Appendix 5A 

Original and Revised LADCO Technical 

Support Document for Regional Haze Modeling 
Regional Air Quality Analyses for

Ozone, PM2.5, and Regional Haze: 

Final Technical Support Document

April 25, 2008

States of Illinois, Indiana, Michigan, Ohio, and Wisconsin
ii

Table of Contents

 Section-Title Page

Executive Summary iii

1.0 Introduction 1

1.1 SIP Requirements 1

1.2 Organization 2

1.3 Technical Work: Overview 3

2.0 Ambient Data Analyses 4

2.1 Ozone 4

2.2 PM2.5 21

2.3 Regional Haze 35

3.0 Air Quality Modeling 46

3.1 Selection of Base Year 46

3.2 Future Years of Interest 46

3.3 Modeling System 47

3.4 Domain/Grid Resolution 47

3.5 Model Inputs: Meteorology 48

3.6 Model Inputs: Emissions 51

3.7 Base Year Modeling Results 60

4.0 Attainment Demonstration for Ozone and PM2.5 71

4.1 Future Year Modeling Results 71

4.2 Supplemental Analyses 82

4.3 Weight of Evidence Determination for Ozone 82

4.4 Weight of Evidence Determination for PM2.5 90

5.0 Reasonable Progress Assessment for Regional Haze 93

5.1 Class I Areas Impacted 93

5.2 Future Year Modeling Results 96

5.3 Weight of Evidence Determination for Regional Haze 104

6.0 Summary 111

7.0 References 114

Appendix I Ozone and PM2.5 Modeling Results

Appendix II Ozone Source Apportionment Modeling Results

Appendix III PM2.5Source Apportionment Modeling Results

Appendix IV Haze Source Apportionment Modeling Results
1

Regional Air Quality Analyses for Ozone, PM2.5, and Regional Haze: 

Final Technical Support Document (Supplement), September 12, 2008

The purpose of this paper is to summarize a new modeling analysis performed by the Lake 

Michigan Air Directors Consortium (LADCO) to address the effect of the recent court decision 

vacating EPA’s Clean Air Interstate Rule (CAIR). This new modeling is intended to supplement 

the LADCO Technical Support Document (“Regional Air Quality Analyses for Ozone, PM2.5, 

and Regional Haze: Final Technical Support Document”, April 25, 2008), which summarizes the 

air quality analyses conducted by LADCO and its contractors to support the development of 

State Implementation Plans for ozone, PM2.5, and regional haze in the States of Illinois, 

Indiana, Michigan, Ohio, and Wisconsin.

Compared to the previous LADCO modeling (Round 5.1), the new modeling shows similar 

results for ozone, but much more nonattainment for PM2.5 and higher visibility levels for 

regional haze. Specifically, the new modeling shows:

Ozone: Attainment of the 0.08 ppm standard by 2009 everywhere in the region, except 

Holland, MI, and nonattainment of the 0.075 ppm standard through at least 2018.

PM2.5: Widespread nonattainment of annual (15 ug/m3) and daily (35 ug/m3) standards.

Haze: Higher visibility levels on the 20% worst visibility days in 2018 in Class I areas in 

the eastern U.S., resulting in most areas being above the glide path.

Background: On July 11, 2008, the U.S. Court of Appeals for D.C. Circuit vacated EPA’s CAIR 

rule (cite). The reductions in NOx and SO2 emissions associated with this rule were a key part 

of the LADCO States’ attainment demonstrations for ozone and PM2.5 and the reasonable 

progress determinations for regional haze. LADCO’s previous modeling (Round 5.1) relied on 

EGU emission projections from EPA’s IPM3.0 analysis, which assumed implementation of 

Phases I and II of CAIR. For this new modeling, alternative EGU emission projections were 

developed, which did not rely on CAIR (or IPM).

Model Set-Up: The new modeling was performed consistent with LADCO’s previous modeling 

(Round 5.1):

Model Version: CAMx v4.50beta_deposition

Future Years: 2009, 2012, 2018

Runs: (a) Ozone: Summer 2005 meteorology with 12 km grids

(b) PM2.5 and haze: Full year 2005 meteorology with 36 km grids

Emission Scenarios: The new modeling assumed the same set of “on the books” controls as 

in LADCO’s previous modeling (Round 5.1) for all sectors, except EGUs. In light of the CAIR 

decision, three new EGU scenarios were prepared:
2

Scenario A: 2007 CEM-based emissions were projected for all states in the modeling domain 

based on EIA growth rates by state (NERC region) and fuel type. The assumed growth rates for 

the Midwest States were: MAIN (IL, IA, MO, WI): 8.8% (2007-2018); ECAR (IN, KY, MI, OH): 

13.5% (2007-2018); and MAPP (MN): 15.1% (2007-2018). No control was applied. The annual 

emissions were temporalized based on profiles derived from 2004-2006 CEM data. (Note, these 

are the same temporal profiles used in Round 5.1.)

Scenario B. Scenario A emissions for the LADCO States and select neighboring states (e.g., 

MN, IA, MO, KY, TN, and WV) were adjusted by applying legally enforceable controls (i.e., 

emission reductions required by a Consent Decree, state rule, or permit). Only those legally 

enforceable controls identified (and justified) by the States were applied. The States also 

supplied the appropriate control factors. A table summarizing the Scenario B controls is provided 

in Appendix I.

Scenario C. For the years 2009 and 2012, Scenario A emissions for all states were adjusted by 

applying all planned SO2 and NOx controls based on the July 10 CAMD list (i.e., 90% reduction 

for scrubbers, 95% reduction for SCRs). Because the July 10 CAMD list only includes controls 

generally out to 2011, additional SO2 and NOx controls for the year 2018 were assumed for all 

BART-eligible EGUs in the five LADCO State plus MN, IA, MO, KY, TN, and MO list (i.e., 90% 

reduction for scrubbers, 95% reduction for SCRs). All Scenario B controls were included in 

Scenario C. A table summarizing the Scenario C controls (CAMD list plus BART) is provided in 

Appendix II.

Table 1 and Figure 1 provide a summary of the 5-state regional NOx and SO2 emissions for 

each scenario and future year. (Note, the CAIR emissions included here are based on EPA’s 

IPM3.0 modeling.) Several comments on the emissions should be noted:

Summer NOx

• There is llittle difference between the three alternative scenarios and CAIR. This 

suggests that summer ozone concentrations for the alternative scenarios are 

likely to be similar to those predicted with CAIR (i.e., Round 5.1).

Annual NOx:

• There is a significant change in emissions between scenarios, mostly during the 

non-summer months.

• Scenario B reflects application of NOx controls in several states; especially, IL, 

OH, and WI.

• Because there are relatively few SCRs (in the LADCO States) on the CAMD list, 

Scenario C results in only a small emissions decrease compared to Scenario C.

• Assumed BART controls result in a significant emissions decrease.

Annual SO2

• There is a significant change in emissions between scenarios.

• Scenario B reflects application of SO2 controls in several states; especially, IL, 

OH, and WI.

• Because there are several FGDs (in the LADCO States) on the CAMD list, 

Scenario C results in a large emissions decrease compared to Scenario C.

• Assumed BART controls result in a significant emissions decrease (i.e., even 

lower emissions than the IPM-estimated CAIR emissions).
3

Figure 1. Regional NOx and SO2 Emissions

Summer NOx Emissions

0

500

1,000

1,500

2,000

2,500

3,000

2005

2007

2009A

2009B

2009C

2009CAIR

2012A

2012B

2012C

2012CAIR

2018A

2018B

2018C

2018BART

2018CAIR

Annual NOx Emissions

0

200,000

400,000

600,000

800,000

1,000,000

2005

2007

2009A

2009B

2009C

2009CAIR

2012A

2012B

2012C

2012CAIR

2018A

2018B

2018C

2018BART

2018CAIR

Annual SO2 Emissions

0

500,000

1,000,000

1,500,000

2,000,000

2,500,000

3,000,000

2005

2007

2009A

2009B

2009C

2009CAIR

2012A

2012B

2012C

2012CAIR

2018A

2018B

2018C

2018BART

2018CAIR
4

Table 1. Regional NOx and SO2 Emissions

 

Summer NOx Emissions (TPD)

2005 2007 2009 A 2009 B 2009 C

2010 

CAIR 2012 A 2012 B 2012 C

2012 

CAIR 2018 A 2018 B 2018 C

2018 CBART2018 

CAIR

IL 305 305 311 311 311 275 340 236 236 266 333 227 227 219 224

IN 393 393 376 376 374 384 393 393 390 368 410 386 383 292 264

MI 393 393 350 350 350 242 366 366 366 229 377 377 377 260 243

OH 408 408 395 355 335 285 423 351 351 290 431 366 366 230 290

WI 413 413 167 160 160 238 184 170 170 177 183 168 168 168 177

1,912 1,912 1,599 1,552 1,530 1,424 1,706 1,516 1,513 1,330 1,734 1,524 1,521 1,169 1,198

 

 

Annual NOx Emissions (TPY)

2005 2007 2009 A 2009 B 2009 C

2010 

CAIR 2012 A 2012 B 2012 C

2012 

CAIR 2018 A 2018 B 2018 C

2018 CBART2018 

CAIR

IL 126,786 121,006 124,917 124,917 124,917 83,224 137,438 81,989 81,989 82,248 135,983 79,771 79,771 63,590 69,958

IN 214,727 203,493 203,776 203,776 201,947 133,188 212,790 212,790 210,877 125,541 221,950 212,805 210,810 177,027 90,415

MI 120,332 112,484 112,478 112,478 112,478 83,117 117,621 117,621 117,621 77,897 122,447 122,447 122,447 89,444 79,543

OH 255,554 240,351 240,016 173,071 164,911 94,346 251,065 172,514 172,514 97,679 261,644 179,737 179,737 125,762 95,678

WI 71,414 54,582 56,540 54,065 54,065 53,032 62,266 57,759 57,759 56,480 61,812 56,952 56,952 56,952 56,158

788,812 731,917 737,727 668,307 658,317 446,908 781,179 642,673 640,760 439,845 803,837 651,712 649,717 512,774 391,752

 

 

Annual SO2 Emissions (TPY)

2005 2007 2009 A 2009 B 2009 C

2010 

CAIR 2012 A 2012 B 2012 C

2012 

CAIR 2018 A 2018 B 2018 C

2018 CBART2018 

CAIR

IL 326,598 273,467 281,028 281,028 281,028 295,516 309,209 196,238 194,746 267,110 305,364 106,638 105,152 82,351 275,716

IN 866,964 722,301 721,252 721,252 619,486 374,335 754,323 754,323 558,567 379,144 786,551 764,065 559,945 426,695 359,915

MI 350,694 343,487 343,140 343,140 315,326 227,296 358,879 358,879 301,062 233,204 373,964 373,964 313,677 178,680 242,853

OH 1,100,510 960,820 959,466 959,466 693,438 427,145 1,003,633 897,099 572,807 370,532 1,045,945 819,770 481,623 333,740 315,560

WI 181,426 137,562 142,007 142,007 133,738 139,181 156,659 144,818 133,592 139,203 155,818 144,027 132,849 77,214 127,073

2,826,192 2,437,638 2,446,892 2,446,892 2,043,017 1,463,473 2,582,703 2,351,356 1,760,775 1,389,192 2,667,641 2,208,463 1,593,245 1,098,679 1,321,116
5

Modeling Results: Several tables summarizing the modeling results are provided:

Table 2 - future year ozone and PM2.5 concentrations for key monitors in the 

 LADCO region

Table 3 - number of monitoring sites greater than the National Ambient Air Quality 

 Standards (NNAQS)

Table 4 – visibility levels for Class I areas in the eastern U.S. 

Note, given that Scenario B and BART controls were only applied in an 11-state Midwest 

region, the validity of the results for other Class I areas in the eastern U.S. may be 

questionable. The Scenario C controls, on the other hand, cover all states and are, thus, 

likely valid in other Class I areas.

Spatial plots of the future year ozone and PM2.5 concentrations are provided in Figures 2 – 4. 

Based on these results, the following key findings should be noted:

Ozone 

• There is little change from the previous LADCO modeling (Round 5.1 with CAIR)

• The modeling shows attainment of the 0.08 ppm (85 ppb) standard by 2009, 

except Holland. (Note, Holland does meet this standard by 2012.)

• The modeling shows nonattainment of the 0.075 ppm (75 ppb) standard through 

2018.

PM2.5 - Annual

• There is a significant change from the previous LADCO modeling (Round 5.1 

with CAIR)

• The modeling shows extensive nonattainment of the annual standard.

PM2.5 - Daily 

• There is a significant change from the previous LADCO modeling (Round 5.1 

with CAIR)

• The modeling shows extensive nonattainment of the daily standard.

Haze 

• There is a significant change from the previous LADCO modeling (Round 5.1 

with CAIR)

• The modeling shows higher visibility levels in 2018 for the 20% worst visibility 

days (average about 0.5 deciviews for the northern Class I areas). The resulting 

visibility levels in the northern Class I areas (except Voyageurs) are above the 

glide path.
2005

Site Site ID Base Year Scen. A Scen. B Scen.C Round 5 Scen. A Scen. B Scen.C Round 5 Scen. A Scen. B Scen.C

Scen.CBART Round 5

Lake Michigan Area

Chiwaukee 550590019 84.7 82.2 82.2 82.0 82.3 81.1 80.8 80.6 80.9 77.2 77.2 77.0 76.0 76.2

Racine 551010017 80.3 77.8 77.8 77.5 77.5 76.6 76.2 76.1 76.1 72.9 72.3 72.1 71.1 71.2

Milwaukee-Bayside 550890085 82.7 79.9 79.9 79.7 79.8 78.5 78.0 78.0 78.0 74.3 73.6 73.4 72.4 72.7

Harrington Beach 550890009 83.3 80.1 80.1 79.9 80.1 78.6 78.1 78.0 78.3 73.9 73.2 73.1 72.2 72.5

Manitowoc 550710007 85.0 80.8 80.8 80.7 80.8 79.0 78.5 78.4 78.6 73.9 73.2 73.1 72.0 72.5

Sheboygan 551170006 88.0 84.1 84.0 83.9 84.0 82.2 81.7 81.5 81.8 76.9 76.0 75.9 74.8 75.4

Kewaunee 550610002 82.7 78.2 78.2 78.0 78.1 76.4 75.9 75.7 75.9 71.3 70.7 70.5 69.4 69.9

Door County 550290004 88.7 84.1 84.1 83.9 83.9 82.0 81.4 81.3 81.5 76.5 75.6 75.5 74.2 74.7

Hammond 180892008 77.7 76.2 76.2 76.0 75.4 75.6 75.3 75.2 74.6 73.2 72.7 72.6 71.7 71.6

Whiting 180890030 79.3 77.8 77.8 77.7 77.0 77.2 76.9 76.8 76.2 74.8 74.3 74.2 73.2 73.1

Michigan City 180910005 77.0 74.5 74.5 74.3 73.9 73.3 72.9 72.8 72.5 69.7 69.2 69.1 68.1 68.1

Ogden Dunes 181270020 78.3 76.3 76.3 76.2 75.6 75.5 75.1 75.0 74.5 72.9 72.3 72.1 71.2 70.8

Holland 260050003 90.0 85.7 85.7 85.5 85.3 83.5 83.1 82.9 82.8 78.2 77.5 77.3 76.0 76.1

Jenison 261390005 82.0 76.8 76.8 76.7 76.0 75.1 74.6 74.5 74.5 70.2 69.6 69.5 67.9 68.7

Muskegon 261210039 85.0 80.6 80.6 80.5 80.5 78.6 78.2 78.1 78.0 73.5 72.8 72.8 71.5 71.9

Indianapolis Area

Noblesville 189571001 82.7 78.3 78.3 78.1 78.1 76.1 75.9 75.7 75.6 70.2 69.9 69.8 68.9 68.7

Fortville 180590003 78.0 74.1 74.1 73.9 73.9 71.9 71.8 71.7 71.4 66.7 66.5 66.3 65.4 65.1

Fort B. Harrison 180970050 78.7 75.4 75.3 75.2 75.1 73.8 73.6 73.6 73.2 70.6 70.3 70.2 69.3 69.1

Detroit Area

New Haven 260990009 86.0 82.4 82.3 82.1 81.4 81.4 81.2 81.1 80.2 78.1 77.8 77.7 76.5 76.1

Warren 260991003 84.0 82.4 82.3 82.2 81.3 82.1 81.8 81.7 80.7 79.7 79.4 79.3 78.0 77.6

Port Huron 261470005 82.7 78.2 78.2 78.1 77.5 76.5 76.3 76.2 75.5 72.6 72.5 72.3 70.9 70.9

Cleveland Area

Ashtabula 390071001 89.0 84.2 84.1 83.9 83.4 82.0 81.8 81.6 81.0 76.8 76.5 76.4 74.8 75.1

