501
0.0021
0.0221
0.0221
0.3121
0.2721
0.0000
0.0000
0.0121
0.1121
0.0000
0.0000
ESP-1
...
...
ESP-4
ESP-1
ESP-1
ESP-1
ESP-1
ESP-4
ESP-1
ESP-4
ESP-4
ESP-4
ESP-4
...
...
ESP-3
ESP-4
...
...
56
-------
GG Allen
Gadsden
Gadsden
Gallatin
Gallatin
Gallatin
Gallatin
General James M Gavin
General James M Gavin
George Neal North
George Neal North
George Neal North
George Neal South
Ghent
Ghent
Ghent
Ghent
Gibbons Creek
Gibson
Gibson
Gibson
Gibson
Gibson
Glen Lyn
Glen Lyn
Glen Lyn
Gorgas
5
1
2
1
2
3
4
1
2
1
2
3
4
1
2
3
4
1
1
2
3
4
5
51
52
6
10
North
Carolina
Alabama
Alabama
Tennessee
Tennessee
Tennessee
Tennessee
Ohio
Ohio
Iowa
Iowa
Iowa
Iowa
Kentucky
Kentucky
Kentucky
Kentucky
Texas
Indiana
Indiana
Indiana
Indiana
Indiana
Virginia
Virginia
Virginia
Alabama
2718 B 5
7 B 1
7 B 2
3403 B 1
3403 B 2
3403 B 3
3403 B 4
8102 B 1
8102 B 2
1091 B 1
1091 B 2
1091 B 3
7343 B 4
1356 B 1
1356 B 2
1356 B 3
1356 B 4
6136 B 1
6113 B 1
6113 B 2
6113 B 3
6113 B 4
6113 B 5
3776 B 51
3776 B 52
3776 B 6
8 B 10
265
64
66
222
222
260
260
1310
1300
135
300
515
632
468
463
472
472
462
621
619
619
622
620
45
45
235
681
1961
1949
1949
1956
1957
1959
1959
1974
1975
1964
1972
1975
1979
1973
1977
1981
1984
1983
1975
1975
1978
1979
1982
1944
1944
1957
1972
tangential
tangential
tangential
tangential
tangential
tangential
tangential
cell
cell
cyclone
wall
wall
wall
tangential
tangential
wall
wall
tangential
wall
wall
wall
wall
wall
tangential
tangential
wall
tangential
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0400
0.0300
0.0400
0.0100
0.0393
0.0100
0.0100
0.0300
0.0300
0.1700
0.2300
0.0300
0.0300
0.0600
0.0700
0.0300
0.0200
0.3000
0.0067
0.0038
0.0400
0.0500
0.0900
0.0300
0.0300
0.0300
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
No
No
Yes
No
Yes
Yes
No
No
No
No
No
No
No
No
No
Yes
No
Yes
Yes
No
No
No
No
No
No
Yes
0.0279
0.0279
0.0279
0.0100
0.0279
0.0100
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0200
0.0279
0.0067
0.0038
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0200
0.0121
0.0021
0.0121
0.0000
0.0114
0.0000
0.0000
0.0021
0.0021
0.1421
0.2021
0.0021
0.0021
0.0321
0.0421
0.0021
0.0000
0.2721
0.0000
0.0000
0.0121
0.0221
0.0621
0.0021
0.0021
0.0021
0.0000
ESP-3
ESP-1
ESP-3
ESP-3
ESP-1
ESP-1
ESP-4
ESP-4
ESP-1
ESP-1
ESP-4
ESP-4
ESP-1
ESP-4
ESP-3
ESP-4
ESP-4
ESP-1
ESP-1
ESP-1
57
-------
Gorgas
Gorgas
Gorgas
Gorgas
GRDA
GRDA
Green River
Green River
Greene County
Greene County
H B Robinson
H L Spurlock
H L Spurlock
Hamilton
Hammond
Hammond
Hammond
Hammond
Harbor Beach
Harding Street
Harding Street
Harding Street
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Harrington
6
7
8
9
1
2
4
5
1
2
1
1
2
8
1
2
3
4
1
50
60
70
1
2
3
4
061 B
Alabama
Alabama
Alabama
Alabama
Oklahoma
Oklahoma
Kentucky
Kentucky
Alabama
Alabama
South
Carolina
Kentucky
Kentucky
Ohio
Georgia
Georgia
Georgia
Georgia
Michigan
Indiana
Indiana
Indiana
Georgia
Georgia
Georgia
Georgia
Texas
8 B 6
8 B 7
8 B 8
8 B 9
165 B 1
165 B 2
1357 B 4
1357 B 5
10 B 1
10 B 2
3251 B 1
6041 B 1
6041 B 2
2917 B 8
708 B 1
708 B 2
708 B 3
708 B 4
1731 B 1
990 B 50
990 B 60
990 B 70
709 B 1
709 B 2
709 B 3
709 B 4
6193 B 061 B
108
109
163
173
490
520
68
95
254
243
176
315
509
33
112
112
112
510
103
109
109
429
261
319
499
497
347
1951
1952
1956
1958
1982
1986
1954
1959
1965
1966
1960
1977
1981
1964
1954
1954
1955
1970
1968
1958
1961
1973
1965
1967
1968
1969
1976
wall
wall
tangential
tangential
wall
wall
wall
wall
wall
wall
tangential
wall
tangential
wall
wall
wall
wall
wall
wall
tangential
tangential
tangential
cell
wall
cell
cell
tangential
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0600
0.0300
0.0100
0.0200
0.0400
0.0200
0.0900
0.0600
0.0140
0.0160
0.0800
0.0065
0.0065
0.0400
0.0430
0.0430
0.0430
0.0190
0.0900
0.0049
0.0021
0.0168
0.0100
0.0100
0.0500
0.0500
0.0400
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
No
Yes
Yes
No
Yes
No
No
Yes
Yes
No
Yes
Yes
No
No
No
No
Yes
No
Yes
Yes
Yes
Yes
Yes
No
No
No
0.0279
0.0279
0.0100
0.0200
0.0279
0.0200
0.0279
0.0279
0.0140
0.0160
0.0279
0.0065
0.0065
0.0279
0.0279
0.0279
0.0279
0.0190
0.0279
0.0049
0.0021
0.0168
0.0100
0.0100
0.0279
0.0279
0.0279
0.0321
0.0021
0.0000
0.0000
0.0121
0.0000
0.0621
0.0321
0.0000
0.0000
0.0521
0.0000
0.0000
0.0121
0.0151
0.0151
0.0151
0.0000
0.0621
0.0000
0.0000
0.0000
0.0000
0.0000
0.0221
0.0221
0.0121
ESP-4
ESP-1
ESP-3
ESP-4
ESP-4
ESP-4
ESP-3
ESP-3
ESP-3
ESP-3
ESP-4
ESP-4
ESP-4
ESP-3
58
-------
Harrison Power Station
Harrison Power Station
Harrison Power Station
Hatfields Ferry Power
Station
Hatfields Ferry Power
Station
Hatfields Ferry Power
Station
Herbert A Wagner
Herbert A Wagner
HMP&L Station Two
Henderson
HMP&L Station Two
Henderson
Homer City Station
Homer City Station
Homer City Station
Hoot Lake
Hoot Lake
Hugo
Hunter
Hunter
Hutsonville
Hutsonville
Independence
Independence
J B Sims
J C Weadock
J C Weadock
1
2
3
1
2
3
2
3
H1
H2
1
2
3
2
3
1
1
2
05
06
1
2
3
7
8
West
Virginia
West
Virginia
West
Virginia
Pennsylvani
a
Pennsylvani
a
Pennsylvani
a
Maryland
Maryland
Kentucky
Kentucky
Pennsylvani
a
Pennsylvani
a
Pennsylvani
a
Minnesota
Minnesota
Oklahoma
Utah
Utah
Illinois
Illinois
Arkansas
Arkansas
Michigan
Michigan
Michigan
3944 B 1
3944 B 2
3944 B 3
3179 B 1
3179 B 2
3179 B 3
1554 B 2
1554 B 3
1382 B H1
1382 B H2
3122 B 1
3122 B 2
3122 B 3
1943 B 2
1943 B 3
6772 B 1
6165 B 1
6165 B 2
863 B 05
863 B 06
6641 B 1
6641 B 2
1825 B 3
1720 B 7
1720 B 8
643
633
642
523
523
523
135
324
151
157
612
606
641
60
84
440
430
430
76
77
836
842
73
151
151
1972
1973
1974
1969
1970
1971
1959
1966
1973
1974
1969
1970
1977
1959
1964
1982
1978
1980
1953
1954
1983
1985
1983
1955
1958
wall
wall
wall
cell
cell
cell
wall
wall
wall
wall
wall
wall
wall
tangential
wall
wall
tangential
tangential
tangential
tangential
tangential
tangential
wall
tangential
tangential
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
wet
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0200
0.0200
0.0100
0.0323
0.0200
0.0200
0.0017
0.0100
0.0700
0.0700
0.0300
0.0300
0.0600
0.0812
0.0812
0.0100
0.0100
0.0300
0.0300
0.0300
0.0400
0.0400
0.0300
0.0500
0.0400
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
Yes
Yes
Yes
No
Yes
Yes
Yes
Yes
No
No
No
No
No
No
No
Yes
Yes
No
No
No
No
No
No
No
No
0.0200
0.0200
0.0100
0.0279
0.0200
0.0200
0.0017
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0100
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0000
0.0000
0.0000
0.0044
0.0000
0.0000
0.0000
0.0000
0.0421
0.0421
0.0021
0.0021
0.0321
0.0533
0.0533
0.0000
0.0000
0.0021
0.0021
0.0021
0.0121
0.0121
0.0021
0.0221
0.0121
...