Geauga 390550004 79.3 75.8 75.8 75.6 74.7 74.0 73.8 73.7 72.7 69.5 69.2 69.1 67.6 67.3

Eastlake 390850003 86.3 83.1 83.1 82.9 81.9 81.8 81.6 81.5 80.5 78.2 78.0 77.8 76.5 76.2

Akron 391530020 83.7 79.1 79.1 79.0 78.1 76.9 76.7 76.6 75.6 70.9 70.6 70.4 68.7 68.7

Cincinnati Area

Wilmington 390271002 82.3 77.3 77.4 77.1 77.5 75.3 75.2 74.8 74.9 70.1 69.9 69.5 67.1 68.3

Sycamore 390610006 84.7 81.5 81.4 81.1 81.9 80.4 80.2 79.8 80.3 76.4 76.0 75.7 73.5 74.6

Lebanon 391650007 87.7 82.8 82.8 82.4 83.0 80.8 80.7 80.3 80.7 75.4 75.1 74.8 72.6 74.2

Columbus Area

London 390970007 79.7 75.0 75.0 74.8 75.0 73.0 72.8 72.7 72.6 68.1 67.8 67.6 65.9 66.3

New Albany 390490029 86.3 82.1 82.1 81.9 81.8 80.2 80.0 79.9 79.6 74.7 74.3 74.2 73.3 73.0

Franklin 290490028 80.3 76.7 76.6 76.5 75.9 75.1 74.9 74.8 74.1 70.5 70.2 70.1 70.2 69.0

St. Louis Area

W. Alton (MO) 291831002 86.3 81.1 81.2 81.1 81.0 80.0 79.9 79.9 78.6 76.9 76.8 76.7 74.2 74.9

Orchard (MO) 291831004 87.0 82.1 82.1 82.0 82.0 80.9 80.8 80.7 80.0 77.7 77.6 77.4 75.2 76.2

Sunset Hills (MO) 291890004 82.3 79.2 79.2 79.1 78.7 78.3 78.1 78.1 77.1 75.3 75.2 75.1 73.0 73.9

Arnold (MO) 290990012 82.3 77.8 77.8 77.7 77.2 76.7 76.6 76.5 75.6 73.6 73.4 73.4 71.3 72.0

Margaretta (MO) 295100086 83.0 79.8 79.8 79.7 79.3 78.8 78.7 78.6 77.9 75.7 75.6 75.5 73.7 74.4

Maryland Heights (MO) 291890014 87.3 85.4 85.4 85.3 84.0 84.3 84.1 84.0 81.7 81.1 80.9 80.8 78.4 78.1

Table 2a. Ozone Modeling Results

2009 2012 2018
2005

Site Site ID Base Year Scen. A Scen. B Scen.C Round 5 Scen. A Scen. B Scen.C Round 5 Scen. A Scen. B Scen.C

Scen.CBART Round 5

Illinois

Chicago - Washington HS 170310022 15.2 14.9 14.8 14.5 14.1 14.8 14.7 14.2 14.0 15.0 14.6 14.2 13.7 13.9

Chicago - Mayfair 170310052 15.8 15.1 15.1 14.8 14.4 15.1 14.9 14.5 14.2 15.1 14.7 14.3 13.7 13.9

Chicago - Springfield 170310057 15.0 14.6 14.6 14.3 13.9 14.6 14.4 14.0 13.8 14.8 14.4 14.0 13.4 13.7

Chicago - Lawndale 170310076 14.9 14.5 14.5 14.2 13.8 14.5 14.3 13.9 13.7 14.7 14.3 13.9 13.3 13.6

Blue Island 170312001 14.8 14.4 14.4 14.0 13.7 14.4 14.2 13.8 13.6 14.5 14.1 13.7 13.2 13.4

Summit 170313301 15.2 14.9 14.9 14.6 14.2 14.9 14.7 14.3 14.0 15.0 14.6 14.3 13.7 13.9

Cicero 170316005 15.5 15.1 15.1 14.8 14.4 15.1 14.9 14.5 14.3 15.2 14.9 14.4 13.9 14.2

Granite City 171191007 16.7 16.3 16.2 15.9 15.1 16.1 16.0 15.3 14.9 15.9 15.6 14.9 14.2 14.3

E. St. Louis 171630010 15.6 15.2 15.2 14.8 14.1 15.0 14.9 14.3 13.9 14.9 14.6 14.0 13.3 13.4

Indiana

Jeffersonville 180190005 16.4 15.8 15.7 14.8 13.8 15.8 15.6 14.5 13.7 16.0 15.5 14.3 13.7 13.4

Jasper 180372001 15.2 14.3 14.2 13.4 12.4 14.2 14.0 13.0 12.2 14.3 13.9 12.8 12.1 11.8

Gary 180890031 15.6 13.9 13.9 13.5 13.0 13.8 13.6 13.1 12.8 13.7 13.4 12.9 12.3 12.4

Indy-Washington Park 180970078 15.3 14.4 14.4 13.6 12.8 14.3 14.2 13.2 12.6 14.3 13.9 12.9 12.2 12.0

Indy-W 18th Street 180970081 16.0 15.1 15.1 14.3 15.0 14.9 13.9 15.0 14.6 13.5 12.8

Indy- Michigan Street 180970083 15.9 15.0 15.0 14.2 13.4 14.9 14.8 13.8 13.1 14.9 14.5 13.5 12.8 12.6

Michigan

Allen Park 261630001 14.5 11.0 14.0 13.5 13.0 14.0 13.8 13.2 12.8 13.9 13.6 13.0 12.4 12.4

Southwest HS 261630015 15.9 15.3 15.3 14.8 14.2 15.2 15.0 14.4 13.9 15.1 14.8 14.1 13.5 13.5

Linwood 261630016 14.6 14.1 14.1 13.6 13.1 14.0 13.9 13.3 12.8 13.9 13.6 13.0 12.5 12.5

Dearborn 261630033 17.5 17.0 17.0 16.4 15.8 16.9 16.7 16.0 15.5 16.8 16.4 15.7 15.1 15.1

Wyandotte 261630036 14.7 14.2 14.1 13.6 13.1 14.1 13.9 13.3 12.8 14.0 13.7 13.0 12.4 12.5

Ohio

Middletown - Bonita 390170003 16.2 15.3 15.2 14.3 13.5 15.2 15.0 13.9 13.2 15.2 14.8 13.7 13.0 12.8

Fairfield 390170016 15.8 15.1 15.0 14.1 13.1 15.1 14.9 13.7 12.9 15.2 14.7 13.5 12.8 12.5

Cleveland-28th Street 390350027 15.4 14.9 14.9 14.3 13.5 14.7 14.5 13.9 13.2 14.6 14.2 13.5 12.8 12.7

Cleveland-St. Tikhon 390350038 17.4 16.7 16.7 16.0 15.2 16.5 16.3 15.6 14.8 16.3 16.0 15.2 14.4 14.3

Cleveland-Broadway 390350045 16.5 15.9 15.8 15.2 14.4 15.6 15.5 14.8 14.0 15.5 15.1 14.4 13.6 13.5

Cleveland-GT Craig 390350060 17.1 16.5 16.4 15.8 15.0 16.3 16.1 15.4 14.6 16.1 15.7 15.0 14.2 14.1

Newburg Hts - Harvard Ave 390350065 16.0 15.4 15.3 14.7 14.0 15.2 15.0 14.3 13.6 15.1 14.7 14.0 13.2 13.1

Columbus - Fairgrounds 390490024 15.3 14.6 14.5 13.7 12.9 14.4 14.1 13.2 12.6 14.2 13.8 12.8 12.2 12.0

Columbus - Ann Street 390490025 15.1 14.4 14.3 13.5 12.7 14.2 13.9 13.1 12.4 14.1 13.6 12.6 12.0 11.9

Cincinnati - Seymour 390610014 17.3 16.6 16.5 15.5 14.5 16.5 16.3 15.1 14.3 16.6 16.2 14.9 14.2 13.8

Cincinnati - Taft Ave 390610040 15.5 14.8 14.7 13.8 12.8 14.8 14.6 13.4 12.6 14.9 14.5 13.2 12.5 12.2

Cincinnati - 8th Ave 390610042 16.9 12.0 16.1 15.0 14.0 16.1 15.9 14.7 13.8 16.2 15.7 14.4 13.7 13.4

Sharonville 390610043 15.6 14.9 14.8 13.9 12.9 14.9 14.7 13.5 12.7 14.9 14.5 13.3 12.6 12.3

Norwood 390617001 16.2 15.5 15.4 14.4 13.4 15.4 15.2 14.0 13.2 15.5 15.1 13.8 13.1 12.8

St. Bernard 390618001 17.6 16.8 16.7 15.7 14.7 16.7 16.5 15.3 14.4 16.8 16.4 15.1 14.3 14.0

Steubenville 390810016 15.8 14.5 14.4 13.5 12.8 14.3 14.2 13.1 12.5 14.8 14.5 13.3 12.9 12.7

Mingo Junction 390811001 16.5 15.2 15.2 14.3 13.5 15.0 14.9 13.8 13.2 15.6 15.2 14.0 13.6 13.4

Ironton 390870010 15.2 14.8 14.6 13.6 12.8 14.6 14.4 13.2 12.5 14.8 14.1 12.8 12.4 12.3

Dayton 391130032 15.5 14.9 14.8 14.0 13.2 14.8 14.6 13.6 12.9 14.8 14.3 13.3 12.6 12.4

New Boston 391450013 14.7 12.0 14.0 13.0 12.1 14.1 13.8 12.5 11.9 14.2 13.6 12.2 11.7 11.6

Canton - Dueber 391510017 16.3 15.7 15.6 14.8 14.0 15.5 15.3 14.4 13.6 15.4 14.9 14.0 13.3 13.3

Canton - Market 391510020 14.6 11.0 14.1 13.3 12.6 13.9 13.7 12.9 12.3 13.9 13.5 12.6 12.0 11.9

Akron - Brittain 391530017 15.1 14.6 14.5 13.8 13.0 14.4 14.2 13.4 12.7 14.3 13.8 13.0 12.3 12.3

Akron - W. Exchange 391530023 14.3 13.7 13.7 13.0 12.3 13.6 13.3 12.6 12.0 13.4 13.0 12.2 11.6 11.5

2009 2012 2018

Table 2b. PM2.5 Modeling Results (Annual)
2005

Key Site County Site ID

Base 

Year Scen. A Scen. B Scen.C Round 5 Scen. A Scen. B Scen.C Round 5 Scen. A Scen. B Scen.C

Scen. C - 

BART Round 5

Illinois

Chicago - Washington HS Cook 170310022 36.6 36 36 36 36 36 36 37 36 37 36 37 37 35

Chicago - Mayfair Cook 170310052 40.3 37 37 37 36 37 36 37 36 38 37 37 37 36

Chicago - Springfield Cook 170310057 37.4 34 34 33 32 35 34 33 32 36 34 33 33 31

Chicago - Lawndale Cook 170310076 38.1 35 35 35 35 36 35 36 35 36 35 36 36 34

McCook Cook 170311016 43.0 39 39 39 39 40 39 40 39 40 40 41 40 38

Blue Island Cook 170312001 37.7 35 35 35 34 36 35 36 34 36 35 36 36 33

Schiller Park Cook 170313103 41.6 40 40 40 39 40 40 40 39 41 40 40 39 39

Summit Cook 170313301 40.2 38 38 39 38 39 38 39 38 39 38 39 39 37

Maywood Cook 170316005 39.2 38 38 38 38 38 38 39 38 39 38 39 39 37

Granite City Madison 171191007 39.2 36 36 35 33 36 35 34 33 36 35 35 33 32

E. St. Louis St. Clair 171630010 33.7 31 31 30 28 31 30 29 28 31 30 30 29 28

Indiana

Jeffersonville Clark 180190005 38.4 35 33 31 29 35 34 32 31 37 35 34 33 31

Jasper Dubois 180372001 36.2 32 32 30 28 32 32 30 29 33 31 31 30 28

Gary - IITRI Lake 180890022 39.0 35 35 35 34 35 34 35 34 36 36 36 35 35

Gary - Burr School Lake 180890026 39.0 34 34 34 33 34 34 35 34 34 34 34 34 32

Gary Lake 180890031 35.2 29 28 26 24 28 28 24 24 29 28 27 27 27

Indy-West Street Marion 180970043 38.0 34 34 33 33 35 35 34 33 36 35 34 34 33

Indy-English Avenue Marion 180970066 38.0 34 34 32 32 35 34 33 32 35 34 33 33 32

Indy-Washington Park Marion 180970078 36.6 33 33 32 31 33 33 32 31 34 33 32 32 32

Indy-W 18th Street Marion 180970081 38.3 33 33 31 31 33 33 32 31 34 33 32 32 31

Indy- Michigan Street Marion 180970083 36.0 32 32 29 28 32 31 29 28 32 31 29 29 29

Michigan

Luna Pier Monroe 261150005 38.9 34 34 32 32 34 34 32 32 34 33 32 31 31

Oak Park Oakland 261250001 39.9 38 38 37 36 38 37 37 36 38 37 37 36 35

Port Huron St. Clair 261470005 39.6 36 35 35 34 35 35 35 34 35 35 34 33 33

Ypsilanti Washtenaw 261610008 39.5 37 37 36 35 37 36 36 35 37 36 36 35 34

Allen Park Wayne 261630001 38.6 36 36 36 35 36 35 35 34 36 35 35 34 33

Southwest HS Wayne 261630015 40.1 36 36 36 35 36 35 35 35 36 35 35 34 33

Linwood Wayne 261630016 43.0 40 40 40 39 40 40 40 39 40 39 39 39 38

E 7 Mile Wayne 261630019 41.0 39 39 39 38 39 39 39 38 39 38 38 38 37

Dearborn Wayne 261630033 43.9 41 41 41 40 41 41 41 40 41 40 40 40 39

Wyandotte Wayne 261630036 37.2 36 36 36 35 35 35 35 35 35 35 35 35 34

Newberry Wayne 261630038 42.7 39 39 39 38 39 38 38 37 39 38 38 37 36

FIA Wayne 261630039 39.7 35 34 34 33 35 34 34 33 35 34 33 33 31

Ohio

Middleton Butler 390170003 39.3 33 32 29 28 33 33 29 28 34 32 29 28 27

Fairfield Butler 390170016 37.1 32 31 29 27 31 30 28 28 32 30 29 28 27

Butler 390170017 40.8 33 32 30 29 33 33 30 29 33 32 30 29 28

Cleveland-28th Street Cuyahoga 390350027 36.9 34 34 33 32 34 33 33 32 34 33 33 31 31

Cleveland-St. Tikhon Cuyahoga 390350038 44.2 40 40 37 36 40 39 36 35 40 38 36 35 34

Cleveland-Broadway Cuyahoga 390350045 38.8 35 35 33 31 35 34 32 30 35 34 31 29 29

Cleveland-GT Craig Cuyahoga 390350060 42.1 39 39 38 37 39 38 38 37 39 38 37 36 35

Newburg Hts - Harvard Ave Cuyahoga 390350065 38.9 35 35 33 31 35 34 32 30 36 35 32 31 30

2009 2012 2018

Table 2c. PM2.5 Modeling Results (Daily)
2005

Key Site County Site ID

Base 

Year Scen. A Scen. B Scen.C Round 5 Scen. A Scen. B Scen.C Round 5 Scen. A Scen. B Scen.C

Scen. C - 

BART Round 5

2009 2012 2018

Table 2c. PM2.5 Modeling Results (Daily)

Columbus - Fairgrounds Franklin 390490024 38.5 34 34 33 33 34 33 32 32 34 34 33 32 31

Columbus - Ann Street Franklin 390490025 38.5 34 33 31 31 33 33 31 31 34 33 31 31 30

Cincinnait Hamilton 390610006 40.6 33 33 30 27 33 32 29 28 34 32 29 28 27

Cincinnati - Seymour Hamilton 390610014 38.4 33 33 28 26 33 32 27 25 33 31 29 25 24

Cincinnati - Taft Ave Hamilton 390610040 36.7 31 30 26 24 31 30 26 24 32 29 26 24 23

Cincinnati - 8th Ave Hamilton 390610042 37.3 32 32 30 28 32 31 29 28 33 31 29 28 27

Sharonville Hamilton 390610043 36.0 32 31 30 28 32 31 29 28 32 31 29 28 27

Norwood Hamilton 390617001 38.8 34 33 32 30 33 33 31 30 34 33 31 30 29

St. Bernard Hamilton 390618001 40.6 35 35 32 30 35 34 31 30 35 33 32 31 29

Steubenville Jefferson 390810016 40.7 36 35 32 29 35 34 30 28 37 35 31 29 28

Mingo Junction Jefferson 390811001 42.0 37 37 33 30 37 36 32 30 38 36 32 30 30

Dayton Montgomery391130032 37.8 34 33 31 30 33 33 31 30 34 33 31 31 30

Canton - Dueber Stark 391510017 38.6 33 32 30 28 33 31 30 28 33 30 29 28 27

Akron - Brittain Summit 391530017 38.1 33 33 31 30 33 32 31 30 33 32 30 29 29

Wisconsin

Green Bay - Est High Brown 550090005 37.1 35 34 35 35 34 35 35 34 33 33 33 32 32

Madison Dane 550250047 36.4 33 33 32 32 33 32 32 31 32 31 30 29 29

Milwaukee-Health Center Milwaukee 550790010 38.7 35 35 35 35 35 35 35 34 35 34 34 34 33

Milwaukee-SER Hdqs Milwaukee 550790026 37.4 34 34 34 34 34 34 34 34 34 34 34 34 33

Milwaukee-Virginia FS Milwaukee 550790043 39.9 37 37 37 36 37 36 37 36 36 36 37 36 36

Milwaukee- Fire Dept Hdqs Milwaukee 550790099 37.8 34 34 33 33 34 33 33 32 34 33 33 33 32

Waukesha Waukesha 551330027 35.5 32 32 32 31 32 32 32 31 32 31 31 30 29
10

Table 3. Modeling Results: Number of Sites > NAAQS

Ozone (85 ppb) 

2009 Baseyear Scen. A Scen. B Scen. C

Scen. CBART CAIR

IL 0 0 0 0 ---- 0

IN 0 0 0 0 ---- 0

MI 3 1 1 1 ---- 1

OH 4 0 0 0 ---- 0

WI 2 0 0 0 ---- 0

Total 9 1 1 1 1

 

2012

IL 0 0 0 0 ---- 0

IN 0 0 0 0 ---- 0

MI 3 0 0 0 ---- 0

OH 4 0 0 0 ---- 0

WI 2 0 0 0 ---- 0

Total 9 0 0 0 0

 

2018

IL 0 0 0 0 0 0

IN 0 0 0 0 0 0

MI 3 0 0 0 0 0

OH 4 0 0 0 0 0

WI 2 0 0 0 0 0

Total 9 0 0 0 0 0

 

Ozone (75 ppb) 

2009 Baseyear Scen. A Scen. B Scen. C

Scen. CBART CAIR

IL 12 6 6 6 ---- 4

IN 26 10 9 8 ---- 5

MI 21 12 12 12 ---- 12

OH 45 27 25 24 ---- 21

WI 12 10 10 10 ---- 10

Total 116 65 62 60 ---- 52

 

2012

IL 12 3 3 3 ---- 1

IN 26 5 4 4 ---- 3

MI 21 9 8 8 ---- 6

OH 45 18 14 12 ---- 11

WI 12 10 9 9 ---- 9

Total 116 45 38 36 30

 

2018

IL 12 0 0 0 0 0

IN 26 0 0 0 0 0

MI 21 3 3 3 3 3

OH 45 3 3 2 1 1

WI 12 3 2 1 1 1

Total 116 9 8 6 5 5
11

PM2.5 - Annual

2009 Baseyear Scen. A Scen. B Scen. C

Scen. CBART CAIR

IL 7 4 4 1 ---- 1

IN 6 2 2 0 ---- 0

MI 2 2 2 1 ---- 1

OH 26 13 12 5 ---- 1

WI 0 0 0 0 ---- 0

Total 41 21 20 7 3

 

2012

IL 7 3 1 1 ---- 0

IN 6 1 1 0 ---- 0

MI 2 2 1 1 ---- 1

OH 26 12 9 4 ---- 0

WI 0 0 0 0 ---- 0

Total 41 18 12 6 1

 

2018

IL 7 3 1 0 0 0

IN 6 1 1 0 0 0

MI 2 2 1 1 1 1

OH 26 13 8 2 0 0

WI 0 0 0 0 0 0

Total 41 19 11 3 1 1

 

PM2.5 - Daily

2009 Baseyear Scen. A Scen. B Scen. C

Scen. CBART CAIR

IL 16 7 7 6 ---- 6

IN 13 0 0 0 ---- 0

MI 14 10 9 9 ---- 5

OH 31 4 3 2 ---- 2

WI 8 1 1 1 ---- 1

Total 82 22 20 18 ---- 14

2012

IL 16 9 6 8 ---- 6

IN 13 0 0 0 ---- 0

MI 14 8 6 6 ---- 5

OH 31 3 3 2 ---- 1

WI 8 1 1 1 ---- 1

Total 82 21 16 17 13

 

2018

IL 16 10 6 8 8 5

IN 13 4 1 1 0 0

MI 14 8 6 6 5 4

OH 31 5 3 2 1 0

WI 8 1 1 1 1 1

Total 82 28 17 18 15 10
12

Table 4. Modeling Results: Future Year Visibility Levels 

Worst 20% 2018

Site

Baseline

(2000-2004) 2018 URP Scen. A Scen. B Scen. C

Scen. CBART CAIR 

BOWA1 19.86 17.94 19.09 18.87 18.54 18.02 17.94

VOYA2 19.48 17.75 18.60 18.44 18.17 17.77 17.63

SENE1 24.38 21.64 24.02 23.58 23.03 22.38 22.59

ISLE1 21.59 19.43 21.05 20.86 20.62 20.22 20.09

ISLE9 21.59 19.43 20.83 20.58 20.38 19.84 19.84

 

HEGL1 26.75 23.13 26.24 25.83 24.87 24.23 24.22

MING1 28.15 24.27 27.51 26.98 25.81 24.93 24.74

CACR1 26.36 22.91 25.32 24.80 23.57 22.97 22.44

UPBU1 26.27 22.82 25.31 24.79 23.50 22.79 22.59

MACA1 31.37 26.64 30.11 29.08 27.06 26.24 26.10

DOSO1 29.05 24.69 27.88 26.96 24.36 23.74 23.00

SHEN1 29.31 25.12 28.38 27.65 25.24 24.69 23.92

JARI1 29.12 24.91 28.06 27.21 25.00 24.48 24.06

BRIG1 29.01 25.05 28.10 28.07 26.57 26.25 25.21

LYBR1 24.45 21.48 24.06 23.86 22.58 22.30 21.14

ACAD1 22.89 20.45 22.88 22.76 22.31 22.16 21.49

 

 

Best 20% 2018

Site

Baseline

(2000-2004) 2018 Max Scen. A Scen. B Scen. C

Scen. CBART CAIR

BOWA1 6.42 6.42 6.20 6.17 6.16 6.12 6.14

VOYA2 7.09 7.09 6.87 6.83 6.81 6.78 6.75

SENE1 7.14 7.14 7.80 7.78 7.81 7.77 7.71

ISLE1 6.75 6.75 6.77 6.76 6.72 6.67 6.60

ISLE9 6.75 6.75 6.63 6.61 6.58 6.53 6.52

 

HEGL1 12.84 12.84 12.17 12.20 12.07 11.63 11.66

MING1 14.46 14.46 13.78 13.77 13.70 13.37 13.28

CACR1 11.24 11.24 10.94 10.99 10.97 10.78 10.52

UPBU1 11.71 11.71 11.18 11.23 11.18 10.96 10.73

MACA1 16.51 16.51 16.32 16.21 15.76 15.34 15.25

DOSO1 12.28 12.28 12.02 11.84 11.27 11.03 11.00

SHEN1 10.93 10.93 10.98 10.91 10.25 10.16 9.91

JARI1 14.21 14.21 14.19 13.98 13.42 13.21 13.14

BRIG1 14.33 14.33 14.32 14.46 14.22 14.17 13.92

LYBR1 6.37 6.37 6.39 6.38 6.31 6.28 6.14

ACAD1 8.78 8.78 8.97 8.96 8.90 8.89 8.82
13

Figure 2. Ozone Modeling Results

2009 Scenario A Scenario B Scenario C CAIR

2012 Scenario A Scenario B Scenario C CAIR

2018 Scenario A Scenario B Scenario C CAIR
14

Figure 3. PM2.5 Annual Modeling Results

2009 Scenario A Scenario B Scenario C CAIR

2012 Scenario A Scenario B Scenario C CAIR

2018 Scenario A Scenario B Scenario C CAIR
15

Figure 4. PM2.5 Daily Modeling Results

2009 Scenario A Scenario B Scenario C CAIR

2012 Scenario A Scenario B Scenario C CAIR

2018 Scenario A Scenario B Scenario C CAIR
16

Appendix I

Scenario B (Legally Enforceable) Controls

 
17

NOx – 2009

Point Source Grown and Controlled Emissions by facility for NOX r6s1b_2009 

Base Year = 2002

Future Year = 2009

STID=17 CYID=57 fcid=057801AAA name=AES DUCK CREEK

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 57 057801AAA 0001 0001 01 10100202 NOX 0.8147 0.8416 0.8416 0.00 0.00 SCR SCR added by LADCO 

STID=17 CYID=143 fcid=143805AAG name=AES ED EDWARDS STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 143 143805AAG 0001 0001 01 10100202 NOX 3.0515 3.1522 3.1522 0.00 0.00 lnb LNB added by LADCO 

 17 143 143805AAG 0001 0003 01 10100202 NOX 6.9419 7.1708 7.1708 0.00 0.00 lnb LNB added by LADCO 

 17 143 143805AAG 0002 0004 01 10100202 NOX 2.1310 2.2013 2.2013 0.00 0.00 lnb LNB added by LADCO 

---- -------- -------- ----------

fcid 12.1244 12.5243 12.5243 

cyid 12.1244 12.5243 12.5243 

stid 12.9392 13.3659 13.3659 

STID=39 CYID=1 fcid=0701000007 name="DP&L, J.M. STUART GENERATING STATION"

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 1 0701000007 R1 B001 B001P1 10100202 NOX 6.9860 6.9756 2.3252 0.85 0.95 SCR SCR added by LADCO 

 39 1 0701000007 R2 B002 B002P1 10100202 NOX 3.6327 3.6273 1.2091 0.85 0.95 SCR SCR added by LADCO 

 39 1 0701000007 R3 B003 B003P1 10100202 NOX 5.0133 5.0058 1.6686 0.85 0.95 SCR SCR added by LADCO 

 39 1 0701000007 R4 B004 B004P1 10100202 NOX 7.8493 7.8376 2.6125 0.85 0.95 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 23.4814 23.4464 7.8155 

cyid 23.4814 23.4464 7.8155 

STID=39 CYID=167 fcid=0684000000 name=MUSKINGUM RIVER POWER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 167 0684000000 R1 B001 B001P1 10200501 NOX 0.0017 0.0017 0.0001 0.00 0.95 SCR SCR added by LADCO 

 39 167 0684000000 R2 B002 B002P1 10100201 NOX 5.8167 5.8080 0.2904 0.00 0.95 SCR SCR added by LADCO 

 39 167 0684000000 R2 B002 B002P2 10100501 NOX 0.0000 0.0000 0.0000 0.00 0.95 SCR SCR added by LADCO 

 39 167 0684000000 R3 B003 B003P1 10100201 NOX 7.9017 7.8899 0.3945 0.00 0.95 SCR SCR added by LADCO 

 39 167 0684000000 R3 B003 B003P2 10100501 NOX 0.0000 0.0000 0.0000 0.00 0.95 SCR SCR added by LADCO 
18

 39 167 0684000000 R4 B004 B004P1 10100203 NOX 7.8775 7.8657 0.3933 0.00 0.95 SCR SCR added by LADCO 

 39 167 0684000000 R4 B004 B004P2 10100501 NOX 0.0000 0.0000 0.0000 0.00 0.95 SCR SCR added by LADCO 

 39 167 0684000000 R6 B006 B006P1 10100202 NOX 3.8586 3.8528 0.1926 0.00 0.95 SCR SCR added by LADCO 

 39 167 0684000000 R6 B006 B006P2 10100501 NOX 0.0000 0.0000 0.0000 0.00 0.95 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 25.4561 25.4182 1.2709 

cyid 25.4561 25.4182 1.2709 

stid 48.9375 48.8646 9.0864 

STID=55 CYID=79 fcid=241007800 name=WIS ELECTRIC POWER VALLEY STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 55 79 241007800 S11 B21 01 10100202 NOX 2.7972 2.8895 1.6470 0.00 0.43 SCR SCR added by LADCO 

 55 79 241007800 S11 B22 01 10100202 NOX 2.9073 3.0032 1.7118 0.00 0.43 SCR SCR added by LADCO 

 55 79 241007800 S12 B23 01 10100202 NOX 2.3270 2.4038 1.2740 0.00 0.47 SCR SCR added by LADCO 

 55 79 241007800 S12 B24 01 10100202 NOX 2.3427 2.4199 1.2826 0.00 0.47 SCR Scrubber added by LADCO

---- -------- -------- ----------

fcid 10.3742 10.7164 5.9154 

cyid 10.3742 10.7164 5.9154 

STID=55 CYID=117 fcid=460033090 name=WP & L Alliant Energy - Edgewater Gen Station

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 55 117 460033090 S11 B23 01 10100203 NOX 1.6197 1.6731 1.0038 0.00 0.40 SCR SCR added by LADCO 

 55 117 460033090 S11 B24 01 10100203 NOX 4.1072 4.2426 3.4789 0.00 0.18 SCR SCR added by LADCO 

 55 117 460033090 S12 B25 01 10100221 NOX 5.6804 5.8677 4.9876 0.00 0.15 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 11.4072 11.7834 9.4703 

cyid 11.4072 11.7834 9.4703 

stid 21.7814 22.4997 15.3857 

 ======== ======== ==========

 83.6581 84.7302 37.8380 
19

NOx - 2012

Point Source Grown and Controlled Emissions by facility for NOX r6s1b_2012 

Base Year = 2002

Future Year = 2012

STID=17 CYID=33 fcid=033801AAA name=AMEREN ENERGY GENERATING CO

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 33 033801AAA 0005 0005 01 10100202 NOX 1.642 1.871 0.9357 0.00 0.500 SCR SCR added by LADCO 

 17 33 033801AAA 0006 0006 01 10100202 NOX 2.116 2.413 1.2063 0.00 0.500 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 3.758 4.284 2.1420 

cyid 3.758 4.284 2.1420 

STID=17 CYID=57 fcid=057801AAA name=AES DUCK CREEK

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 57 057801AAA 0001 0001 01 10100202 NOX 0.815 0.929 0.9288 0.00 0.000 SCR SCR added by LADCO 

STID=17 CYID=79 fcid=079808AAA name=AMEREN ENERGY GENERATING CO

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 79 079808AAA 0003 0003 01 10100202 NOX 6.735 7.678 7.6780 0.00 0.000 SCR SCR added by LADCO 

 17 79 079808AAA 0012 0013 01 10100501 NOX 5.936 5.378 5.3781 0.00 0.000 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 12.671 13.056 13.0561 

cyid 12.671 13.056 13.0561 

STID=17 CYID=97 fcid=097190AAC name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 97 097190AAC 0016 0031 02 10100401 NOX 0.000 0.000 0.0000 0.00 0.999 SHUTDOWN SCR added by LADCO 

STID=17 CYID=137 fcid=137805AAA name=AMEREN ENERGY GENERATING CO

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 137 137805AAA 0003 0003 01 10100202 NOX 5.356 6.106 6.1058 0.00 0.000 LNB LNB added by LADCO 
20

STID=17 CYID=143 fcid=143805AAG name=AES ED EDWARDS STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 143 143805AAG 0001 0001 01 10100202 NOX 3.052 3.479 3.4789 0.00 0.000 lnb LNB added by LADCO 

 17 143 143805AAG 0001 0003 01 10100202 NOX 6.942 7.914 7.9141 0.00 0.000 lnb LNB added by LADCO 

 17 143 143805AAG 0002 0004 01 10100202 NOX 2.131 2.429 2.4294 0.00 0.000 lnb LNB added by LADCO 

---- -------- -------- ----------

fcid 12.124 13.822 13.8224 

cyid 12.124 13.822 13.8224 

STID=17 CYID=167 fcid=167120AAO name=CITY WATER LIGHT & POWER

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 167 167120AAO 0010 0012 01 10100203 NOX 6.527 7.441 0.0074 0.00 0.999 SHUTDOWN SHUTDOWN added by LADCO

 17 167 167120AAO 0010 0013 01 10100203 NOX 2.646 3.017 0.0030 0.00 0.999 SHUTDOWN SHUTDOWN added by LADCO

---- -------- -------- ----------

fcid 9.173 10.458 0.0105 

cyid 9.173 10.458 0.0105 

STID=17 CYID=179 fcid=179801AAA name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 179 179801AAA 0018 0029 01 10100203 NOX 22.429 25.570 1.2785 0.00 0.950 SCR SCR added by LADCO 