...
ESP-1
...
ESP-4
ESP-4
ESP-1
ESP-1
ESP-4
ESP-4
ESP-4
ESP-1
ESP-1
ESP-1
ESP-3
ESP-3
ESP-1
ESP-4
ESP-3
59
-------
J E Corette Plant
J H Campbell
J H Campbell
J H Campbell
J M Stuart
J M Stuart
J M Stuart
J M Stuart
J R Whiting
J R Whiting
J R Whiting
Jack Watson
Jack Watson
James De Young
James H Miller Jr
James H Miller Jr
James H Miller Jr
James H Miller Jr
James River Power
Station
James River Power
Station
James River Power
Station
Jefferies
Jefferies
Jeffrey Energy Center
Jeffrey Energy Center
Jeffrey Energy Center
2
1
2
3
1
2
3
4
1
2
3
4
5
5
1
2
3
4
3
4
5
3
4
1
2
3
Montana
Michigan
Michigan
Michigan
Ohio
Ohio
Ohio
Ohio
Michigan
Michigan
Michigan
Mississippi
Mississippi
Michigan
Alabama
Alabama
Alabama
Alabama
Missouri
Missouri
Missouri
South
Carolina
South
Carolina
Kansas
Kansas
Kansas
2187 B 2
1710 B 1
1710 B 2
1710 B 3
2850 B 1
2850 B 2
2850 B 3
2850 B 4
1723 B 1
1723 B 2
1723 B 3
2049 B 4
2049 B 5
1830 B 5
6002 B 1
6002 B 2
6002 B 3
6002 B 4
2161 B 3
2161 B 4
2161 B 5
3319 B 3
3319 B 4
6068 B 1
6068 B 2
6068 B 3
158
260
353
822
597
597
597
597
102
102
124
230
476
27
674
687
687
688
41
56
97
153
153
726
727
727
1968
1962
1967
1980
1971
1970
1972
1974
1952
1952
1953
1968
1973
1969
1978
1985
1989
1991
1960
1964
1970
1970
1970
1978
1980
1983
tangential
tangential
wall
wall
cell
cell
cell
cell
wall
wall
wall
wall
wall
wall
wall
wall
wall
wall
wall
wall
wall
wall
wall
tangential
tangential
tangential
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.2700
0.0111
0.0111
0.0100
0.0500
0.0500
0.0700
0.0200
0.1600
0.1400
0.1300
0.0400
0.0400
0.0300
0.0100
0.0200
0.0100
0.0040
0.1100
0.1000
0.0113
0.0000
0.0000
0.0600
0.0300
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
Yes
Yes
Yes
No
No
No
Yes
No
No
No
No
No
No
Yes
Yes
Yes
Yes
No
No
Yes
Yes
Yes
No
No
Yes
0.0279
0.0111
0.0111
0.0100
0.0279
0.0279
0.0279
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0100
0.0200
0.0100
0.0040
0.0279
0.0279
0.0113
0.0000
0.0000
0.0279
0.0279
0.0200
0.2421
0.0000
0.0000
0.0000
0.0221
0.0221
0.0421
0.0000
0.1321
0.1121
0.1021
0.0121
0.0121
0.0021
0.0000
0.0000
0.0000
0.0000
0.0821
0.0721
0.0000
0.0000
0.0000
0.0321
0.0021
0.0000
ESP-4
___
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-3
ESP-3
ESP-1
ESP-4
ESP-4
...
...
ESP-4
ESP-1
60
-------
Jim Bridger
Jim Bridger
Jim Bridger
Jim Bridger
John E Amos
John E Amos
John E Amos
John Sevier
John Sevier
John Sevier
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Joliet 29
Joliet 29
Joliet 29
Joliet 29
Joliet 9
Joppa Steam
Joppa Steam
BW71
BW72
BW73
BW74
1
2
3
2
3
4
1
10
2
3
4
5
6
7
8
9
71
72
81
82
5
1
2
Wyoming
Wyoming
Wyoming
Wyoming
West
Virginia
West
Virginia
West
Virginia
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Illinois
Illinois
Illinois
Illinois
Illinois
Illinois
Illinois
8066 B BW71
8066 B BW72
8066 B BW73
8066 B BW74
3935 B 1
3935 B 2
3935 B 3
3405 B 2
3405 B 3
3405 B 4
3406 B 1
3406 B 10
3406 B 2
3406 B 3
3406 B 4
3406 B 5
3406 B 6
3406 B 7
3406 B 8
3406 B 9
384 B 71
384 B 72
384 B 81
384 B 82
874 B 5
887 B 1
887 B 2
530
530
530
530
800
789
1282
176
176
176
106
141
106
106
106
106
106
141
141
141
258
258
258
258
311
167
167
1974
1975
1976
1979
1971
1972
1973
1955
1956
1957
1951
1959
1951
1952
1952
1952
1953
1958
1959
1959
1965
1965
1965
1965
1959
1953
1953
tangential
tangential
tangential
tangential
wall
wall
cell
tangential
tangential
tangential
tangential
wall
tangential
tangential
tangential
tangential
tangential
wall
wall
wall
tangential
tangential
tangential
tangential
cyclone
tangential
tangential
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0100
0.0100
0.0200
0.0100
0.0300
0.0300
0.0300
0.0100
0.0100
0.0100
0.0200
0.0200
0.0200
0.0200
0.0200
0.0200
0.0200
0.0200
0.0200
0.0200
0.0650
0.0650
0.0490
0.0490
0.0588
0.0200
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
Yes
Yes
Yes
Yes
No
No
No
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
No
No
No
No
No
Yes
Yes
0.0100
0.0100
0.0200
0.0100
0.0279
0.0279
0.0279
0.0100
0.0100
0.0100
0.0200
0.0200
0.0200
0.0200
0.0200
0.0200
0.0200
0.0200
0.0200
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0200
0.0200
0.0000
0.0000
0.0000
0.0000
0.0021
0.0021
0.0021
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0371
0.0371
0.0211
0.0211
0.0309
0.0000
0.0000
ESP-1
ESP-1
ESP-1
___
___
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
___
___
61
-------
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Kammer
Kammer
Kammer
Kanawha River
Kanawha River
Kenneth C Coleman
Kenneth C Coleman
Kenneth C Coleman
Keystone
Keystone
Killen Station
Kincaid Generation LLC
Kincaid Generation LLC
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
3
4
5
6
1
2
3
1
2
C1
C2
C3
1
2
2
1
2
1
2
3
4
5
6
7
8
9
Illinois
Illinois
Illinois
Illinois
West
Virginia
West
Virginia
West
Virginia
West
Virginia
West
Virginia
Kentucky
Kentucky
Kentucky
Pennsylvani
a
Pennsylvani
a
Ohio
Illinois
Illinois
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
887 B 3
887 B 4
887 B 5
887 B 6
3947 B 1
3947 B 2
3947 B 3
3936 B 1
3936 B 2
1381 B C1
1381 B C2
1381 B C3
3136 B 1
3136 B 2
6031 B 2
876 B 1
876 B 2
3407 B 1
3407 B 2
3407 B 3
3407 B 4
3407 B 5
3407 B 6
3407 B 7
3407 B 8
3407 B 9
167
167
167
167
206
206
206
204
204
148
148
153
839
839
608
584
584
134
134
134
134
175
175