 17 179 179801AAA 0018 0031 01 10100203 NOX 38.993 44.454 2.2227 0.00 0.950 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 61.422 70.024 3.5012 

cyid 61.422 70.024 3.5012 

STID=17 CYID=197 fcid=197809AAO name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 197 197809AAO 0032 0033 02 10100604 NOX 0.000 0.000 0.0000 0.00 0.800 SCR SCR added by LADCO 

STID=17 CYID=197 fcid=197810AAK name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 197 197810AAK 0011 0016 02 10100222 NOX 5.731 6.534 3.9203 0.00 0.400 SCR SCR added by LADCO 

 17 197 197810AAK 0011 0016 03 10100501 NOX 0.000 0.000 0.0000 0.00 0.400 SCR SCR added by LADCO 

 17 197 197810AAK 0013 0010 02 10100223 NOX 8.598 9.802 0.0098 0.00 0.999 SHUTDOWN SCR added by LADCO 
21

 17 197 197810AAK 0013 0010 03 10100501 NOX 0.000 0.000 0.0000 0.00 0.999 SHUTDOWN SCR added by LADCO 

 17 197 197810AAK 0007 0012 02 10100223 NOX 10.974 12.511 0.0125 0.00 0.999 SHUTDOWN SCR added by LADCO 

 17 197 197810AAK 0007 0012 03 10100501 NOX 0.000 0.000 0.0000 0.00 0.999 SHUTDOWN SCR added by LADCO 

---- -------- -------- ----------

fcid 25.303 28.847 3.9426 

cyid 25.303 28.847 3.9426 

stid 130.622 147.527 43.5096 

STID=27 CYID=61 fcid=2706100004 name=Minnesota Power Inc - Boswell Energy Ctr

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 27 61 2706100004 SV003 EU003 001 10100226 NOX 13.661 14.142 2.8284 0.00 0.800 SCR SCR added by LADCO 

 27 61 2706100004 SV003 EU003 002 10100501 NOX 0.000 0.000 0.0000 0.00 0.800 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 13.661 14.142 2.8284 

cyid 13.661 14.142 2.8284 

STID=27 CYID=109 fcid=2710900011 name=Rochester Public Utilities - Silver Lake

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 27 109 2710900011 SV003 EU004 001 10100202 NOX 2.079 2.152 1.2911 0.00 0.400 SNCR SCR added by LADCO 

---- -------- -------- ----------

stid 15.739 16.294 4.1195 

STID=39 CYID=1 fcid=0701000007 name="DP&L, J.M. STUART GENERATING STATION"

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 1 0701000007 R1 B001 B001P1 10100202 NOX 6.986 7.296 2.4319 0.85 0.950 SCR SCR added by LADCO 

 39 1 0701000007 R2 B002 B002P1 10100202 NOX 3.633 3.794 1.2646 0.85 0.950 SCR SCR added by LADCO 

 39 1 0701000007 R3 B003 B003P1 10100202 NOX 5.013 5.235 1.7452 0.85 0.950 SCR SCR added by LADCO 

 39 1 0701000007 R4 B004 B004P1 10100202 NOX 7.849 8.197 2.7324 0.85 0.950 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 23.481 24.522 8.1740 

cyid 23.481 24.522 8.1740 

STID=39 CYID=31 fcid=0616000000 name=CONESVILLE POWER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 31 0616000000 R4 B004 B004P1 10100212 NOX 20.852 21.776 1.0888 0.00 0.950 SCR SCR added by LADCO 
22

STID=39 CYID=167 fcid=0684000000 name=MUSKINGUM RIVER POWER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 167 0684000000 R1 B001 B001P1 10200501 NOX 0.002 0.002 0.0001 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R2 B002 B002P1 10100201 NOX 5.817 6.074 0.3037 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R2 B002 B002P2 10100501 NOX 0.000 0.000 0.0000 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R3 B003 B003P1 10100201 NOX 7.902 8.252 0.4126 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R3 B003 B003P2 10100501 NOX 0.000 0.000 0.0000 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R4 B004 B004P1 10100203 NOX 7.877 8.227 0.4113 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R4 B004 B004P2 10100501 NOX 0.000 0.000 0.0000 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R6 B006 B006P1 10100202 NOX 3.859 4.030 0.2015 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R6 B006 B006P2 10100501 NOX 0.000 0.000 0.0000 0.00 0.950 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 25.456 26.584 1.3292 

cyid 25.456 26.584 1.3292 

stid 69.789 72.882 10.5920 

STID=55 CYID=79 fcid=241007690 name=WIS ELECTRIC POWER OAK CREEK STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 55 79 241007690 S13 B25 01 10100202 NOX 4.755 5.421 3.0898 0.00 0.430 SCR SCR added by LADCO 

 55 79 241007690 S13 B26 01 10100202 NOX 3.277 3.736 2.2045 0.00 0.410 SCR SCR added by LADCO 

 55 79 241007690 S14 B27 01 10100212 NOX 3.333 3.800 2.8499 0.00 0.250 SCR SCR added by LADCO 

 55 79 241007690 S14 B28 01 10100212 NOX 3.384 3.857 2.9316 0.00 0.240 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 14.749 16.814 11.0757 

STID=55 CYID=79 fcid=241007800 name=WIS ELECTRIC POWER VALLEY STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 55 79 241007800 S11 B21 01 10100202 NOX 2.797 3.189 1.8177 0.00 0.430 SCR SCR added by LADCO 

 55 79 241007800 S11 B22 01 10100202 NOX 2.907 3.314 1.8893 0.00 0.430 SCR SCR added by LADCO 

 55 79 241007800 S12 B23 01 10100202 NOX 2.327 2.653 1.4061 0.00 0.470 SCR SCR added by LADCO 

 55 79 241007800 S12 B24 01 10100202 NOX 2.343 2.671 1.4155 0.00 0.470 SCR Scrubber added by LADCO

---- -------- -------- ----------

fcid 10.374 11.827 6.5285 

cyid 25.123 28.641 17.6042 
23

STID=55 CYID=117 fcid=460033090 name=WP & L Alliant Energy - Edgewater Gen Station

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 55 117 460033090 S11 B23 01 10100203 NOX 1.620 1.846 1.1079 0.00 0.400 SCR SCR added by LADCO 

 55 117 460033090 S11 B24 01 10100203 NOX 4.107 4.682 3.8395 0.00 0.180 SCR SCR added by LADCO 

 55 117 460033090 S12 B25 01 10100221 NOX 5.680 6.476 5.5045 0.00 0.150 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 11.407 13.005 10.4519 

cyid 11.407 13.005 10.4519 

stid 36.530 41.646 28.0562 

 ======== ======== ==========

 252.681 278.349 86.2773 
24

NOx 2018

Point Source Grown and Controlled Emissions by facility for NOX r6s1b_2018 

Base Year = 2002

Future Year = 2018

STID=17 CYID=31 fcid=031600AIN name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 31 031600AIN 0010 0013 01 10100226 NOX 2.283 2.592 1.5550 0.00 0.400 SCR SCR added by LADCO 

 17 31 031600AIN 0010 0013 02 10100601 NOX 0.000 0.000 0.0000 0.00 0.400 SCR SCR added by LADCO 

 17 31 031600AIN 0012 0016 01 10100226 NOX 3.991 4.531 2.7184 0.00 0.400 SCR SCR added by LADCO 

 17 31 031600AIN 0012 0016 02 10100601 NOX 0.000 0.000 0.0000 0.00 0.400 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 6.274 7.122 4.2734 

cyid 6.274 7.122 4.2734 

STID=17 CYID=33 fcid=033801AAA name=AMEREN ENERGY GENERATING CO

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 33 033801AAA 0005 0005 01 10100202 NOX 1.642 1.863 0.9317 0.00 0.500 SCR SCR added by LADCO 

 17 33 033801AAA 0006 0006 01 10100202 NOX 2.116 2.402 1.2012 0.00 0.500 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 3.758 4.266 2.1329 

cyid 3.758 4.266 2.1329 

STID=17 CYID=57 fcid=057801AAA name=AES DUCK CREEK

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 57 057801AAA 0001 0001 01 10100202 NOX 0.815 0.925 0.9249 0.00 0.000 SCR SCR added by LADCO 

STID=17 CYID=79 fcid=079808AAA name=AMEREN ENERGY GENERATING CO

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 79 079808AAA 0003 0003 01 10100202 NOX 6.735 7.645 7.6453 0.00 0.000 SCR SCR added by LADCO 

 17 79 079808AAA 0012 0013 01 10100501 NOX 5.936 3.984 3.9838 0.00 0.000 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 12.671 11.629 11.6291 

cyid 12.671 11.629 11.6291 
25

STID=17 CYID=97 fcid=097190AAC name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 97 097190AAC 0016 0031 02 10100401 NOX 0.000 0.000 0.0000 0.00 0.999 SHUTDOWN SCR added by LADCO 

STID=17 CYID=137 fcid=137805AAA name=AMEREN ENERGY GENERATING CO

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 137 137805AAA 0003 0003 01 10100202 NOX 5.356 6.080 6.0798 0.00 0.000 LNB LNB added by LADCO 

STID=17 CYID=143 fcid=143805AAG name=AES ED EDWARDS STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 143 143805AAG 0001 0001 01 10100202 NOX 3.052 3.464 3.4641 0.00 0.000 lnb LNB added by LADCO 

 17 143 143805AAG 0001 0003 01 10100202 NOX 6.942 7.880 7.8804 0.00 0.000 lnb LNB added by LADCO 

 17 143 143805AAG 0002 0004 01 10100202 NOX 2.131 2.419 2.4191 0.00 0.000 lnb LNB added by LADCO 

---- -------- -------- ----------

fcid 12.124 13.764 13.7636 

cyid 12.124 13.764 13.7636 

STID=17 CYID=167 fcid=167120AAO name=CITY WATER LIGHT & POWER

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 167 167120AAO 0010 0012 01 10100203 NOX 6.527 7.410 0.0074 0.00 0.999 SHUTDOWN SHUTDOWN added by LADCO

 17 167 167120AAO 0010 0013 01 10100203 NOX 2.646 3.004 0.0030 0.00 0.999 SHUTDOWN SHUTDOWN added by LADCO

---- -------- -------- ----------

fcid 9.173 10.414 0.0104 

cyid 9.173 10.414 0.0104 

STID=17 CYID=179 fcid=179801AAA name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 179 179801AAA 0018 0029 01 10100203 NOX 22.429 25.462 1.2731 0.00 0.950 SCR SCR added by LADCO 

 17 179 179801AAA 0018 0031 01 10100203 NOX 38.993 44.265 2.2132 0.00 0.950 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 61.422 69.726 3.4863 

cyid 61.422 69.726 3.4863 
26

STID=17 CYID=197 fcid=197809AAO name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 197 197809AAO 0032 0033 02 10100604 NOX 0.000 0.000 0.0000 0.00 0.800 SCR SCR added by LADCO 

STID=17 CYID=197 fcid=197810AAK name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 197 197810AAK 0011 0016 02 10100222 NOX 5.731 6.506 3.9036 0.00 0.400 SCR SCR added by LADCO 

 17 197 197810AAK 0011 0016 03 10100501 NOX 0.000 0.000 0.0000 0.00 0.400 SCR SCR added by LADCO 

 17 197 197810AAK 0013 0010 02 10100223 NOX 8.598 9.760 0.0098 0.00 0.999 SHUTDOWN SCR added by LADCO 

 17 197 197810AAK 0013 0010 03 10100501 NOX 0.000 0.000 0.0000 0.00 0.999 SHUTDOWN SCR added by LADCO 

 17 197 197810AAK 0007 0012 02 10100223 NOX 10.974 12.458 0.0125 0.00 0.999 SHUTDOWN SCR added by LADCO 

 17 197 197810AAK 0007 0012 03 10100501 NOX 0.000 0.000 0.0000 0.00 0.999 SHUTDOWN SCR added by LADCO 

---- -------- -------- ----------

fcid 25.303 28.724 3.9258 

cyid 25.303 28.724 3.9258 

stid 136.896 152.649 46.2263 

STID=18 CYID=147 fcid=00020 name=INDIANA MICHIGAN POWER-ROCKPORT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 18 147 00020 1 001 01 10100222 NOX 23.226 25.291 1.2646 0.00 0.950 SCR SCR added by LADCO 

 18 147 00020 1 001 02 10100501 NOX 0.000 0.000 0.0000 0.00 0.950 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 23.226 25.291 1.2646 

cyid 23.226 25.291 1.2646 

stid 23.226 25.291 1.2646 

STID=27 CYID=61 fcid=2706100004 name=Minnesota Power Inc - Boswell Energy Ctr

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 27 61 2706100004 SV003 EU003 001 10100226 NOX 13.661 15.733 3.1466 0.00 0.800 SCR SCR added by LADCO 

 27 61 2706100004 SV003 EU003 002 10100501 NOX 0.000 0.000 0.0000 0.00 0.800 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 13.661 15.733 3.1466 

cyid 13.661 15.733 3.1466 
27

STID=27 CYID=109 fcid=2710900011 name=Rochester Public Utilities - Silver Lake

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 27 109 2710900011 SV003 EU004 001 10100202 NOX 2.079 2.394 1.4363 0.00 0.400 SNCR SCR added by LADCO 

---- -------- -------- ----------

stid 15.739 18.127 4.5830 

STID=39 CYID=1 fcid=0701000007 name="DP&L, J.M. STUART GENERATING STATION"

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 1 0701000007 R1 B001 B001P1 10100202 NOX 6.986 7.607 2.5358 0.85 0.950 SCR SCR added by LADCO 

 39 1 0701000007 R2 B002 B002P1 10100202 NOX 3.633 3.956 1.3186 0.85 0.950 SCR SCR added by LADCO 

 39 1 0701000007 R3 B003 B003P1 10100202 NOX 5.013 5.459 1.8197 0.85 0.950 SCR SCR added by LADCO 

 39 1 0701000007 R4 B004 B004P1 10100202 NOX 7.849 8.547 2.8491 0.85 0.950 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 23.481 25.570 8.5232 

cyid 23.481 25.570 8.5232 

STID=39 CYID=31 fcid=0616000000 name=CONESVILLE POWER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 31 0616000000 R4 B004 B004P1 10100212 NOX 20.852 22.706 1.1353 0.00 0.950 SCR SCR added by LADCO 

STID=39 CYID=167 fcid=0684000000 name=MUSKINGUM RIVER POWER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 167 0684000000 R1 B001 B001P1 10200501 NOX 0.002 0.002 0.0001 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R2 B002 B002P1 10100201 NOX 5.817 6.334 0.3167 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R2 B002 B002P2 10100501 NOX 0.000 0.000 0.0000 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R3 B003 B003P1 10100201 NOX 7.902 8.604 0.4302 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R3 B003 B003P2 10100501 NOX 0.000 0.000 0.0000 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R4 B004 B004P1 10100203 NOX 7.877 8.578 0.4289 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R4 B004 B004P2 10100501 NOX 0.000 0.000 0.0000 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R6 B006 B006P1 10100202 NOX 3.859 4.202 0.2101 0.00 0.950 SCR SCR added by LADCO 

 39 167 0684000000 R6 B006 B006P2 10100501 NOX 0.000 0.000 0.0000 0.00 0.950 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 25.456 27.720 1.3860 

cyid 25.456 27.720 1.3860 

stid 69.789 75.996 11.0445 
28

STID=54 CYID=39 fcid=0006 name=APPALACHIAN POWER - KANAWHA RIVER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 39 0006 012 001 99 10100202 NOX 4.829 5.258 2.6291 0.00 0.500 SCR Scrubber added by LADCO

 54 39 0006 012 002 99 10100202 NOX 4.921 5.359 2.6794 0.00 0.500 SCR Scrubber added by LADCO

---- -------- -------- ----------

fcid 9.750 10.617 5.3085 

cyid 9.750 10.617 5.3085 

stid 9.750 10.617 5.3085 

STID=55 CYID=79 fcid=241007690 name=WIS ELECTRIC POWER OAK CREEK STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 55 79 241007690 S13 B25 01 10100202 NOX 4.755 5.398 3.0766 0.00 0.430 SCR SCR added by LADCO 

 55 79 241007690 S13 B26 01 10100202 NOX 3.277 3.720 2.1951 0.00 0.410 SCR SCR added by LADCO 

 55 79 241007690 S14 B27 01 10100212 NOX 3.333 3.784 2.8378 0.00 0.250 SCR SCR added by LADCO 

 55 79 241007690 S14 B28 01 10100212 NOX 3.384 3.841 2.9191 0.00 0.240 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 14.749 16.743 11.0285 

STID=55 CYID=79 fcid=241007800 name=WIS ELECTRIC POWER VALLEY STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 55 79 241007800 S11 B21 01 10100202 NOX 2.797 3.175 1.4289 0.00 0.550 SCR SCR added by LADCO 