175
175
175
1954
1954
1955
1955
1958
1958
1959
1953
1953
1969
1970
1971
1967
1968
1982
1967
1968
1954
1954
1954
1954
1955
1955
1955
1955
1955
tangential
tangential
tangential
tangential
cyclone
cyclone
cyclone
vertical
vertical
wall
wall
wall
tangential
tangential
wall
cyclone
cyclone
tangential
tangential
tangential
tangential
tangential
tangential
tangential
tangential
tangential
dry
dry
dry
dry
wet
wet
wet
dry
dry
dry
dry
dry
dry
dry
dry
wet
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0400
0.0400
0.0400
0.0400
0.0300
0.0300
0.0300
0.0300
0.0300
0.1400
0.1900
0.1200
0.0800
0.0600
0.0300
0.0100
0.0100
0.0100
0.0100
0.0100
0.0100
0.0100
0.0200
0.0200
0.0200
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0100
0.0100
0.0100
0.0100
0.0100
0.0100
0.0100
0.0200
0.0200
0.0200
0.0200
0.0121
0.0121
0.0121
0.0121
0.0021
0.0021
0.0021
0.0021
0.0021
0.1121
0.1621
0.0921
0.0521
0.0321
0.0021
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
ESP-3
ESP-3
ESP-3
ESP-3
ESP-1
ESP-1
ESP-1
ESP-1
ESP-1
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-1
62
-------
Kraft
Kraft
Kraft
KUCC
KUCC
KUCC
KUCC
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
La Cygne
Labadie
Labadie
Labadie
Labadie
Lake Road
Lake Shore
Lansing
Lansing Smith
Lansing Smith
Laramie River Station
Laramie River Station
Laramie River Station
Lawrence Energy Center
Leland Olds
1
2
3
1
2
3
4
1
2
3
4
5
2
1
2
3
4
6
18
4
1
2
1
2
3
3
1
Georgia
Georgia
Georgia
Utah
Utah
Utah
Utah
Ohio
Ohio
Ohio
Ohio
Ohio
Kansas
Missouri
Missouri
Missouri
Missouri
Missouri
Ohio
Iowa
Florida
Florida
Wyoming
Wyoming
Wyoming
Kansas
North
Dakota
733 B 1
733 B 2
733 B 3
56163 B 1
56163 B 2
56163 B 3
56163 B 4
2876 B 1
2876 B 2
2876 B 3
2876 B 4
2876 B 5
1241 B 2
2103 B 1
2103 B 2
2103 B 3
2103 B 4
2098 B 6
2838 B 18
1047 B 4
643 B 1
643 B 2
6204 B 1
6204 B 2
6204 B 3
1250 B 3
2817 B 1
48
52
102
30
30
30
65
214
214
214
214
214
682
597
594
612
612
97
245
260
162
195
565
570
570
48
221
1958
1961
1965
1944
1945
1945
1959
1955
1955
1955
1955
1955
1977
1970
1971
1972
1973
1967
1962
1977
1965
1967
1980
1981
1982
1955
1966
tangential
tangential
tangential
wall
wall
wall
tangential
wall
wall
wall
wall
wall
wall
tangential
tangential
tangential
tangential
cyclone
tangential
wall
tangential
tangential
wall
wall
wall
tangential
wall
dry
dry
dry
wet
wet
wet
dry
wet
wet
wet
wet
wet
dry
dry
dry
dry
dry
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0.0200
0.0170
0.0430
0.0300
0.0300
0.0300
0.0300
0.0500
0.0300
0.0400
0.0100
0.0500
0.0200
0.0400
0.0300
0.0300
0.0200
0.0200
0.0500
0.0900
0.0200
0.0100
0.0100
0.0100
0.0100
0.0300
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
Yes
Yes
No
No
No
No
No
No
No
No
Yes
No
Yes
No
No
No
Yes
Yes
No
No
Yes
Yes
Yes
Yes
Yes
No
Yes
0.0200
0.0170
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0100
0.0279
0.0200
0.0279
0.0279
0.0279
0.0200
0.0200
0.0279
0.0279
0.0200
0.0100
0.0100
0.0100
0.0100
0.0279
0.0100
0.0000
0.0000
0.0151
0.0021
0.0021
0.0021
0.0021
0.0221
0.0021
0.0121
0.0000
0.0221
0.0000
0.0121
0.0021
0.0021
0.0000
0.0000
0.0221
0.0621
0.0000
0.0000
0.0000
0.0000
0.0000
0.0021
0.0000
ESP-3
ESP-1
ESP-1
ESP-1
ESP-1
ESP-4
ESP-1
ESP-3
ESP-4
ESP-3
ESP-1
ESP-1
ESP-4
ESP-4
___
ESP-1
...
63
-------
Leland Olds
Limestone
Limestone
Lon Wright
Marion
Marshall
Marshall
Marshall
Marshall
Martin Lake
Martin Lake
Martin Lake
Mayo
Mayo
Mclntosh
Meramec
Meramec
Meramec
Meramec
Meredosia
Merom
Merom
Merrimack
Merrimack
Miami Fort
2
LIM1
LIM2
8
4
1
2
3
4
1
2
3
1A
1B
1
1
2
3
4
05
1SG1
2SG1
1
2
6
North
Dakota
Texas
Texas
Nebraska
Illinois
North
Carolina
North
Carolina
North
Carolina
North
Carolina
Texas
Texas
Texas
North
Carolina
North
Carolina
Georgia
Missouri
Missouri
Missouri
Missouri
Illinois
Indiana
Indiana
New
Hampshire
New
Hampshire
Ohio
2817 B 2
298 B LIM1
298 B LIM2
2240 B 8
976 B 4
2727 B 1
2727 B 2
2727 B 3
2727 B 4
6146 B 1
6146 B 2
6146 B 3
6250 B 1A
6250 B 1B
6124 B 1
2104 B 1
2104 B 2
2104 B 3
2104 B 4
864 B 05
6213 B 1SG1
6213 B 2SG1
2364 B 1
2364 B 2
2832 B 6
448
830
857
85
170
378
378
657
657
750
750
750
371
371
157
122
120
269
347
203
507
493
111
315
162
1975
1985
1986
1976
1978
1965
1966
1969
1970
1977
1978
1979
1983
1983
1979
1953
1954
1959
1961
1960
1983
1982
1960
1968
1960
cyclone
tangential
tangential
wall
cyclone
tangential
tangential
tangential
tangential
tangential
tangential
tangential
wall
wall
wall
tangential
tangential
wall
wall
tangential
wall
wall
wall
cyclone
tangential
wet
dry
dry
dry
wet
dry
dry
dry
dry
wet
wet
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
wet
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0100
0.0100
0.0100
0.1200
0.0400
0.0200
0.0200
0.0600
0.0200
0.0100
0.0100
0.0100
0.0600
0.0600
0.0200
0.0300
0.0100
0.0200
0.0100
0.0319
0.0200
0.0200
0.0332
0.0332
0.0400
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
Yes
Yes
Yes
No
No
Yes
Yes
No
Yes
Yes
Yes
Yes
No
No
Yes
No
Yes
Yes
Yes
No
Yes
Yes
No
No
No
0.0100
0.0100
0.0100
0.0279
0.0279
0.0200
0.0200
0.0279
0.0200
0.0100
0.0100
0.0100
0.0279
0.0279
0.0200
0.0279
0.0100
0.0200
0.0100
0.0279
0.0200
0.0200
0.0279
0.0279
0.0279
0.0000
0.0000
0.0000
0.0921
0.0121
0.0000
0.0000
0.0321
0.0000
0.0000
0.0000
0.0000
0.0321
0.0321
0.0000
0.0021
0.0000
0.0000
0.0000
0.0040
0.0000
0.0000
0.0053
0.0053
0.0121
...