 55 79 241007800 S11 B22 01 10100202 NOX 2.907 3.300 1.4852 0.00 0.550 SCR SCR added by LADCO 

 55 79 241007800 S12 B23 01 10100202 NOX 2.327 2.642 1.1887 0.00 0.550 SCR SCR added by LADCO 

 55 79 241007800 S12 B24 01 10100202 NOX 2.343 2.659 1.1967 0.00 0.550 SCR SCR added by LADCO 

---- -------- -------- ----------

fcid 10.374 11.777 5.2995 

cyid 25.123 28.519 16.3281 

STID=55 CYID=117 fcid=460033090 name=WP & L Alliant Energy - Edgewater Gen Station

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 55 117 460033090 S11 B23 01 10100203 NOX 1.620 1.839 1.1032 0.00 0.400 SCR SCR added by LADCO 

 55 117 460033090 S11 B24 01 10100203 NOX 4.107 4.662 3.8232 0.00 0.180 SCR SCR added by LADCO 

 55 117 460033090 S12 B25 01 10100221 NOX 5.680 6.448 5.4811 0.00 0.150 SCR SCR added by LADCO 

---- -------- -------- ----------
29

fcid 11.407 12.949 10.4074 

cyid 11.407 12.949 10.4074 

stid 36.530 41.469 26.7355 

 ======== ======== ==========

 291.931 324.149 95.1624 
30

SO2 – 2009

Point Source Grown and Controlled Emissions by facility for SO2 r6s1b_2009 1

Base Year = 2002

Future Year = 2009

STID=19 CYID=115 fcid=58-07-001 name=MIDAMERICAN ENERGY CO. - LOUISA STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 19 115 58-07-001 117487 147281 99 10100222 SO2 33.664 34.774 3.4774 0.0 0.90 SCRUBBER Scrubber added by LADCO

STID=21 CYID=161 fcid=2116100009 name=EAST KY POWER COOP

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 21 161 2116100009 1 001 99 10100202 SO2 42.166 42.103 4.2103 0.0 0.90 SCRUBBER Scrubber added by LADCO

 21 161 2116100009 2 002 99 10100212 SO2 55.385 55.303 5.5303 0.0 0.90 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 97.551 97.406 9.7406 

cyid 97.551 97.406 9.7406 

stid 97.551 97.406 9.7406 

STID=27 CYID=141 fcid=2714100004 name=NSP - Sherburne Generating Plant

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 27 141 2714100004 SV001 EU001 001 10100222 SO2 16.765 16.987 3.6401 0.3 0.85 SCRUBBER Scrubber added by LADCO

 27 141 2714100004 SV001 EU002 001 10100222 SO2 22.549 22.848 4.8959 0.3 0.85 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 39.314 39.834 8.5360 

cyid 39.314 39.834 8.5360 

stid 39.314 39.834 8.5360 

STID=54 CYID=51 fcid=0005 name=OHIO POWER - MITCHELL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 51 0005 012 001 99 10100202 SO2 17.775 17.748 1.7748 0.0 0.90 SCRUBBER Scrubber added by LADCO

 54 51 0005 012 002 99 10100202 SO2 5.689 5.680 0.5680 0.0 0.90 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 23.463 23.428 2.3428 

cyid 23.463 23.428 2.3428 
31

STID=54 CYID=53 fcid=0009 name=APPALACHIAN POWER - MOUNTAINEER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 53 0009 001 001 99 10100202 SO2 11.196 11.179 1.1179 0.0 0.90 SCRUBBER Scrubber added by LADCO

STID=54 CYID=79 fcid=0006 name=APPALACHIAN POWER - JOHN E AMOS PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 79 0006 012 001 99 10100202 SO2 79.635 79.516 7.9516 0.0 0.90 SCRUBBER Scrubber added by LADCO

 54 79 0006 003 003 99 10100202 SO2 139.377 139.169 13.9169 0.0 0.90 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 219.012 218.685 21.8685 

cyid 219.012 218.685 21.8685 

stid 253.671 253.293 25.3293 

 ======== ======== ==========

 424.200 425.307 47.0832 
32

SO2 – 2012

Point Source Grown and Controlled Emissions by facility for SO2 r6s1b_2012 1

Base Year = 2002

Future Year = 2012

STID=17 CYID=31 fcid=031600AMI name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 31 031600AMI 0007 0010 01 10100226 SO2 16.13 18.39 1.839 0.0 0.900 SCRUBBER Scrubber added by LADCO

STID=17 CYID=97 fcid=097190AAC name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 97 097190AAC 0018 0033 01 10100226 SO2 24.14 27.52 2.752 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 97 097190AAC 0021 0036 01 10100226 SO2 19.23 21.92 2.192 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 97 097190AAC 0016 0031 01 10100203 SO2 4.59 5.24 0.005 0.0 0.999 SHUTDOWN Scrubber added by LADCO

---- -------- -------- ----------

fcid 47.96 54.68 4.950 

cyid 47.96 54.68 4.950 

STID=17 CYID=125 fcid=125804AAB name=DYNEGY MIDWEST GENERATION INC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 125 125804AAB 0019 0023 01 10100202 SO2 22.34 25.47 3.821 0.0 0.850 SCRUBBER Scrubber added by LADCO

STID=17 CYID=127 fcid=127855AAC name=ELECTRIC ENERGY INC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 127 127855AAC 0001 0001 01 10100222 SO2 11.83 13.48 13.482 0.0 0.000 LNB LNB added by LADCO 

 17 127 127855AAC 0001 0002 01 10100222 SO2 11.48 13.09 13.085 0.0 0.000 LNB LNB added by LADCO 

 17 127 127855AAC 0002 0003 01 10100222 SO2 10.25 11.68 11.680 0.0 0.000 LNB LNB added by LADCO 

 17 127 127855AAC 0002 0004 01 10100222 SO2 12.04 13.73 13.731 0.0 0.000 LNB LNB added by LADCO 

 17 127 127855AAC 0003 0006 01 10100222 SO2 12.68 14.46 14.456 0.0 0.000 LNB LNB added by LADCO 

---- -------- -------- ----------

fcid 58.27 66.43 66.435 

cyid 58.27 66.43 66.435 
33

STID=17 CYID=135 fcid=135803AAA name=AMEREN ENERGY GENERATING CO

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 135 135803AAA 0001 0001 01 10100203 SO2 32.99 37.61 3.761 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 135 135803AAA 0001 0003 01 10100203 SO2 72.92 83.13 8.313 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 105.91 120.74 12.074 

cyid 105.91 120.74 12.074 

STID=17 CYID=157 fcid=157851AAA name=DYNEGY MIDWEST GENERATION INC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 157 157851AAA 0001 0001 01 10100203 SO2 25.14 28.66 4.299 0.0 0.850 SCRUBBER Scrubber added by LADCO

 17 157 157851AAA 0002 0002 01 10100203 SO2 25.79 29.41 4.411 0.0 0.850 SCRUBBER Scrubber added by LADCO

 17 157 157851AAA 0013 0013 01 10100202 SO2 27.79 31.68 4.752 0.0 0.850 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 78.72 89.75 13.462 

cyid 78.72 89.75 13.462 

STID=17 CYID=167 fcid=167120AAO name=CITY WATER LIGHT & POWER

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 167 167120AAO 0010 0012 01 10100203 SO2 44.20 50.39 0.050 0.0 0.999 SHUTDOWN Scrubber added by LADCO

 17 167 167120AAO 0010 0013 01 10100203 SO2 16.40 18.70 0.019 0.0 0.999 SHUTDOWN Scrubber added by LADCO

---- -------- -------- ----------

fcid 60.61 69.10 0.069 

cyid 60.61 69.10 0.069 

STID=17 CYID=179 fcid=179801AAA name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 179 179801AAA 0018 0029 01 10100203 SO2 25.35 28.90 2.890 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 179 179801AAA 0018 0031 01 10100203 SO2 41.57 47.39 4.739 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 66.91 76.29 7.629 

cyid 66.91 76.29 7.629 

STID=17 CYID=197 fcid=197810AAK name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes
34

 17 197 197810AAK 0013 0010 03 10100501 SO2 0.00 0.00 0.000 0.0 0.999 SHUTDOWN Scrubber added by LADCO

 17 197 197810AAK 0007 0012 02 10100223 SO2 15.33 17.48 0.017 0.0 0.999 SHUTDOWN Scrubber added by LADCO

 17 197 197810AAK 0007 0012 03 10100501 SO2 0.00 0.00 0.000 0.0 0.999 SHUTDOWN Scrubber added by LADCO

---- -------- -------- ----------

fcid 15.33 17.48 0.017 

cyid 15.33 17.48 0.017 

stid 472.19 538.32 110.295 

STID=19 CYID=115 fcid=58-07-001 name=MIDAMERICAN ENERGY CO. - LOUISA STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 19 115 58-07-001 117487 147281 99 10100222 SO2 33.66 38.38 3.838 0.0 0.900 SCRUBBER Scrubber added by LADCO

STID=21 CYID=161 fcid=2116100009 name=EAST KY POWER COOP

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 21 161 2116100009 1 001 99 10100202 SO2 42.17 44.03 4.403 0.0 0.900 SCRUBBER Scrubber added by LADCO

 21 161 2116100009 2 002 99 10100212 SO2 55.39 57.84 5.784 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 97.55 101.87 10.187 

cyid 97.55 101.87 10.187 

stid 97.55 101.87 10.187 

STID=27 CYID=61 fcid=2706100004 name=Minnesota Power Inc - Boswell Energy Ctr

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 27 61 2706100004 SV003 EU003 001 10100226 SO2 33.99 35.19 15.081 0.3 0.700 SCRUBBER Scrubber added by LADCO

 27 61 2706100004 SV003 EU003 002 10100501 SO2 0.00 0.00 0.000 0.3 0.700 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 33.99 35.19 15.081 

cyid 33.99 35.19 15.081 

STID=27 CYID=109 fcid=2710900011 name=Rochester Public Utilities - Silver Lake

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 27 109 2710900011 SV003 EU004 001 10100202 SO2 7.86 8.13 1.220 0.0 0.850 SCRUBBER Scrubber added by LADCO
35

STID=27 CYID=141 fcid=2714100004 name=NSP - Sherburne Generating Plant

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 27 141 2714100004 SV001 EU001 001 10100222 SO2 16.76 17.36 3.719 0.3 0.850 SCRUBBER Scrubber added by LADCO

 27 141 2714100004 SV001 EU002 001 10100222 SO2 22.55 23.34 5.002 0.3 0.850 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 39.31 40.70 8.721 

cyid 39.31 40.70 8.721 

stid 81.16 84.02 25.023 

STID=39 CYID=13 fcid=0607130015 name=R. E. BURGER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 13 0607130015 R6 B011 B011P1 10100202 SO2 29.83 31.15 3.115 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 13 0607130015 R7 B012 B012P1 10100202 SO2 34.77 36.31 3.631 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 64.60 67.46 6.746 

cyid 64.60 67.46 6.746 

STID=39 CYID=31 fcid=0616000000 name=CONESVILLE POWER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 31 0616000000 R4 B004 B004P1 10100212 SO2 316.00 330.00 33.000 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

stid 380.60 397.46 39.746 

STID=47 CYID=1 fcid=0009 name=TVA BULL RUN FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 1 0009 S-1 001 99 10100212 SO2 130.81 133.01 13.301 0.0 0.900 SCRUBBER Scrubber added by LADCO

STID=47 CYID=73 fcid=0007 name=TVA JOHN SEVIER FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 73 0007 S-1A 001 99 10100212 SO2 20.15 20.49 2.049 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 73 0007 S-1B 002 99 10100212 SO2 20.25 20.59 2.059 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 73 0007 S-2A 003 99 10100212 SO2 19.62 19.95 1.995 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 73 0007 S-2B 004 99 10100212 SO2 18.93 19.25 1.925 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------
36

fcid 78.95 80.28 8.028 

cyid 78.95 80.28 8.028 

STID=47 CYID=85 fcid=0011 name=TVA JOHNSONVILLE FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 85 0011 S1-01 001 99 10100212 SO2 17.06 17.35 1.735 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 85 0011 S1-04 004 99 10100212 SO2 19.85 20.18 2.018 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 85 0011 S1-05 005 99 10100212 SO2 24.11 24.52 2.452 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 61.02 62.04 6.204 

cyid 61.02 62.04 6.204 

STID=47 CYID=145 fcid=0013 name=TVA KINGSTON FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 145 0013 S-1 001 99 10100202 SO2 12.68 12.89 1.289 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-1 002 99 10100202 SO2 14.00 14.24 1.424 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-1 003 99 10100202 SO2 13.80 14.04 1.404 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-1 004 99 10100202 SO2 12.24 12.44 1.244 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-1 005 99 10100202 SO2 19.57 19.90 1.990 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-2 006 99 10100202 SO2 18.92 19.24 1.924 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-2 007 99 10100202 SO2 21.30 21.66 2.166 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-2 008 99 10100202 SO2 18.54 18.85 1.885 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-2 009 99 10100202 SO2 20.72 21.07 2.107 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 151.77 154.33 15.433 

cyid 151.77 154.33 15.433 

STID=47 CYID=165 fcid=0025 name=TVA GALLATIN FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 165 0025 S-01 001 99 10100212 SO2 13.91 14.14 1.414 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 165 0025 S-01 002 99 10100212 SO2 14.87 15.12 1.512 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 165 0025 S-02 003 99 10100212 SO2 16.33 16.60 1.660 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 165 0025 S-02 004 99 10100212 SO2 20.39 20.73 2.073 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 65.49 66.59 6.659 

cyid 65.49 66.59 6.659 

stid 488.04 496.25 49.625 
37

STID=54 CYID=51 fcid=0005 name=OHIO POWER - MITCHELL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 51 0005 012 001 99 10100202 SO2 17.77 18.56 1.856 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 51 0005 012 002 99 10100202 SO2 5.69 5.94 0.594 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 23.46 24.50 2.450 

cyid 23.46 24.50 2.450 

STID=54 CYID=53 fcid=0009 name=APPALACHIAN POWER - MOUNTAINEER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 53 0009 001 001 99 10100202 SO2 11.20 11.69 1.169 0.0 0.900 SCRUBBER Scrubber added by LADCO

STID=54 CYID=79 fcid=0006 name=APPALACHIAN POWER - JOHN E AMOS PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 79 0006 012 001 99 10100202 SO2 79.63 83.16 8.316 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 79 0006 012 002 99 10100202 SO2 100.33 104.78 10.478 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 79 0006 003 003 99 10100202 SO2 139.38 145.55 14.555 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 319.35 333.50 33.350 

cyid 319.35 333.50 33.350 

stid 354.00 369.69 36.969 

STID=55 CYID=79 fcid=241007690 name=WIS ELECTRIC POWER OAK CREEK STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 55 79 241007690 S13 B25 01 10100202 SO2 12.75 14.54 3.490 0.0 0.760 SCRUBBER Scrubber added by LADCO

 55 79 241007690 S13 B26 01 10100202 SO2 8.68 9.89 2.473 0.0 0.750 SCRUBBER Scrubber added by LADCO

 55 79 241007690 S14 B27 01 10100212 SO2 10.97 12.51 2.876 0.0 0.770 SCRUBBER Scrubber added by LADCO

 55 79 241007690 S14 B28 01 10100212 SO2 11.28 12.86 2.958 0.0 0.770 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 43.68 49.80 11.797 

cyid 43.68 49.80 11.797 

stid 43.68 49.80 11.797 

 ======== ======== ==========

 1950.90 2075.80 287.480 
38

SO2 – 2018

Point Source Grown and Controlled Emissions by facility for SO2 r6s1b_2018 1

Base Year = 2002

Future Year = 2018

STID=17 CYID=31 fcid=031600AIN name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 31 031600AIN 0010 0013 01 10100226 SO2 10.92 12.39 1.239 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 31 031600AIN 0012 0016 01 10100226 SO2 17.69 20.08 2.008 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 28.61 32.48 3.248 

STID=17 CYID=31 fcid=031600AMI name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 31 031600AMI 0007 0010 01 10100226 SO2 16.13 18.31 1.831 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

cyid 44.74 50.79 5.079 

STID=17 CYID=79 fcid=079808AAA name=AMEREN ENERGY GENERATING CO

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 79 079808AAA 0003 0003 01 10100202 SO2 36.35 41.27 4.127 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 79 079808AAA 0012 0013 01 10100501 SO2 28.99 19.46 1.946 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 65.34 60.72 6.072 

cyid 65.34 60.72 6.072 

STID=17 CYID=97 fcid=097190AAC name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 97 097190AAC 0018 0033 01 10100226 SO2 24.14 27.40 2.740 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 97 097190AAC 0021 0036 01 10100226 SO2 19.23 21.83 2.183 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 97 097190AAC 0016 0031 01 10100203 SO2 4.59 5.22 0.005 0.0 0.999 SHUTDOWN Scrubber added by LADCO