ESP-4
ESP-3
ESP-4
ESP-4
ESP-4
ESP-1
ESP-1
ESP-2
ESP-2
ESP-3
64
-------
Miami Fort
Miami Fort
Michigan City
Mill Creek
Mill Creek
Mill Creek
Mill Creek
Milton L Kapp
Milton R Young
Milton R Young
Mitchell
Mitchell
Mitchell Power Station
Monroe
Monroe
Monroe
Monroe
Monticello
Montrose
Montrose
Montrose
Morgantown Generating
Plant
Morgantown Generating
Plant
Mountaineer
Mt Storm
7
8
12
1
2
3
4
2
B1
B2
1
2
33
1
2
3
4
3
1
2
3
1
2
1
1
Ohio
Ohio
Indiana
Kentucky
Kentucky
Kentucky
Kentucky
Iowa
North
Dakota
North
Dakota
West
Virginia
West
Virginia
Pennsylvani
a
Michigan
Michigan
Michigan
Michigan
Texas
Missouri
Missouri
Missouri
Maryland
Maryland
West
Virginia
West
Virginia
2832 B 7
2832 B 8
997 B 12
1364 B 1
1364 B 2
1364 B 3
1364 B 4
1048 B 2
2823 B B1
2823 B B2
3948 B 1
3948 B 2
3181 B 33
1733 B 1
1733 B 2
1733 B 3
1733 B 4
6147 B 3
2080 B 1
2080 B 2
2080 B 3
1573 B 1
1573 B 2
6264 B 1
3954 B 1
493
493
469
303
301
391
477
211
250
455
800
800
277
760
775
785
765
750
170
164
176
624
620
1300
524
1975
1978
1974
1972
1974
1978
1982
1967
1970
1977
1971
1971
1963
1972
1973
1973
1974
1978
1958
1960
1964
1970
1971
1980
1965
wall
wall
cyclone
tangential
tangential
wall
wall
tangential
cyclone
cyclone
wall
wall
tangential
cell
cell
cell
cell
wall
tangential
tangential
tangential
tangential
tangential
wall
tangential
dry
dry
wet
dry
dry
dry
dry
dry
wet
wet
dry
dry
dry
dry
dry
dry
dry
wet
dry
dry
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0100
0.0900
0.0800
0.0500
0.0900
0.0900
0.0100
0.1420
0.0100
0.0100
0.0300
0.0300
0.1800
0.0300
0.0300
0.0200
0.0200
0.0453
0.1300
0.1300
0.1300
0.0700
0.0700
0.0300
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
Yes
No
No
No
No
No
Yes
No
Yes
Yes
No
No
No
No
No
Yes
Yes
No
No
No
No
No
No
No
Yes
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0100
0.0279
0.0100
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0200
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0100
0.0000
0.0621
0.0521
0.0221
0.0621
0.0621
0.0000
0.1141
0.0000
0.0000
0.0021
0.0021
0.1521
0.0021
0.0021
0.0000
0.0000
0.0174
0.1021
0.1021
0.1021
0.0421
0.0421
0.0021
0.0000
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
...
ESP-1
ESP-1
ESP-4
ESP-1
ESP-1
ESP-3
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-1
...
65
-------
Mt Storm
Mt Storm
Muscatine Plant #1
Muscatine Plant #1
Muskingum River
Muskingum River
Muskingum River
Muskingum River
Muskingum River
Muskogee
Muskogee
Muskogee
Naughton
Naughton
Naughton
Navajo
Navajo
Navajo
Nearman Creek
Nebraska City
Neil Simpson II
Nelson Dewey
Nelson Dewey
New Castle
New Castle
New Castle
2
3
8
9
1
2
3
4
5
4
5
6
1
2
3
1
2
3
N1
1
2
1
2
3
4
5
West
Virginia
West
Virginia
Iowa
Iowa
Ohio
Ohio
Ohio
Ohio
Ohio
Oklahoma
Oklahoma
Oklahoma
Wyoming
Wyoming
Wyoming
Arizona
Arizona
Arizona
Kansas
Nebraska
Wyoming
Wisconsin
Wisconsin
Pennsylvani
a
Pennsylvani
a
Pennsylvani
a
3954 B 2
3954 B 3
1167 B 8
1167 B 9
2872 B 1
2872 B 2
2872 B 3
2872 B 4
2872 B 5
2952 B 4
2952 B 5
2952 B 6
4162 B 1
4162 B 2
4162 B 3
4941 B 1
4941 B 2
4941 B 3
6064 B N1
6096 B 1
7504 B 2
4054 B 1
4054 B 2
3138 B 3
3138 B 4
3138 B 5
524
521
35
147
190
190
205
205
578
511
522
515
158
207
330
750
750
750
229
646
80
107
111
95
96
138
1966
1973
1969
1983
1953
1954
1957
1958
1968
1977
1978
1984
1963
1968
1971
1974
1975
1976
1981
1979
1995
1959
1962
1952
1958
1964
tangential
tangential
cyclone
tangential
wall
wall
cyclone
cyclone
cell
tangential
tangential
tangential
tangential
tangential
tangential
tangential
tangential
tangential
wall
wall
wall
cyclone
cyclone
wall
wall
wall
dry
dry
wet
dry
wet
wet
wet
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
wet
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
0
0.0100
0.0100
0.0200
0.0200
0.0300
0.0300
0.0300
0.0300
0.0300
0.0300
0.0300
0.0300
0.0100
0.0200
0.0200
0.0200
0.0200
0.0200
0.0200
0.0300
0.0300
0.1000
0.0700
0.0100
0.0100
0.0500
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
Yes
Yes
Yes
Yes
No
No
No
No
No
No
No
No
Yes
Yes
Yes
Yes
Yes
Yes
Yes
No
No
No
No
Yes
Yes
No
0.0100
0.0100
0.0200
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0100
0.0200
0.0200
0.0200
0.0200
0.0200
0.0200
0.0279
0.0279
0.0279
0.0279
0.0100
0.0100
0.0279
0.0000
0.0000
0.0000
0.0000
0.0021
0.0021
0.0021
0.0021
0.0021
0.0021
0.0021
0.0021
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0021
0.0021
0.0721
0.0421
0.0000
0.0000
0.0221
...
...
ESP-1
ESP-1
ESP-1
ESP-1
ESP-1
ESP-1
ESP-1
ESP-1
___
ESP-1
ESP-4
ESP-4
...
ESP-4
66
-------
New Madrid
New Madrid
Newton
Newton
Niles
Niles
North Omaha
North Omaha
North Omaha
North Omaha
North Omaha
Northeastern
Northeastern
O H Mulchings
O H Mulchings
O H Mulchings
O H Mulchings
O H Mulchings
O H Mulchings
Oklaunion
Ottumwa
P H Glatfelter
Paradise
Petersburg
Petersburg
Petersburg
Petersburg
1
2
1
2
1
2
1
2
3
4
5
3313
3314
H-1
H-2
H-3
H-4
H-5
H-6
1
1
5PB03
6
3
1
2
3
4
Missouri
Missouri
Illinois
Illinois
Ohio
Ohio
Nebraska
Nebraska
Nebraska
Nebraska
Nebraska
Oklahoma
Oklahoma
Ohio
Ohio
Ohio
Ohio
Ohio
Ohio
Texas
Iowa
Pennsylvani
a
Kentucky
Indiana
Indiana
Indiana
Indiana
2167 B 1
2167 B 2
6017 B 1
6017 B 2
2861 B 1
2861 B 2
2291 B 1
2291 B 2
2291 B 3
2291 B 4
2291 B 5
2963 B 3313
2963 B 3314
2848 B H-1
2848 B H-2
2848 B H-3
2848 B H-4
2848 B H-5
2848 B H-6
127 B 1
6254 B 1
50397 B 5PBO
36
1378 B 3
994 B 1
994 B 2
994 B 3
994 B 4
580
580
555
567
107
111
79
111
111
138
224
450
450
58
55
63
63
63
63
690
673
36
963
232
435
532
545
1972
1977
1977
1982
1954
1954
1954
1957
1959
1963
1968
1979
1980
1948
1949
1950
1951
1952
1953
1986
1981
1989
1970
1967
1969
1977
1986
cyclone
cyclone
tangential
tangential
cyclone
cyclone
tangential
tangential
tangential
tangential
wall
tangential
tangential
tangential
tangential
tangential
tangential
tangential
tangential
wall
tangential
FBC
cyclone
tangential
tangential
tangential
tangential
wet
wet
dry
dry
wet
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0600
0.0500
0.0091
0.0091
0.0100
0.0100
0.0300
0.0300
0.0300
0.0300
0.0300
0.0200
0.0200
0.0300
0.0600
0.0300
0.0300
0.0200
0.0200
0.0200
0.0300
0.0300
0.0400
0.0520
66.0000
0.0270
0.0250
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
No
Yes
Yes
Yes
Yes
No
No
No
No
No
Yes
Yes
No
No
No
No
Yes
Yes
Yes
No
No
No
No
No
Yes
Yes
0.0279
0.0279
0.0091
0.0091
0.0100
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0200
0.0200
0.0279
0.0279
0.0279
0.0279
0.0200
0.0200
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0270
0.0250
0.0321
0.0221
0.0000
0.0000
0.0000
0.0000
0.0021
0.0021
0.0021
0.0021
0.0021
0.0000
0.0000
0.0021
0.0321
0.0021
0.0021
0.0000
0.0000
0.0000
0.0021
0.0021
0.0121
0.0241
65.9721
0.0000
0.0000
ESP-4
ESP-4
ESP-1
ESP-1
ESP-1
ESP-1
ESP-1
ESP-1
ESP-4
ESP-1
ESP-1
ESP-1
ESP-1
ESP-3
ESP-4
ESP-4
—
67
-------
Philip Sporn
Philip Sporn
Philip Sporn
Philip Sporn
Picway
Pirkey
Platte
Pleasant Prairie
Pleasant Prairie
Pleasants Power Station
Pleasants Power Station
Portland
Portland
Potomac River
Potomac River
Potomac River
Potomac River
Potomac River
Powerton
Powerton
Powerton
Powerton
PPL Brunner Island
PPL Brunner Island
PPL Montour
11
21
31
41
9
1
1
1
2
1
2
1
2
1
2
3
4
5
51
52
61
62
2
3
1
West
Virginia
West
Virginia
West
Virginia
West
Virginia
Ohio
Texas
Nebraska
Wisconsin
Wisconsin
West
Virginia
West
Virginia
Pennsylvani
a
Pennsylvani
a
Virginia
Virginia
Virginia
Virginia
Virginia
Illinois
Illinois
Illinois
Illinois
Pennsylvani
a
Pennsylvani
a
Pennsylvani
a
3938 B 11
3938 B 21
3938 B 31
3938 B 41
2843 B 9
7902 B 1
59 B 1
6170 B 1
6170 B 2
6004 B 1
6004 B 2
3113 B 1
3113 B 2
3788 B 1
3788 B 2
3788 B 3
3788 B 4
3788 B 5
879 B 51
879 B 52
879 B 61
879 B 62
3140 B 2
3140 B 3
3149 B 1
150
150
150
150
95
674
100
617
617
639
639
157
242
88
88
102
102
102
382
383
382
383
382
744
751
1950
1950
1951
1952
1955
1985
1982
1980
1985
1979
1980
1958
1962
1949
1950
1954
1956
1957
1972
1972
1975
1975
1965
1981
1971
vertical
vertical
vertical
vertical
wall
wall
tangential
wall
wall
wall
wall
tangential
tangential
tangential
tangential
tangential
tangential
tangential
cyclone
cyclone
cyclone
cyclone
tangential
tangential
tangential
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
wet
wet
wet
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
1
1
1
1
1
0
0
0
0
0
0
0
0.0300
0.0300
0.0300
0.0300
0.0300
0.2500
0.0280
0.0100
0.0100
0.0200
0.0200
0.0800
0.0200
0.0200
0.0300
0.0500
0.0100
0.0200
0.0300
0.0300
0.0100
0.0100
0.0256
0.0256
0.0107
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
No
No
No
No
No
No
Yes
Yes
Yes
Yes
No
Yes
Yes
No
No
Yes
Yes
No
No
Yes
Yes
Yes
Yes
Yes
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0100
0.0100
0.0200
0.0200
0.0279
0.0200
0.0200
0.0279
0.0279
0.0100
0.0200
0.0279
0.0279
0.0100
0.0100
0.0256
0.0256
0.0107
0.0021
0.0021
0.0021
0.0021
0.0021
0.2221
0.0001
0.0000
0.0000
0.0000
0.0000
0.0521
0.0000
0.0000
0.0021
0.0221
0.0000
0.0000
0.0021
0.0021
0.0000
0.0000
0.0000
0.0000
0.0000
ESP-1
ESP-1
ESP-1
ESP-1
ESP-1
ESP-4
ESP-1
...
ESP-4
...
ESP-1
ESP-1
...
...
...
68
-------
PPL Montour
Prairie Creek
Prairie Creek
Pulliam
Pulliam
Pulliam
Pulliam
Quindaro
Quindaro
R D Green
R D Green
R D Morrow
R D Morrow
R E Burger
R E Burger
R M Heskett
R M Heskett
R M Schahfer
R M Schahfer
R M Schahfer
R M Schahfer
R Paul Smith Power
Station
R S Nelson
River Rouge
River Rouge
Riverbend
2
3
4
5
6
7
8
1
2
G1
G2
1
2
5
6
B1
B2
14
15
17
18
9
6
2
3
10
Pennsylvani
a
Iowa
Iowa
Wisconsin
Wisconsin
Wisconsin
Wisconsin
Kansas
Kansas
Kentucky
Kentucky
Mississippi
Mississippi
Ohio
Ohio
North
Dakota
North
Dakota
Indiana
Indiana
Indiana
Indiana
Maryland
Louisiana
Michigan
Michigan
North
Carolina
3149 B 2
1073 B 3
1073 B 4
4072 B 5
4072 B 6
4072 B 7
4072 B 8
1295 B 1
1295 B 2
6639 B G1
6639 B G2
6061 B 1
6061 B 2
2864 B 5
2864 B 6
2790 B B1
2790 B B2
6085 B 14
6085 B 15
6085 B 17
6085 B 18
1570 B 9
1393 B 6
1740 B 2
1740 B 3
2732 B 10
747
42
125
49
72
88
133
72
111
231
233
180
180
47
47
29
76
424
472
361
361
28
550
241
272
133
1973
1958
1967
1949
1951
1958
1964
1965
1971
1979
1981
1978
1978
1955
1955
1954
1963
1976
1979
1983
1986
1947
1982
1957
1958
1954
tangential
wall
wall
wall
wall
wall
wall
cyclone
wall
wall
wall
wall
wall
wall
wall
stoker/SP
R
FBC
cyclone
wall
tangential
tangential
wall
tangential
tangential
wall
tangential
dry
dry
dry
dry
dry
dry
dry
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
dry
dry
dry
dry
wet
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0166
0.0800
0.0600
0.0700
0.0700
0.0200
0.0700
0.0284
0.0284
0.0469
0.0469
0.0300
0.0200
0.0600
0.0400
0.0400
0.0100
0.0152
0.0152
0.0152
0.0152
0.1700
0.0113
0.0100
0.0100
0.0284
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
Yes
No
No
No
No
Yes
No
No
No
No
No
No
Yes
No
No
No
Yes
Yes
Yes
Yes
Yes
No
Yes
Yes
Yes
No
0.0166
0.0279
0.0279
0.0279
0.0279
0.0200
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0200
0.0279
0.0279
0.0279
0.0100
0.0152
0.0152
0.0152
0.0152
0.0279
0.0113
0.0100
0.0100
0.0279
0.0000
0.0521
0.0321
0.0421
0.0421
0.0000
0.0421
0.0005
0.0005
0.0190
0.0190
0.0021
0.0000
0.0321
0.0121
0.0121
0.0000
0.0000
0.0000
0.0000
0.0000
0.1421
0.0000
0.0000
0.0000
0.0005
...