---- -------- -------- ----------

fcid 47.96 54.45 4.928 

cyid 47.96 54.45 4.928 
39

STID=17 CYID=125 fcid=125804AAB name=DYNEGY MIDWEST GENERATION INC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 125 125804AAB 0019 0023 01 10100202 SO2 22.34 25.36 3.805 0.0 0.850 SCRUBBER Scrubber added by LADCO

STID=17 CYID=127 fcid=127855AAC name=ELECTRIC ENERGY INC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 127 127855AAC 0002 0003 01 10100222 SO2 10.25 11.63 11.630 0.0 0.000 LNB LNB added by LADCO 

 17 127 127855AAC 0002 0004 01 10100222 SO2 12.04 13.67 13.673 0.0 0.000 LNB LNB added by LADCO 

 17 127 127855AAC 0001 0001 01 10100222 SO2 11.83 13.42 1.342 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 127 127855AAC 0001 0002 01 10100222 SO2 11.48 13.03 1.303 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 127 127855AAC 0003 0005 01 10100222 SO2 11.72 13.31 1.331 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 127 127855AAC 0003 0006 01 10100222 SO2 12.68 14.39 1.439 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 70.00 79.46 30.719 

cyid 70.00 79.46 30.719 

STID=17 CYID=135 fcid=135803AAA name=AMEREN ENERGY GENERATING CO

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 135 135803AAA 0001 0001 01 10100203 SO2 32.99 37.45 3.745 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 135 135803AAA 0001 0003 01 10100203 SO2 72.92 82.77 8.277 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 105.91 120.22 12.022 

cyid 105.91 120.22 12.022 

STID=17 CYID=143 fcid=143805AAG name=AES ED EDWARDS STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 143 143805AAG 0002 0004 01 10100202 SO2 15.28 17.34 1.734 0.0 0.900 SCRUBBER Scrubber added by LADCO

STID=17 CYID=157 fcid=157851AAA name=DYNEGY MIDWEST GENERATION INC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 157 157851AAA 0001 0001 01 10100203 SO2 25.14 28.54 4.281 0.0 0.850 SCRUBBER Scrubber added by LADCO

 17 157 157851AAA 0002 0002 01 10100203 SO2 25.79 29.28 4.392 0.0 0.850 SCRUBBER Scrubber added by LADCO

 17 157 157851AAA 0013 0013 01 10100202 SO2 27.79 31.54 4.732 0.0 0.850 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------
40

fcid 78.72 89.36 13.404 

cyid 78.72 89.36 13.404 

STID=17 CYID=167 fcid=167120AAO name=CITY WATER LIGHT & POWER

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 167 167120AAO 0010 0012 01 10100203 SO2 44.20 50.18 0.050 0.0 0.999 SHUTDOWN Scrubber added by LADCO

 17 167 167120AAO 0010 0013 01 10100203 SO2 16.40 18.62 0.019 0.0 0.999 SHUTDOWN Scrubber added by LADCO

---- -------- -------- ----------

fcid 60.61 68.80 0.069 

cyid 60.61 68.80 0.069 

STID=17 CYID=179 fcid=179801AAA name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 179 179801AAA 0018 0029 01 10100203 SO2 25.35 28.77 2.877 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 179 179801AAA 0018 0031 01 10100203 SO2 41.57 47.19 4.719 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 66.91 75.96 7.596 

cyid 66.91 75.96 7.596 

STID=17 CYID=197 fcid=197809AAO name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 197 197809AAO 0006 0009 01 10100203 SO2 15.89 18.04 1.804 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 197 197809AAO 0016 0031 01 10100202 SO2 27.43 31.13 3.113 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 197 197809AAO 0017 0033 01 10100202 SO2 23.13 26.26 2.626 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 66.45 75.44 7.544 

STID=17 CYID=197 fcid=197810AAK name=MIDWEST GENERATION LLC

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 17 197 197810AAK 0009 0014 02 10100222 SO2 11.64 13.21 1.321 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 197 197810AAK 0011 0016 02 10100222 SO2 25.67 29.14 2.914 0.0 0.900 SCRUBBER Scrubber added by LADCO

 17 197 197810AAK 0013 0010 03 10100501 SO2 0.00 0.00 0.000 0.0 0.999 SHUTDOWN Scrubber added by LADCO

 17 197 197810AAK 0007 0012 02 10100223 SO2 15.33 17.40 0.017 0.0 0.999 SHUTDOWN Scrubber added by LADCO

 17 197 197810AAK 0007 0012 03 10100501 SO2 0.00 0.00 0.000 0.0 0.999 SHUTDOWN Scrubber added by LADCO

---- -------- -------- ----------

fcid 52.64 59.75 4.252 
41

cyid 119.09 135.19 11.796 

stid 696.90 777.66 97.225 

STID=18 CYID=147 fcid=00020 name=INDIANA MICHIGAN POWER-ROCKPORT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 18 147 00020 1 001 01 10100222 SO2 66.42 72.32 7.232 0.0 0.900 SCRUBBER Scrubber added by LADCO

 18 147 00020 1 001 02 10100501 SO2 0.00 0.00 0.000 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 66.42 72.32 7.232 

cyid 66.42 72.32 7.232 

stid 66.42 72.32 7.232 

STID=19 CYID=115 fcid=58-07-001 name=MIDAMERICAN ENERGY CO. - LOUISA STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 19 115 58-07-001 117487 147281 99 10100222 SO2 33.66 38.22 3.822 0.0 0.900 SCRUBBER Scrubber added by LADCO

STID=21 CYID=127 fcid=2112700003 name=KENTUCKY POWER CO

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 21 127 2112700003 2 002 99 10100202 SO2 104.52 113.82 11.382 0.0 0.900 SCRUBBER Scrubber added by LADCO

STID=21 CYID=161 fcid=2116100009 name=EAST KY POWER COOP

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 21 161 2116100009 1 001 99 10100202 SO2 42.17 45.92 4.592 0.0 0.900 SCRUBBER Scrubber added by LADCO

 21 161 2116100009 2 002 99 10100212 SO2 55.39 60.31 6.031 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 97.55 106.23 10.623 

cyid 97.55 106.23 10.623 

stid 202.07 220.04 22.004 

STID=27 CYID=61 fcid=2706100004 name=Minnesota Power Inc - Boswell Energy Ctr

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 27 61 2706100004 SV003 EU003 001 10100226 SO2 33.99 39.15 16.778 0.3 0.700 SCRUBBER Scrubber added by LADCO

 27 61 2706100004 SV003 EU003 002 10100501 SO2 0.00 0.00 0.000 0.3 0.700 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------
42

fcid 33.99 39.15 16.778 

cyid 33.99 39.15 16.778 

STID=27 CYID=109 fcid=2710900011 name=Rochester Public Utilities - Silver Lake

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 27 109 2710900011 SV003 EU004 001 10100202 SO2 7.86 9.05 1.357 0.0 0.850 SCRUBBER Scrubber added by LADCO

STID=27 CYID=141 fcid=2714100004 name=NSP - Sherburne Generating Plant

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 27 141 2714100004 SV001 EU001 001 10100222 SO2 16.76 19.31 4.138 0.3 0.850 SCRUBBER Scrubber added by LADCO

 27 141 2714100004 SV001 EU002 001 10100222 SO2 22.55 25.97 5.565 0.3 0.850 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 39.31 45.28 9.703 

cyid 39.31 45.28 9.703 

stid 81.16 93.48 27.838 

STID=39 CYID=13 fcid=0607130015 name=R. E. BURGER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 13 0607130015 R6 B011 B011P1 10100202 SO2 29.83 32.48 3.248 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 13 0607130015 R7 B012 B012P1 10100202 SO2 34.77 37.86 3.786 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 64.60 70.34 7.034 

cyid 64.60 70.34 7.034 

STID=39 CYID=31 fcid=0616000000 name=CONESVILLE POWER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 31 0616000000 R4 B004 B004P1 10100212 SO2 316.00 344.11 34.411 0.0 0.900 SCRUBBER Scrubber added by LADCO

STID=39 CYID=167 fcid=0684000000 name=MUSKINGUM RIVER POWER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 39 167 0684000000 R2 B002 B002P1 10100201 SO2 65.07 70.85 7.085 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R2 B002 B002P2 10100501 SO2 0.00 0.00 0.000 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R3 B003 B003P1 10100201 SO2 94.58 103.00 10.300 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R3 B003 B003P2 10100501 SO2 0.00 0.00 0.000 0.0 0.900 SCRUBBER Scrubber added by LADCO
43

 39 167 0684000000 R4 B004 B004P1 10100203 SO2 81.64 88.90 8.890 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R4 B004 B004P2 10100501 SO2 0.00 0.00 0.000 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R5 B005 B005P1 10100203 SO2 97.22 105.87 10.587 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R5 B005 B005P2 10100501 SO2 0.00 0.00 0.000 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R6 B006 B006P1 10100202 SO2 113.96 124.10 12.410 0.0 0.900 SCRUBBER Scrubber added by LADCO

 39 167 0684000000 R6 B006 B006P2 10100501 SO2 0.00 0.00 0.000 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 452.48 492.72 49.272 

cyid 452.48 492.72 49.272 

stid 833.08 907.16 90.716 

STID=47 CYID=1 fcid=0009 name=TVA BULL RUN FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 1 0009 S-1 001 99 10100212 SO2 130.81 136.82 13.682 0.0 0.900 SCRUBBER Scrubber added by LADCO

STID=47 CYID=73 fcid=0007 name=TVA JOHN SEVIER FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 73 0007 S-1A 001 99 10100212 SO2 20.15 21.07 2.107 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 73 0007 S-1B 002 99 10100212 SO2 20.25 21.18 2.118 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 73 0007 S-2A 003 99 10100212 SO2 19.62 20.52 2.052 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 73 0007 S-2B 004 99 10100212 SO2 18.93 19.80 1.980 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 78.95 82.57 8.257 

cyid 78.95 82.57 8.257 

STID=47 CYID=85 fcid=0011 name=TVA JOHNSONVILLE FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 85 0011 S1-01 001 99 10100212 SO2 17.06 17.84 1.784 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 85 0011 S1-04 004 99 10100212 SO2 19.85 20.76 2.076 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 85 0011 S1-05 005 99 10100212 SO2 24.11 25.22 2.522 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 61.02 63.82 6.382 

cyid 61.02 63.82 6.382 
44

STID=47 CYID=145 fcid=0013 name=TVA KINGSTON FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 145 0013 S-1 001 99 10100202 SO2 12.68 13.26 1.326 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-1 002 99 10100202 SO2 14.00 14.65 1.465 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-1 003 99 10100202 SO2 13.80 14.44 1.444 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-1 004 99 10100202 SO2 12.24 12.80 1.280 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-1 005 99 10100202 SO2 19.57 20.47 2.047 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-2 006 99 10100202 SO2 18.92 19.79 1.979 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-2 007 99 10100202 SO2 21.30 22.28 2.228 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-2 008 99 10100202 SO2 18.54 19.39 1.939 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 145 0013 S-2 009 99 10100202 SO2 20.72 21.68 2.168 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 151.77 158.75 15.875 

cyid 151.77 158.75 15.875 

STID=47 CYID=165 fcid=0025 name=TVA GALLATIN FOSSIL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 47 165 0025 S-01 001 99 10100212 SO2 13.91 14.54 1.454 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 165 0025 S-01 002 99 10100212 SO2 14.87 15.56 1.556 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 165 0025 S-02 003 99 10100212 SO2 16.33 17.08 1.708 0.0 0.900 SCRUBBER Scrubber added by LADCO

 47 165 0025 S-02 004 99 10100212 SO2 20.39 21.32 2.132 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 65.49 68.50 6.850 

cyid 65.49 68.50 6.850 

stid 488.04 510.46 51.046 

STID=54 CYID=39 fcid=0006 name=APPALACHIAN POWER - KANAWHA RIVER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 39 0006 012 001 99 10100202 SO2 19.45 21.18 10.591 0.0 0.500 SCRUBBER Scrubber added by LADCO

 54 39 0006 012 002 99 10100202 SO2 20.94 22.80 11.399 0.0 0.500 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 40.39 43.98 21.990 

cyid 40.39 43.98 21.990 
45

STID=54 CYID=51 fcid=0005 name=OHIO POWER - MITCHELL PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 51 0005 012 001 99 10100202 SO2 17.77 19.36 1.936 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 51 0005 012 002 99 10100202 SO2 5.69 6.19 0.619 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 23.46 25.55 2.555 

STID=54 CYID=51 fcid=0006 name=OHIO POWER - KAMMER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 51 0006 013 001 99 10100203 SO2 47.06 51.25 5.125 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 51 0006 013 002 99 10100203 SO2 47.66 51.90 5.190 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 51 0006 013 003 99 10100203 SO2 41.94 45.67 4.567 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 136.67 148.82 14.882 

cyid 160.13 174.37 17.437 

STID=54 CYID=53 fcid=0001 name=APPALACHIAN POWER CO.-PHILIP SPORN PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 53 0001 014 001 99 10100202 SO2 18.65 20.31 2.031 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 53 0001 014 002 99 10100202 SO2 15.87 17.28 1.728 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 53 0001 014 003 99 10100202 SO2 21.46 23.36 2.336 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 53 0001 014 004 99 10100202 SO2 20.53 22.36 2.236 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 53 0001 005 005 99 10100202 SO2 46.82 50.98 5.098 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 123.33 134.30 13.430 

STID=54 CYID=53 fcid=0009 name=APPALACHIAN POWER - MOUNTAINEER PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 54 53 0009 001 001 99 10100202 SO2 11.20 12.19 1.219 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

cyid 134.53 146.49 14.649 

STID=54 CYID=79 fcid=0006 name=APPALACHIAN POWER - JOHN E AMOS PLANT

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes
46

 54 79 0006 012 001 99 10100202 SO2 79.63 86.72 8.672 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 79 0006 012 002 99 10100202 SO2 100.33 109.26 10.926 0.0 0.900 SCRUBBER Scrubber added by LADCO

 54 79 0006 003 003 99 10100202 SO2 139.38 151.77 15.177 0.0 0.900 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 319.35 347.75 34.775 

cyid 319.35 347.75 34.775 

stid 654.39 712.59 88.851 

STID=55 CYID=79 fcid=241007690 name=WIS ELECTRIC POWER OAK CREEK STATION

 Base Yr Grown Controlled Base Year Future Year

STID CYID fcid stkid dvid prid scc polid Tons/Day Tons/Day Tons/Day Control EF Control EF ctrltype ctrldes

 55 79 241007690 S13 B25 01 10100202 SO2 12.75 14.48 3.475 0.0 0.760 SCRUBBER Scrubber added by LADCO

 55 79 241007690 S13 B26 01 10100202 SO2 8.68 9.85 2.462 0.0 0.750 SCRUBBER Scrubber added by LADCO

 55 79 241007690 S14 B27 01 10100212 SO2 10.97 12.45 2.864 0.0 0.770 SCRUBBER Scrubber added by LADCO

 55 79 241007690 S14 B28 01 10100212 SO2 11.28 12.81 2.945 0.0 0.770 SCRUBBER Scrubber added by LADCO

---- -------- -------- ----------

fcid 43.68 49.59 11.746 

cyid 43.68 49.59 11.746 

stid 43.68 49.59 11.746 

 ======== ======== ==========

 3099.41 3381.52 400.481 
47

 

Appendix II

Scenario C Controls (CAMD List)
48

NOx Controls (SCRs, 2007 – 2013))