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-1
ESP-1
ESP-3
ESP-3
ESP-1
ESP-4
ESP-3
ESP-3
...
___
ESP-4
ESP-1
69
-------
Riverbend
Riverbend
Riverbend
Riverside
Riverton
Riverton
Rivesville
Rivesville
Rockport
Rockport
Rodemacher
Roxboro
Roxboro
Roxboro
Roxboro
Roxboro
Roxboro
Rumford Cogeneration
Rumford Cogeneration
Rush Island
Rush Island
Salem Harbor
Salem Harbor
Salem Harbor
7
8
9
9
39
40
7
8
MB1
MB2
2
1
2
3A
3B
4A
4B
6
7
1
2
1
2
3
North
Carolina
North
Carolina
North
Carolina
Iowa
Kansas
Kansas
West
Virginia
West
Virginia
Indiana
Indiana
Louisiana
North
Carolina
North
Carolina
North
Carolina
North
Carolina
North
Carolina
North
Carolina
Maine
Maine
Missouri
Missouri
Massachuse
tts
Massachuse
tts
Massachuse
tts
2732 B 7
2732 B 8
2732 B 9
1081 B 9
1239 B 39
1239 B 40
3945 B 7
3945 B 8
6166 B MB1
6166 B MB2
6190 B 2
2712 B 1
2712 B 2
2712 B 3A
2712 B 3B
2712 B 4A
2712 B 4B
10495 B 6
10495 B 7
6155 B 1
6155 B 2
1626 B 1
1626 B 2
1626 B 3
94
94
133
130
38
54
46
91
1280
1280
523
369
671
353
353
349
349
43
43
604
604
82
80
149
1952
1952
1954
1961
1950
1954
1943
1951
1984
1989
1982
1966
1968
1973
1973
1980
1980
1990
1990
1976
1977
1951
1952
1958
tangential
tangential
tangential
tangential
wall
tangential
vertical
vertical
wall
wall
wall
wall
tangential
wall
wall
wall
wall
FBC
FBC
tangential
tangential
wall
wall
wall
dry
dry
dry
dry
dry
dry
wet
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0284
0.1050
0.1050
0.0500
0.0300
0.0300
0.0100
0.0200
0.0300
0.0300
0.0100
0.0600
0.0700
0.0600
0.0600
0.0700
0.0700
0.0100
0.0100
0.0100
0.0300
0.0100
0.0005
0.0300
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
No
No
No
No
No
Yes
Yes
No
No
Yes
No
No
No
No
No
No
Yes
Yes
Yes
No
Yes
Yes
No
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0100
0.0200
0.0279
0.0279
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0100
0.0100
0.0100
0.0279
0.0100
0.0005
0.0279
0.0005
0.0771
0.0771
0.0221
0.0021
0.0021
0.0000
0.0000
0.0021
0.0021
0.0000
0.0321
0.0421
0.0321
0.0321
0.0421
0.0421
0.0000
0.0000
0.0000
0.0021
0.0000
0.0000
0.0021
ESP-1
ESP-4
ESP-4
ESP-4
ESP-1
ESP-1
...
...
ESP-1
ESP-1
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-1
...
...
ESP-1
70
-------
San Miguel
Sandow
Schiller
Scholz
Scholz
Seminole
Seminole
Shawville
Shawville
Shawville
Shawville
Sherburne County
Sherburne County
Sibley
Sibley
Sibley
Sikeston Power Station
Sioux
Sioux
Sooner
Sooner
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
Southwest Power Station
SM-1
4
4
1
2
1
2
1
2
3
4
1
2
1
2
3
1
1
2
1
2
5
6
7
8
1
Texas
Texas
New
Hampshire
Florida
Florida
Florida
Florida
Pennsylvani
a
Pennsylvani
a
Pennsylvani
a
Pennsylvani
a
Minnesota
Minnesota
Missouri
Missouri
Missouri
Missouri
Missouri
Missouri
Oklahoma
Oklahoma
Wisconsin
Wisconsin
Wisconsin
Wisconsin
Missouri
6183 B SM-1
6648 B 4
2367 B 4
642 B 1
642 B 2
136 B 1
136 B 2
3131 B 1
3131 B 2
3131 B 3
3131 B 4
6090 B 1
6090 B 2
2094 B 1
2094 B 2
2094 B 3
6768 B 1
2107 B 1
2107 B 2
6095 B 1
6095 B 2
4041 B 5
4041 B 6
4041 B 7
4041 B 8
6195 B 1
391
542
48
49
49
654
654
122
125
175
175
762
752
54
54
401
233
490
490
535
540
257
260
292
306
178
1982
1981
1952
1953
1953
1984
1984
1954
1954
1959
1960
1976
1977
1960
1962
1969
1981
1967
1968
1979
1980
1959
1961
1965
1967
1976
wall
tangential
wall
wall
wall
wall
wall
wall
wall
tangential
tangential
tangential
tangential
cyclone
cyclone
cyclone
wall
cyclone
cyclone
tangential
tangential
wall
wall
tangential
tangential
wall
dry
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
wet
wet
dry
wet
wet
dry
dry
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.1000
0.0400
0.0400
0.0200
0.0200
0.0210
0.0160
0.0800
0.0400
0.0133
0.0133
0.0200
0.0200
0.0300
0.0400
0.0092
0.0200
0.0034
0.0034
0.0320
0.0500
0.0200
0.0100
0.0015
0.0117
0.0400
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
No
No
Yes
Yes
Yes
Yes
No
No
Yes
Yes
Yes
Yes
No
No
Yes
Yes
Yes
Yes
No
No
Yes
Yes
Yes
Yes
No
0.0279
0.0279
0.0279
0.0200
0.0200
0.0210
0.0160
0.0279
0.0279
0.0133
0.0133
0.0200
0.0200
0.0279
0.0279
0.0092
0.0200
0.0034
0.0034
0.0279
0.0279
0.0200
0.0100
0.0015
0.0117
0.0279
0.0721
0.0121
0.0121
0.0000
0.0000
0.0000
0.0000
0.0521
0.0121
0.0000
0.0000
0.0000
0.0000
0.0021
0.0121
0.0000
0.0000
0.0000
0.0000
0.0041
0.0221
0.0000
0.0000
0.0000
0.0000
0.0121
ESP-4
ESP-3
ESP-3
ESP-4
ESP-3
...
ESP-1
ESP-3
ESP-1
ESP-4
___
ESP-3
71
-------
St Clair
St Clair
St Clair
St Clair
St Clair
St Clair
St Johns River Power
Park
St Johns River Power
Park
Stanton
Stanton Energy Center
Stanton Energy Center
Stone Container Florence
Mill
Streeter Station
Sunbury Generation LP
Sunbury Generation LP
Sutherland
Taconite Harbor Energy
Center
Taconite Harbor Energy
Center
Taconite Harbor Energy
Center
Tanners Creek
Tanners Creek
Tanners Creek
Tanners Creek
Tecumseh Energy Center
Tecumseh Energy Center
1
2
3
4
6
7
1
2
1
1
2
PB4
7
3
4
3
1
2
3
U1
U2
U3
U4
10
9
Michigan
Michigan
Michigan
Michigan
Michigan
Michigan
Florida
Florida
North
Dakota
Florida
Florida
South
Carolina
Iowa
Pennsylvani
a
Pennsylvani
a
Iowa
Minnesota
Minnesota
Minnesota
Indiana
Indiana
Indiana
Indiana
Kansas
Kansas
1743 B 1
1743 B 2
1743 B 3
1743 B 4
1743 B 6
1743 B 7
207 B 1
207 B 2
2824 B 1
564 B 1
564 B 2
50806 B PB4
1131 B 7
3152 B 3
3152 B 4
1077 B 3
10075 B 1
10075 B 2
10075 B 3
988 B U1
988 B U2
988 B U3
988 B U4
1252 B 10
1252 B 9
151
154
160
151
312
440
623
622
130
440
446
75
36
94
128
82
65
67
68
145
145
200
500
129
74
1953
1953
1954
1954
1961
1969
1987
1988
1967
1987
1996
1987
1973
1951
1953
1961
1957
1957
1967
1951
1952
1954
1964
1962
1957
wall
wall
wall
wall
tangential
tangential
wall
wall
wall
wall
wall
wall
wall
wall
wall
cyclone
tangential
tangential
tangential
vertical
vertical
vertical
cyclone
tangential
tangential
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
dry
dry
dry
dry
dry
dry
wet
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
1
1
0
0
0
0
0
0
0.1000
0.0100
0.0100
0.0300
0.0100
0.0200
0.0100
0.0100
0.0100
0.0100
0.0100
0.0100
0.0300
0.0400
0.0600
0.0300
0.0055
0.0201
0.0201
0.0300
0.0053
0.0053
0.0053
0.0500
0.0900
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
Yes
Yes
No
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
No
No
No
No
Yes
Yes
Yes
No
Yes
Yes
Yes
No
No
0.0279
0.0100
0.0100
0.0279
0.0100
0.0200
0.0100
0.0100
0.0100
0.0100
0.0100
0.0100
0.0279
0.0279
0.0279
0.0279
0.0055
0.0201
0.0201
0.0279
0.0053
0.0053
0.0053
0.0279
0.0279
0.0721
0.0000
0.0000
0.0021
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0021
0.0121
0.0321
0.0021
0.0000
0.0000
0.0000
0.0021
0.0000
0.0000
0.0000
0.0221
0.0621
ESP-4
ESP-1
...
...
...
ESP-1
ESP-3
ESP-4
ESP-1
...
...
ESP-1
___
ESP-4
ESP-4
72
-------
Thomas Hill
Thomas Hill
Thomas Hill
Titus
Titus
Titus
Transalta Centralia
Generation
Transalta Centralia
Generation
Trenton Channel
Trenton Channel
Trenton Channel
Trenton Channel
Trenton Channel
Trimble County
Tyrone
Urquhart
Victor J Daniel Jr
Victor J Daniel Jr
WH Sammis
WH Sammis
WH Sammis
W H Weatherspoon
W H Weatherspoon
W H Weatherspoon
W H Zimmer
MB1
MB2
MBS
1
2
3
BW21
BW22
16
17
18
19
9A
1
5
URQ3
1
2
5
6
7
1
2
3
1
Missouri
Missouri
Missouri
Pennsylvani
a
Pennsylvani
a
Pennsylvani
a
Washington
Washington
Michigan
Michigan
Michigan
Michigan
Michigan
Kentucky
Kentucky
South
Carolina
Mississippi
Mississippi
Ohio
Ohio
Ohio
North
Carolina
North
Carolina
North
Carolina
Ohio
2168 B MB1
2168 B MB2
2168 B MBS
3115 B 1
3115 B 2
3115 B 3
3845 B BW21
3845 B BW22
1745 B 16
1745 B 17
1745 B 18
1745 B 19
1745 B 9A
6071 B 1
1361 B 5
3295 B URQ3
6073 B 1
6073 B 2
2866 B 5
2866 B 6
2866 B 7
2716 B 1
2716 B 2
2716 B 3
6019 B 1
175
275
670
81
81
81
703
703
53
53
53
53
536
383
71
94
507
507
300
597
600
48
49
76
1300
1966
1969
1982
1951
1951
1953
1972
1973
1949
1949
1949
1950
1968
1990
1953
1955
1977
1981
1967
1969
1971
1949
1950
1952
1991
cyclone
cyclone
wall
tangential
tangential
tangential
tangential
tangential
tangential
tangential
tangential
tangential
tangential
tangential
wall
tangential
tangential
tangential
wall
wall
wall
wall
wall
tangential
wall
wet
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0300
0.0300
0.0300
0.0400
0.0400
0.0300
0.0100
0.0100
0.0300
0.0300
0.0300
0.0300
0.0400
0.0300
0.0300
0.0800
0.0200
0.0300
0.0200
0.0100
0.0100
0.0600
0.0600
0.0900
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
No
No
No
No
No
Yes
Yes
No
No
No
No
No
No
No
No
Yes
No
Yes
Yes
Yes
No
No
No
Yes
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0100
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0200
0.0279
0.0200
0.0100
0.0100
0.0279
0.0279
0.0279
0.0100
0.0021
0.0021
0.0021
0.0121
0.0121
0.0021
0.0000
0.0000
0.0021
0.0021
0.0021
0.0021
0.0121
0.0021
0.0021
0.0521
0.0000
0.0021
0.0000
0.0000
0.0000
0.0321
0.0321
0.0621
0.0000
ESP-1
ESP-1
ESP-1
ESP-3
ESP-3
ESP-1
...
...
ESP-1
ESP-1
ESP-1
ESP-1
ESP-3
ESP-1
ESP-1
ESP-4
ESP-1
ESP-4
ESP-4
ESP-4
73
-------
WS Lee
WSLee
WS Lee
Wabash River
Wabash River
Wabash River
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Walter Scott Jr. Energy
Center
Walter Scott Jr. Energy
Center
Wansley
Wansley
Warrick
Warrick
Warrick
Warrick
Waukegan
Waukegan
Waukegan
Welsh
Welsh
Welsh
1
2
3
2
4
6
1
2
3
4
5
6
1
2
1
2
1
2
3
4
17
7
8
1
2
3
South
Carolina
South
Carolina
South
Carolina
Indiana
Indiana
Indiana
Ohio
Ohio
Ohio
Ohio
Ohio
Ohio
Iowa
Iowa
Georgia
Georgia
Indiana
Indiana
Indiana
Indiana
Illinois
Illinois
Illinois
Texas
Texas
Texas
3264 B 1
3264 B 2
3264 B 3
1010 B 2
1010 B 4
1010 B 6
2830 B 1
2830 B 2
2830 B 3
2830 B 4
2830 B 5
2830 B 6
1082 B 1
1082 B 2
6052 B 1
6052 B 2
6705 B 1
6705 B 2
6705 B 3
6705 B 4
883 B 17
883 B 7
883 B 8
6139 B 1
6139 B 2
6139 B 3
98
98
168
43
43
318
94
94
128
150
238
409
45
88
891
892
136
136
136
300
100
327
359
527
524
524
1951
1951
1958
1953
1955
1968
1952
1953
1954
1958
1962
1969
1954
1958
1976
1978
1960
1964
1965
1970
1952
1958
1962
1977
1980
1982
tangential
tangential
tangential
wall
wall
tangential
tangential
tangential
wall
tangential
tangential
tangential
wall
tangential
tangential
tangential
wall
wall
wall
cell
cyclone
tangential
tangential
wall
wall
wall
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.1300
0.0700
0.0400
0.0500
0.1100
0.1100
0.0700
0.0500
0.0600
0.0500
0.0400
0.0400
0.0700
0.0500
0.0620
0.0600
0.1000
0.0900
0.1500
0.1400
0.0200
0.0517
0.0517
0.0075
0.0075
0.0075
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
No
Yes
No
No
Yes
Yes
Yes
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0200
0.0279
0.0279
0.0075
0.0075
0.0075
0.1021
0.0421
0.0121
0.0221
0.0821
0.0821
0.0421
0.0221
0.0321
0.0221
0.0121
0.0121
0.0421
0.0221
0.0341
0.0321
0.0721
0.0621
0.1221
0.1121
0.0000
0.0238
0.0238
0.0000
0.0000
0.0000
ESP-4
ESP-4
ESP-3
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-3
ESP-3
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
___
___
74
-------
Weston
Weston
Whelan Energy Center
White Bluff
White Bluff
Widows Creek
Will County
Will County
Williams
Willow Island
Willow Island
Winyah
Winyah
Winyah
Winyah
Wood River
Wood River
Wyandotte
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Yorktown
1
2
1
1
2
7
3
4
WIL1
1
2
1
2
3
4
4
5
7
Y1BR
Y2BR
Y3BR
Y4BR
Y5BR
Y6BR
Y7BR
1
Wisconsin
Wisconsin
Nebraska
Arkansas
Arkansas
Alabama
Illinois
Illinois
South
Carolina
West
Virginia
West
Virginia
South
Carolina
South
Carolina
South
Carolina
South
Carolina
Illinois
Illinois
Michigan
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Virginia
4078 B 1
4078 B 2
60 B 1
6009 B 1
6009 B 2
50 B 7
884 B 3
884 B 4
3298 B WIL1
3946 B 1
3946 B 2
6249 B 1
6249 B 2
6249 B 3
6249 B 4
898 B 4
898 B 5
1866 B 7
728 B Y1BR
728 B Y2BR
728 B Y3BR
728 B Y4BR
728 B Y5BR
728 B Y6BR
728 B Y7BR
3809 B 1
62
86
76
815
825
473
250
503
606
54
181
295
295
295
270
105
383
35
99
105
112
135
137
346
349
157
1954
1960
1981
1980
1981
1961
1957
1963
1973
1949
1960
1975
1977
1980
1981
1954
1964
1948
1950
1950
1952
1957
1958
1974
1974
1957
wall
wall
tangential
tangential
tangential
tangential
tangential
tangential
tangential
vertical
cyclone
wall
wall
wall
wall
tangential
tangential
wall
tangential
tangential
tangential
tangential
tangential
tangential
tangential
tangential
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
wet
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
dry
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.0021
0.0021
0.0042
0.0100
0.0070
0.0100
0.0288
0.0288
0.0200
0.0200
0.0200
0.0800
0.0100
0.0400
0.0300
0.0400
0.0100
0.0300
0.2000
0.2000
0.2000
0.0700
0.0700
0.0300
0.0200
0.0518
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
Yes
Yes
Yes
Yes
Yes
Yes
No
No
Yes
Yes
Yes
No
Yes
No
No
No
Yes
No
No
No
No
No
No
No
Yes
No
0.0021
0.0021
0.0042
0.0100
0.0070
0.0100
0.0279
0.0279
0.0200
0.0200
0.0200
0.0279
0.0100
0.0279
0.0279
0.0279
0.0100
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0279
0.0200
0.0279
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
0.0009
0.0009
0.0000
0.0000
0.0000
0.0521
0.0000
0.0121
0.0021
0.0121
0.0000
0.0021
0.1721
0.1721
0.1721
0.0421
0.0421
0.0021
0.0000
0.0239
ESP-1
ESP-1
...