Plant Name UniqueID_Final State Name County

Capacity 

MW

On Line 

Year

SCR 

Online 

Year

Chesterfield 3797_B_4 Virginia Chesterfield 166 1960 2013

Chesterfield 3797_B_5 Virginia Chesterfield 310 1964 2012

Scherer 6257_B_3 Georgia Monroe 875 1987 2011

Chesterfield 3797_B_6 Virginia Chesterfield 658 1969 2011

Sandow No 4 6648_B_4 Texas Milam 545 1981 2011

Beech Hollow Power Project 82704_B_1 Pennsylvania Washington 272 2011 2011

Longview Power 82702_B_1 West Virginia Monongalia 695 2011 2011

Cliffside 2721_B_6 North Carolina Cleveland 800 2011 2011

AES Westover 2526_B_11 New York Broome 22 1943 2010

AES Westover 2526_B_12 New York Broome 22 1943 2010

AES Westover 2526_B_13 New York Broome 84 1951 2010

Iatan 2 6065_B_2 Missouri Platte 850 2010 2010

Southwest 6195_B_2 Missouri Greene 300 2010 2010

Trimble Station (LGE) 6071_B_2 Kentucky Trimble 732 2010 2010

Elm Road Generating Station 56068_B_2 Wisconsin Milwaukee 615 2010 2010

Clay Boswell 1893_B_3 Minnesota Itasca 350 1973 2009

Asheville 2706_B_2 North Carolina Buncombe 184 1971 2009

Conesville 2840_B_4 Ohio Coshocton 780 1973 2009

Marshall 2727_B_3 North Carolina Catawba 657 1969 2009

St Johns River Power Park 207_B_1 Florida Duval 626 1987 2009

Ghent 1356_B_2 Kentucky Carroll 469 1977 2009

Chalk Point LLC 1571_B_1 Maryland Prince George's 341 1964 2009

Chalk Point LLC 1571_B_2 Maryland Prince George's 342 1965 2009

San Juan 2451_B_2 New Mexico San Juan 320 1973 2009

Big Bend 645_B_BB01 Florida Hillsborough 411 1970 2009

Big Bend 645_B_BB02 Florida Hillsborough 391 1973 2009

Big Bend 645_B_BB03 Florida Hillsborough 414 1976 2009

Nebraska City Unit 2 6096_B_2 Nebraska Otoe 663 2009 2009

Cross 130_B_4 South Carolina Berkeley 652 2009 2009

Springerville 8223_B_4 Arizona Apache 400 2009 2009

Sandow 5 82010_B_5 Texas Milam 600 2009 2009

Oak Grove 82011_B_1 Texas Robertson 800 2009 2009

Oak Grove 82011_B_2 Texas Robertson 800 2009 2009

TS Power Plant 82013_B_1 Nevada Eureka 200 2009 2009

Plum Point Energy 82014_B_1 Arkansas Mississippi 665 2009 2009

Comanche 470_B_3 Colorado Pueblo 750 2009 2009

Elm Road Generating Station 56068_B_1 Wisconsin Milwaukee 615 2009 2009

Two Elk Generating Station 55360_B_1 Wyoming Campbell 300 2009 2009

J K Spruce 7097_B_BLR2 Texas Bexar 750 2009 2009

Dallman 963_B_34 Illinois Sangamon 200 2009 2009

AES Greenidge LLC 2527_B_4 New York Yates 27 1950 2008

AES Greenidge LLC 2527_B_5 New York Yates 27 1950 2008

AES Greenidge LLC 2527_B_6 New York Yates 106 1953 2008

Charles R Lowman 56_B_2 Alabama Washington 238 1979 2008

Charles R Lowman 56_B_3 Alabama Washington 238 1980 2008

Barry 3_B_5 Alabama Mobile 750 1971 2008

St Johns River Power Park 207_B_2 Florida Duval 626 1988 2008

Morgantown Generating Plant 1573_B_2 Maryland Charles 620 1971 2008
49

Bailly 995_B_7 Indiana Porter 160 1962 2008

San Juan 2451_B_1 New Mexico San Juan 322 1976 2008

San Juan 2451_B_3 New Mexico San Juan 495 1979 2008

Weston 4078_B_4 Wisconsin Marathon 519 2008 2008

AES Deepwater 10670_B_AAB001 Texas Harris 140 1986 2007

La Cygne 1241_B_1 Kansas Linn 724 1973 2007

Morgantown Generating Plant 1573_B_1 Maryland Charles 624 1970 2007

PSEG Hudson Generating Station 2403_B_2 New Jersey Hudson 583 1967 2007

San Juan 2451_B_4 New Mexico San Juan 506 1982 2007

Big Bend 645_B_BB04 Florida Hillsborough 457 1985 2007

Cross 130_B_3 South Carolina Berkeley 620 2007 2007

Wygen II 55479_B_4 Wyoming Campbell 90 2007 2007

Council Bluffs 1082_B_4 Iowa Pottawattamie 790 2007 2007

SO2 Controls (FGDs, 2007 – 2012)