...
ESP-4
ESP-3
ESP-1
ESP-3
ESP-1
ESP-4
ESP-4
ESP-4
ESP-4
ESP-4
ESP-1
ESP-4
75
-------
Yorktown
2
Virginia
3809 B 2
164
1959
tangential
dry
0
0.0518
0.0279
No
0.0279
0.0239
ESP-4
76
-------
Gibsons Creek Power Plant: This unit is listed as only having access to subbituminious coal in NEEDS.
However, since it the unit was originally designed to burn lignite, as evidenced by historic consumption, in
MATS policy runs it is subjected to the Hg limit for low Btu virgin coal in the policy case.
Treatment of DSI in Emissions Calculations: DSI is considered when calculating condensable PM for air
quality modeling but not when assigning mercury EMFs in the power sector modeling.
Accounting for Presence of Fabric Filters in Deriving Mercury Emission Modification Factors (EMFs) and
Calculating Filterable Particulate Matter (PM): When fabric filters are added to generating units, the
mercury EMFs are recalculated to account for their presence. This is applied in both the base and policy
case v.4.10_MATS runs and in the v.4.10_MATS runs used in air quality modeling. In addition, since the
calculation of filterable PM for air quality modeling is a function of filter efficiency, the post-processing
procedure, used to prepare model output of air quality modeling, was also updated to account for the
presence of FFs
77
-------
Chapter 7: Set-Up Parameters and Rules
7.5 MATS Specific Set-Up Rules" (new)
The following set-up features apply in the v.4.10 base and policy cases for MATS:
7.5.1 New Builds and Retrofits in 2012: Given the short lead time, EPA's policy analysis has disabled
incremental new capacity and retrofit construction in the 2012 model year. The results presented for the
2012 model year reflect the model's enactment of investment decisions already underway (as opposed to
any investment decisions driven by new policies).
7.5.2 SCR Retrofits in the MATS Policy Scenario: SCR is an advanced post-combustion technology
for NOX control. While SCR can yield mercury control cobenefits, IPM results demonstrate that MATS
alone is insufficient to drive new SCR retrofitting by 2015; the results show that other control
technologies, such as ACI, are generally more cost-effective compliance options in the near term for
MATS implementation. It is possible that certain units may elect to 'accelerate' the installation of SCR
that they may otherwise have considered installing in the 2020-2050 timeframe, depending on future NOX
control requirements. In light of the inherent long-run uncertainty in this type of decision, and the focus of
this analysis on quantifying the incremental impacts of MATS in 2015, EPA conservatively constrained
IPM to prevent the model from "re-locating" (i.e., accelerating) long-term base case SCR installations from
2020-2050 to the 2015 model year for MATS.
78
-------
Chapter 11: Other Fuels and Fuel Emission Factor Assumptions
11.5 Fuel Emission Factors
Table 11-4 brings together all the fuel emission factor assumptions as implemented in EPA Base Case
v.4.10_MATS. For sulfur dioxide and mercury in coal, where emission factors vary widely based on the
rank, grade, and supply seam source of the coal, cross references are given to tables that provide more
detailed treatment of the topic. Nitrogen oxides (NOX) are not included in Table 11-4 because NOX levels
are not primarily fuel based but are a factor of the combustion process.
Table 11-4 Fuel Emission Factor Assumptions in EPA Base Case v.4.10_MATS
Fuel Type
Coal
Bituminous
Subbituminous
Lignite
Natural Gas
Fuel Oil
Distillate
Residual
Biomass
Waste Fuels
Waste Coal4
Petroleum Coke
Fossil Waste
Non-Fossil Waste
Tires
Municipal Solid Waste
Heat Content
(Btu/lb)1
>1 0,260 -13,000
> 7, 500 -10,260
< 7,500
~
~
~
~
6,175
14,150
—
~
~
~
Carbon
Dioxide
(Ibs/MMBtu)2
205.2 - 206.6
212.7-213.1
213.5-217.0
117.08
161.4
161.4- 173.9
0
205.7
225.1
321.1
0
189.5
91.9
Sulfur
Dioxide
(Ibs/MMBtu)3
0.67-6.43
0.58-1.41
1.46-3.91
0
0
0.3-2.65
0.08
5.36
7.27
0.08
0
1.65
0.35
Mercury
(Ibs/TBtu)3
1.82-34.71
4.24 - 6.44
7.51 - 14.88
0.00014
0.48
0.48
0.57
63.9
24442.66
0
0
3.58
71.85
Notes:
1 Distillate and Residual Oils, Biomass, Fossil Waste, Non-Fossil Waste, Tires, and Municipal Solid
Waste (MSW) are priced at a $/MMBtu basis and hence heat content is not required for modeling.
2Also see Table 9-9 in EPA Base Case v.4.10 (EPA #430-R-10-010), August 2010 at
www.epa.gov/airmarkets/progsregs/epa-ipm/transport.html.
3Also see Table 9-6 and Table 9-7 in EPA Base Case v.4.10 (EPA #430-R-10-010), August 2010
atwww.epa.gov/airmarkets/progsregs/epa-ipm/transport.html.
Biomass fuel is considered to have a net zero impact on atmospheric carbon dioxide levels since
the emissions released are equivalent in carbon content to the carbon absorbed during fuel crop
growth. (See, for example, Hughes, E., Role of Renewables in Greenhouse Gas Reduction,
Electric Power Research Institute (EPRI): November, 1998. Report TR-111883, p. 28.)
Biomass Co-firing," Chapter 2 in Renewable Energy Technology Characterizations, U.S.
Department of Energy and Electric Power Research Institute (EPRI), 1997.
Analysis of Emissions Reduction Option for the Electric Power Industry, Office of Air and
Radiation, U.S. Environmental Protection Agency, March 1999.
4ln EPA Base Case v.4.10_MATS waste coal units are assumed to achieve 99% mercury removal.
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