Plant Name UniqueID_Final State Name County

Capacity 

MW

On Line 

Year

Scrubber 

Online 

Year

James H Miller Jr 6002_B_1 Alabama Jefferson 684 1978 2011

James H Miller Jr 6002_B_2 Alabama Jefferson 687 1985 2011

James H Miller Jr 6002_B_3 Alabama Jefferson 687 1989 2011

James H Miller Jr 6002_B_4 Alabama Jefferson 688 1991 2011

Cape Fear 2708_B_5 North Carolina Chatham 143 1956 2011

Baldwin Energy Complex 889_B_1 Illinois Randolph 624 1970 2011

Baldwin Energy Complex 889_B_2 Illinois Randolph 629 1973 2011

Baldwin Energy Complex 889_B_3 Illinois Randolph 629 1975 2011

Scherer 6257_B_3 Georgia Monroe 875 1987 2011

Milton R Young 2823_B_B1 North Dakota Oliver 250 1970 2011

W H Sammis 2866_B_6 Ohio Jefferson 630 1969 2011

W H Sammis 2866_B_7 Ohio Jefferson 630 1971 2011

PSEG Hudson Generating Station 2403_B_2 New Jersey Hudson 583 1967 2011

John Sevier 3405_B_1 Tennessee Hawkins 176 1955 2011

John Sevier 3405_B_2 Tennessee Hawkins 176 1955 2011

John Sevier 3405_B_3 Tennessee Hawkins 176 1956 2011

John Sevier 3405_B_4 Tennessee Hawkins 176 1957 2011

Beech Hollow Power Project 82704_B_1 Pennsylvania Washington 272 2011 2011

Longview Power 82702_B_1 West Virginia Monongalia 695 2011 2011

Cliffside 2721_B_6 North Carolina Cleveland 800 2011 2011

AES Greenidge LLC 2527_B_4 New York Yates 27 1950 2010

AES Greenidge LLC 2527_B_5 New York Yates 27 1950 2010

Barry 3_B_5 Alabama Mobile 750 1971 2010

E C Gaston 26_B_5 Alabama Shelby 861 1974 2010

Warrick 6705_B_4 Indiana Warrick 300 1970 2010

Coffeen 861_B_01 Illinois Montgomery 340 1965 2010

Coffeen 861_B_02 Illinois Montgomery 560 1972 2010

Cardinal 2828_B_3 Ohio Jefferson 630 1977 2010

Brandon Shores 602_B_1 Maryland Anne Arundel 643 1984 2010

Brandon Shores 602_B_2 Maryland Anne Arundel 643 1991 2010

Monroe 1733_B_4 Michigan Monroe 775 1974 2010

Cliffside 2721_B_5 North Carolina Cleveland 550 1972 2010

Crystal River 628_B_4 Florida Citrus 720 1982 2010

Bowen 703_B_1BLR Georgia Bartow 713 1971 2010
50

Crist 641_B_6 Florida Escambia 302 1970 2010

Crist 641_B_7 Florida Escambia 477 1973 2010

Clifty Creek 983_B_1 Indiana Jefferson 217 1955 2010

Clifty Creek 983_B_2 Indiana Jefferson 217 1955 2010

Clifty Creek 983_B_3 Indiana Jefferson 217 1955 2010

Clifty Creek 983_B_4 Indiana Jefferson 217 1955 2010

Clifty Creek 983_B_5 Indiana Jefferson 217 1955 2010

Clifty Creek 983_B_6 Indiana Jefferson 217 1956 2010

Chalk Point LLC 1571_B_1 Maryland Prince George's 341 1964 2010

Chalk Point LLC 1571_B_2 Maryland Prince George's 342 1965 2010

Dickerson 1572_B_1 Maryland Montgomery 182 1959 2010

Dickerson 1572_B_2 Maryland Montgomery 182 1960 2010

Dickerson 1572_B_3 Maryland Montgomery 182 1962 2010

R E Burger 2864_B_7 Ohio Belmont 156 1955 2010

R E Burger 2864_B_8 Ohio Belmont 156 1955 2010

Kyger Creek 2876_B_1 Ohio Gallia 217 1955 2010

Kyger Creek 2876_B_2 Ohio Gallia 217 1955 2010

Kyger Creek 2876_B_3 Ohio Gallia 217 1955 2010

Kyger Creek 2876_B_4 Ohio Gallia 217 1955 2010

Kyger Creek 2876_B_5 Ohio Gallia 217 1955 2010

Cheswick 8226_B_1 Pennsylvania Allegheny 580 1970 2010

PSEG Mercer Generating Station 2408_B_1 New Jersey Mercer 315 1960 2010

PSEG Mercer Generating Station 2408_B_2 New Jersey Mercer 310 1961 2010

Silver Lake 2008_B_4 Minnesota Olmsted 61 1969 2010

Kingston 3407_B_1 Tennessee Roane 135 1954 2010

Kingston 3407_B_2 Tennessee Roane 135 1954 2010

Kingston 3407_B_3 Tennessee Roane 135 1954 2010

Kingston 3407_B_4 Tennessee Roane 135 1954 2010

Kingston 3407_B_5 Tennessee Roane 177 1955 2010

Kingston 3407_B_6 Tennessee Roane 177 1955 2010

Kingston 3407_B_7 Tennessee Roane 177 1955 2010

Kingston 3407_B_8 Tennessee Roane 177 1955 2010

Kingston 3407_B_9 Tennessee Roane 178 1955 2010

Sioux 2107_B_1 Missouri St. Charles 497 1967 2010

Sioux 2107_B_2 Missouri St. Charles 497 1968 2010

Chesterfield 3797_B_5 Virginia Chesterfield 310 1964 2010

Yorktown 3809_B_1 Virginia York 159 1957 2010

AES Westover 2526_B_11 New York Broome 22 1943 2010

AES Westover 2526_B_12 New York Broome 22 1943 2010

AES Westover 2526_B_13 New York Broome 84 1951 2010

Iatan 2 6065_B_2 Missouri Platte 850 2010 2010

Southwest 6195_B_2 Missouri Greene 300 2010 2010

Trimble Station (LGE) 6071_B_2 Kentucky Trimble 732 2010 2010

Elm Road Generating Station 56068_B_2 Wisconsin Milwaukee 615 2010 2010

Cholla 113_B_3 Arizona Navajo 271 1980 2009

Mayo 6250_B_1A North Carolina Person 362 1983 2009

Mayo 6250_B_1B North Carolina Person 362 1983 2009

Conesville 2840_B_4 Ohio Coshocton 780 1973 2009

G G Allen 2718_B_1 North Carolina Gaston 162 1957 2009

G G Allen 2718_B_2 North Carolina Gaston 162 1957 2009

G G Allen 2718_B_3 North Carolina Gaston 260 1959 2009
51

G G Allen 2718_B_4 North Carolina Gaston 275 1960 2009

G G Allen 2718_B_5 North Carolina Gaston 265 1961 2009

H L Spurlock 6041_B_1 Kentucky Mason 315 1977 2009

Crystal River 628_B_5 Florida Citrus 717 1984 2009

Deerhaven Generating Station 663_B_B2 Florida Alachua 228 1981 2009

Bowen 703_B_2BLR Georgia Bartow 718 1972 2009

Wansley 6052_B_2 Georgia Heard 892 1978 2009

E W Brown 1355_B_1 Kentucky Mercer 94 1957 2009

E W Brown 1355_B_2 Kentucky Mercer 160 1963 2009

E W Brown 1355_B_3 Kentucky Mercer 422 1971 2009

Ghent 1356_B_2 Kentucky Carroll 469 1977 2009

Fayette Power Project 6179_B_1 Texas Fayette 598 1979 2009

Fayette Power Project 6179_B_2 Texas Fayette 598 1980 2009

Morgantown Generating Plant 1573_B_1 Maryland Charles 624 1970 2009

Morgantown Generating Plant 1573_B_2 Maryland Charles 620 1971 2009

PPL Brunner Island 3140_B_1 Pennsylvania York 321 1961 2009

PPL Brunner Island 3140_B_2 Pennsylvania York 378 1965 2009

Keystone 3136_B_1 Pennsylvania Armstrong 850 1967 2009

Keystone 3136_B_2 Pennsylvania Armstrong 850 1968 2009

Bull Run 3396_B_1 Tennessee Anderson 881 1967 2009

Bay Shore 2878_B_4 Ohio Lucas 215 1968 2009

Hatfields Ferry Power Station 3179_B_1 Pennsylvania Greene 530 1969 2009

Hatfields Ferry Power Station 3179_B_2 Pennsylvania Greene 530 1970 2009

Hatfields Ferry Power Station 3179_B_3 Pennsylvania Greene 530 1971 2009

Nebraska City Unit 2 6096_B_2 Nebraska Otoe 663 2009 2009

Cross 130_B_4 South Carolina Berkeley 652 2009 2009

Springerville 8223_B_4 Arizona Apache 400 2009 2009

Sandow 5 82010_B_5 Texas Milam 600 2009 2009

Oak Grove 82011_B_1 Texas Robertson 800 2009 2009

Oak Grove 82011_B_2 Texas Robertson 800 2009 2009

TS Power Plant 82013_B_1 Nevada Eureka 200 2009 2009

Plum Point Energy 82014_B_1 Arkansas Mississippi 665 2009 2009

Comanche 470_B_3 Colorado Pueblo 750 2009 2009

Elm Road Generating Station 56068_B_1 Wisconsin Milwaukee 615 2009 2009

Two Elk Generating Station 55360_B_1 Wyoming Campbell 300 2009 2009

J K Spruce 7097_B_BLR2 Texas Bexar 750 2009 2009

Dallman 963_B_34 Illinois Sangamon 200 2009 2009

Charles R Lowman 56_B_1 Alabama Washington 86 1969 2008

John E Amos 3935_B_1 West Virginia Putnam 800 1971 2008

John E Amos 3935_B_2 West Virginia Putnam 800 1972 2008

Cholla 113_B_4 Arizona Navajo 380 1981 2008

Roxboro 2712_B_1 North Carolina Person 369 1966 2008

Roxboro 2712_B_3A North Carolina Person 341 1973 2008

Roxboro 2712_B_3B North Carolina Person 341 1973 2008

Miami Fort 2832_B_7 Ohio Hamilton 500 1975 2008

Miami Fort 2832_B_8 Ohio Hamilton 500 1978 2008

Cogentrix Virginia Leasing Corp 10071_B_2A Virginia Portsmouth 19 1988 2008

Cogentrix Virginia Leasing Corp 10071_B_2B Virginia Portsmouth 19 1988 2008

Cogentrix Virginia Leasing Corp 10071_B_2C Virginia Portsmouth 19 1988 2008

J M Stuart 2850_B_1 Ohio Adams 585 1971 2008

J M Stuart 2850_B_2 Ohio Adams 597 1970 2008
52

J M Stuart 2850_B_3 Ohio Adams 597 1972 2008

J M Stuart 2850_B_4 Ohio Adams 597 1974 2008

Monroe 1733_B_3 Michigan Monroe 795 1973 2008

Belews Creek 8042_B_1 North Carolina Stokes 1,115 1974 2008

Belews Creek 8042_B_2 North Carolina Stokes 1,115 1975 2008

Bowen 703_B_3BLR Georgia Bartow 902 1974 2008

Bowen 703_B_4BLR Georgia Bartow 929 1975 2008

Hammond 708_B_1 Georgia Floyd 112 1954 2008

Hammond 708_B_2 Georgia Floyd 112 1954 2008

Hammond 708_B_3 Georgia Floyd 112 1955 2008

Hammond 708_B_4 Georgia Floyd 510 1970 2008

Wansley 6052_B_1 Georgia Heard 891 1976 2008

Harding Street 990_B_70 Indiana Marion 435 1973 2008

Cogentrix Hopewell 10377_B_1A Virginia Hopewell (city) 18 1987 2008

Cogentrix Hopewell 10377_B_1B Virginia Hopewell (city) 18 1987 2008

Cogentrix Hopewell 10377_B_1C Virginia Hopewell (city) 18 1987 2008

Ghent 1356_B_4 Kentucky Carroll 478 1984 2008

Council Bluffs 1082_B_3 Iowa Pottawattamie 690 1978 2008

PPL Brunner Island 3140_B_3 Pennsylvania York 749 1969 2008

PPL Montour 3149_B_1 Pennsylvania Montour 774 1972 2008

PPL Montour 3149_B_2 Pennsylvania Montour 766 1973 2008

Comanche 470_B_1 Colorado Pueblo 366 1973 2008

Comanche 470_B_2 Colorado Pueblo 370 1975 2008

Cayuga 1001_B_2 Indiana VermilIon 473 1972 2008

Winyah 6249_B_1 South Carolina Georgetown 295 1975 2008

Winyah 6249_B_2 South Carolina Georgetown 295 1977 2008

Winyah 6249_B_3 South Carolina Georgetown 295 1980 2008

Chesterfield 3797_B_6 Virginia Chesterfield 658 1969 2008

Brayton Point 1619_B_1 Massachusetts Bristo 243 1963 2008

Brayton Point 1619_B_2 Massachusetts Bristo 244 1964 2008

Weston 4078_B_4 Wisconsin Marathon 519 2008 2008

Gorgas 8_B_10 Alabama Walker 690 1972 2007

Gorgas 8_B_8 Alabama Walker 165 1956 2007

Gorgas 8_B_9 Alabama Walker 175 1958 2007

John E Amos 3935_B_3 West Virginia Putnam 1,300 1973 2007

Mountaineer 6264_B_1 West Virginia Mason 1,300 1980 2007

Cardinal 2828_B_1 Ohio Jefferson 600 1967 2007

Cardinal 2828_B_2 Ohio Jefferson 600 1967 2007

Roxboro 2712_B_2 North Carolina Person 639 1968 2007

Roxboro 2712_B_4A North Carolina Person 343 1980 2007

Roxboro 2712_B_4B North Carolina Person 343 1980 2007

Cogentrix Virginia Leasing Corp 10071_B_1A Virginia Portsmouth 19 1988 2007

Cogentrix Virginia Leasing Corp 10071_B_1B Virginia Portsmouth 19 1988 2007

Cogentrix Virginia Leasing Corp 10071_B_1C Virginia Portsmouth 19 1988 2007

Killen Station 6031_B_2 Ohio Adams 615 1982 2007

Marshall 2727_B_2 North Carolina Catawba 378 1966 2007

Marshall 2727_B_3 North Carolina Catawba 657 1969 2007

Cogentrix Hopewell 10377_B_2A Virginia Hopewell (city) 18 1987 2007

Cogentrix Hopewell 10377_B_2B Virginia Hopewell (city) 18 1987 2007

Cogentrix Hopewell 10377_B_2C Virginia Hopewell (city) 18 1987 2007

Ghent 1356_B_3 Kentucky Carroll 478 1981 2007
53

Louisa 6664_B_101 Iowa Louisa 700 1983 2007

Allen S King 1915_B_1 Minnesota Washington 571 1968 2007

Mitchell 3948_B_1 West Virginia Marshall 800 1971 2007

Gibson 6113_B_1 Indiana Gibson 630 1975 2007

Gibson 6113_B_2 Indiana Gibson 628 1975 2007

Winyah 6249_B_4 South Carolina Georgetown 270 1981 2007

Pleasant Prairie 6170_B_2 Wisconsin Kenosha 617 1985 2007

Cross 130_B_3 South Carolina Berkeley 620 2007 2007

Wygen II 55479_B_4 Wyoming Campbell 90 2007 2007

Council Bluffs 1082_B_4 Iowa Pottawattamie 790 2007 2007

Assumed BART Facilities and Units

State County Fac ID Facility Name Unit ID

MI Bay B2840 CE - KARN/WEADOCK EU00036

MI Bay B2840 CE - KARN/WEADOCK EU00037

MI Eaton B4001 LAN. BW&L ERICKSON EU00007

MI Houghton B6553 UP POWER CO / PORTAGE EU00008

MI Huron B2815 DTE - HARBOR BEACH EU00009

MI Ingham B2647 LAN. BW&L Eckert RG00023

MI Ingham B2647 LAN. BW&L Eckert RG00023

MI Ingham B2647 LAN. BW&L Eckert RG00023

MI Ingham B2647 LAN. BW&L Moores Park RG00021

MI Marquette B4261 WE-ENERGIES EU00029

MI Marquette B4261 WE-ENERGIES EU00030

MI Marquette B4261 WE-ENERGIES EU00031

MI Marquette B4261 WE-ENERGIES EU00032

MI Marquette B4261 WE-ENERGIES EU00033

MI Monroe B2816 DTE - MONROE EU00062

MI Monroe B2816 DTE - MONROE EU00068

MI Monroe B2816 DTE - MONROE EU00063

MI Monroe B2816 DTE - MONROE EU00064

MI Ottawa B2835 CE – CAMPBELL EU00062

MI Ottawa B2835 CE – CAMPBELL EU00061

MI Saint Clair B2796 DTE - ST. CLAIR / BELLE RIVER EU00111

MI Saint Clair B6145 DTE – GREENWOOD EU00009

MI Wayne B2132 WYANDOTTE EU00036

MI Wayne B2185 DETROIT PLD, MISTERSKY EU00014

MI Wayne B2811 DTE – TRENTON EU00035

 

OH Lake 0243160009 CEI., EASTLAKE PLANT B005

OH 0247030013 Orion Power Midwest B012

OH 0285010188 Dept of Public Utilities, City of Orrville B001

OH 0285010188 Dept of Public Utilities, City of Orrville B004

OH 0448020006 Toledo Edison Co., Bay Shore B003

OH 0448020006 Toledo Edison Co., Bay Shore B004

OH 0616000000 Conesville Power Plant B003

OH 0616000000 Conesville Power Plant B004

OH 0616000000 Conesville Power Plant B007

OH 0641050002 Cardinal Power Plant B001

OH 0641050002 Cardinal Power Plant B002
54

OH 0641050002 Cardinal Power Plant B003

OH 0641050002 Cardinal Power Plant B004

OH 0641050002 Cardinal Power Plant B008

OH 0641050002 Cardinal Power Plant B009

OH 0641050002 Cardinal Power Plant B009

OH Jefferson 0641160017 W. H. SAMMIS PLANT B011

OH Jefferson 0641160017 W. H. SAMMIS PLANT B012

OH Jefferson 0641160017 W. H. SAMMIS PLANT B013

OH 0684000000 Muskingum River Power Plant B006

OH Adams 0701000007 DP&L, J.M. Stuart Generating Station B001

OH Adams 0701000007 DP&L, J.M. Stuart Generating Station B002

OH Adams 0701000007 DP&L, J.M. Stuart Generating Station B003

OH Adams 0701000007 DP&L, J.M. Stuart Generating Station B004

OH 0701000060 DP&L, Killen Station B001

OH 1409040243 City of Hamilton Dept of Public Utilities B002

OH 1409040243 City of Hamilton Dept of Public Utilities B008

OH 1409040243 City of Hamilton Dept of Public Utilities B009

OH 1413100008 CG&E W. C. BECKJORD B005

OH 1413100008 CG&E W. C. BECKJORD B006

OH 1431350093 CG&E MIAMI FORT STATION B015

 

IL Peoria 856 Ameren – Edwards 2

IL Sangamon 963 CWLP – Dallman 31

IL Sangamon 963 CWLP – Dallman 32

IL Christian 876 Dominion – Kincaid 1

IL Christian 876 Dominion – Kincaid 2

 

WI COLUMBIA 111003090 Alliant Energy-Columbia Generating B20

WI COLUMBIA 111003090 Alliant Energy-Columbia Generating B21

WI COLUMBIA 111003090 Alliant Energy-Columbia Generating B22

WI GRANT 122014530 Alliant Energy, Nelson Dewey B22 (unit 2)

WI MILWAUKEE 241007690 We Energies-Oak Creek Station B26 (Unit 6)

WI MILWAUKEE 241007690 We Energies-Oak Creek Station B27 (Unit 7)

WI MILWAUKEE 241007690 We Energies-Oak Creek Station B28

WI MILWAUKEE 241007800 We Energies-Valley Station B21

WI MILWAUKEE 241007800 We Energies-Valley Station B23

WI MILWAUKEE 241007800 We Energies-Valley Station B24

WI BROWN 405031990 WI Public Service Corp - JP Pulliam B27 (unit 8)

WI SHEBOYGAN 460033090 WP & L Alliant Energy – Edgewater B24 

WI BUFFALO 606034110

Dairyland Power Coop Alma Station 

(J.P. Madgett boilers) B25 (+B26)

WI BUFFALO 606034110 Dairyland Power Coop Alma Station B27

WI VERNON 663020930 Dairyland Power Coop Genoa Station B20

WI VERNON 663020930 Dairyland Power Coop Genoa Station B25

 

IN Porter 995 Bailly 7

IN Porter 995 Bailly 8

IN Vermillion 1001 Cayuga 1

IN Vermillion 1001 Cayuga 2

IN Montgomery 1024 Crawfordsville 6

IN Warrick 1012 Culley 2
55

IN Warrick 1012 Culley 3

IN Gibson 6113 Gibson 1

IN Gibson 6113 Gibson 2

IN Cass 1032 Logansport 6

IN Sullivan 6213 Merom 1

IN Sullivan 6213 Merom 2

IN LaPorte 997 Michigan City 12

IN Lake 996 Mitchell 11

IN Pike 994 Petersburg 1

IN Pike 994 Petersburg 2

IN Pike 994 Petersburg 3

IN Pike 1043 Ratts 1

IN Pike 1043 Ratts 2

IN Wayne 7335 RPL 2

IN Jasper 6085 Schahfer 14

IN Jasper 6085 Schahfer 15

IN Lake 981 Stateline 4

IN Marion 990 Stout 70

IN Dearborn 988 Tanners Creek 4

IN Vigo 1010 Wabash River 6

IN Warrick 6705 Warrick 4

 

IA 07-02-005 Cedar Falls Utilities Unit #7 (EU10.1A)

IA 88-01-004

Central Iowa Power Cooperative 

(CIPCO) – Summit Lake Station

CombTurbines (EU 

1/1G, EU2/2G)

IA 70-08-003

Central Iowa Power Cooperative 

(CIPCO) – Fair Station

Unit # 2 (EU 2 & 

EU 2G)

IA 85-01-006 City of Ames - Steam Electric Plant Boiler #7 (EU 2)

IA 29-01-013 Interstate Power & Light - Burlington Main Plant Boiler.

IA 03-03-001 Interstate Power & Light - Lansing

Boiler #4. Sixteen 

units in total.

IA 23-01-014 Interstate Power & Light - ML Kapp

Boiler #2. Six units 

in total.

IA 57-01-042 Interstate Power & Light - Prairie Creek

Boiler #4. Fourteen 

units in total.

IA 78-01-026 MidAmerican Energy Co - Council Bluffs Boiler #3 (EU003)

IA 97-04-010 MidAmerican Energy Co - Neal North

Boilers #1-3 

(EU001 - EU003)

IA 97-04-011 MidAmerican Energy Co - Neal South Boiler #4 (EU003)

IA 70-01-011 Muscatine Power and Water Boiler #8

IA 63-02-005 Pella Municipal Power Plant Boilers #6-8

 

MN 2709900001 Austin Utilities NE Power Station EU001

MN 2713700027 Hibbing Public Utilities EU003

MN 2703100001 MN Power, Taconite Harbor EU003

MN 2706100004 MN Power, Boswell Energy Center EU003

MN 2701500010 New Ulm Public Utilities EU003 - Boiler 4

MN 2711100002 Otter Tail Power Hoot Lake EU003

MN 2710900011 Rochester Public Utilities, Silver Lake EU003

MN 2710900011 Rochester Public Utilities, Silver Lake EU004

MN 2713700028 Virginia Public Utilities EU003 - Boiler 9

MN 2714100004 Xcel Energy, Sherco EU001, EU002

MN 2716300005 Xcel Energy, Allen S King EU001 - Boiler 1
56

MN 2705300015 Xcel Energy, Riverside EU003 - Boiler 8

 

MO 290710003 Ameren -Labadie B1, B2, B3, B4

MO 291830001 Ameren - Sioux B1, B2

MO 290990016 Ameren - Rush Island B1, B2

MO 290950031 Auila - Sibley B3 - 5C

MO 291430004 Assoc. Electric - New Madrid

B1(EP-01), B2 

(EP-02)

MO 290770039 City Utilities Springfield - Southwest B1 (E09)

MO 290770005 City Utilities Springfield - James River EO7, EO8

MO 290970001 Empire Distric Electric - Asbury B7

MO 290830001 KC Power and Light - Montrose EP08

MO 290210004 Aqula - Lake Road EP06

MO 291750001 Assoc. Electric - Thomas Hill EP01, EP02

MO 290950021 Trigen - Kansas City B1A

MO 290190002 City of Columbia Municipal Power Plant EP02

MO 291950010 Marshall Munipal Utilities EP05

MO 290950050 Independence Power & Light-Blue Valley B3 (EP05)

 

WV 3943 Fort Martin

WV 6004 Pleasants

WV 3948 Mitchell

WV 3935 Amos

WV 6264 Mountaineer

WV 3944 Harrison

 

TN 3396 TVA Bull Run

TN 3399 TVA Cumberland

 

KY 1363 Cane Run

KY 1364 Mill Creek

KY 6041 Spurlock

KY 1384 John Sherman Cooper

KY 1353 Big Sandy

KY 1356 Ghent

KY 1355 Brown

KY 1374 Owensboro Municipal

KY 1372 Henderson Municipal

KY 1378 Paradise

KY 1361 Coleman

KY 1382 Reid/Henderson 2

KY 6639 Green
Appendix 5B 

 Updated Glide Path Analysis for Regional Haze 
    February 24, 2010

Updated Glide Path Analysis for Regional Haze (DRAFT)

This memo provides updated information on the measured and model‐projected visibility levels for the

Class I areas in northern Michigan and Minnesota.  Specifically, four additional years of measured data

(2005‐2008) and one recent air quality modeling analysis were considered in preparing new plots of the

glide paths for these Class I areas.  This memo supplements the LADCO Technical Support Document

(“Regional Air Quality Analyses for Ozone, PM2.5, and Regional Haze: Final Technical Support

Document”, April 25, 2008)1

, which summarized the air quality analyses conducted by LADCO and its

contractors to support the development of State Implementation Plans (SIPs) for ozone, PM2.5, and

regional haze in the States of Illinois, Indiana, Michigan, Ohio, and Wisconsin.

Monitoring Data: A summary data set of the mean values for the best 20%, middle 20%, and 

worst 20% visibility days for the period 1988-2008 was obtained from the IMPROVE 

website: http://vista.cira.colostate.edu/IMPROVE/Data/IMPROVE/summary_data.htm

The values were calculated using the revised (new) IMPROVE algorithm.  It should be noted that the

baseline values were determined using 2000‐2004 data, in accordance with the Regional Haze Rule.

Modeling Data: Two sets of future year model predictions were considered:  

(1) Round 5.1 results for 2009, 2012, and 2018 (using EPA’s IPM‐based projections of EGU growth and

the original CAIR rule) – see “Regional Air Regional Air Quality Analyses for Ozone, PM2.5, and

Regional Haze: Final Technical Support Document”, April 25, 2008

(2) State Collaborative results for 2009, 2012, and 2018 (using an alternate EGU growth methodology

and planned/expected EGU controls) – see “Regional Modeling for the Easter U.S.:  Technical

Support Document”, July 9, 2009

A major difference between these modeling analyses is the assumed level of EGU control.  LADCO’s

Round 5.1 modeling reflects full implementation of EPA’s Clean Air Interstate Rule (CAIR), and the State

Collaborative modeling recognizes the CAIR remand and reflects only planned/expected EGU controls.  

Not surprisingly, with lesser control, the State Collaborative modeling shows less visibility improvement.  

In light of the uncertainty due to the CAIR remand, however, the projections, particularly for the farthest

out year – 2018, are suspect.

Results: Figure 1 provides updated glide path plots for Voyageurs and Boundary Waters in Minnesota,

and Isle Royale and Seney in Michigan.  There are insufficient data to establish any clear trends, but it is

encouraging that measured visibility levels for the most recent 2 – 3 years have improved in three of the

four Class I areas (and, furthermore, are on the glide path).  In preparation for the first 5‐year progress

report (due in December 2012), this analysis will be updated on a periodic basis as more measured data

become available (e.g., 2009 – 2011 data), and as more modeling is conducted (e.g., new SIP analyses).

                                                           

1 The memo also supplements the summary of technical information of regional haze and visibility impairment in

the northern Michigan and Minnesota Class I areas: “Regional Haze in the Upper Midwest: Summary of Technical

Information”, Version 2.2, February 22, 2008.

1
February 24, 2010

The top line in each figure represents visibility values for the 20% worst days and the bottom line for the 20% best days. The black diam

the baseline value (2000‐2004 average) and the natural conditions value (2064).

2
Appendix 6A 

Description of Isle Royale National Park 

and Seney Wilderness Area IMPROVE Sites 
Description of Isle Royale National Park and Seney Wilderness Area 

Isle Royale National Park

A description of the Isle Royale IMPROVE site is given in the Table 1 below. The 

monitor for Isle Royale is located off-site of the island on the Keweenaw Peninsula. The 

monitoring site was formerly located on the island itself, however, due to accessibility 

problems during the winter, the monitoring site was moved to the main land. 

Table 1. Information from VIEWS website for Isle Royale 

SiteCode: ISLE1 

SiteName: Isle Royale NP 

State: MI 

StateFIPS: 26 

CountyFIPS: 083 

Latitude: 47.4596 

Longitude: -88.1491 

ElevationMSL: 182 

StartDate: 11/16/1999 

EPARegion: 5 

ImproveRegionID: 3 

AQCRID: 0 

CMSAID: 0 

AirBasinID: 0 

UrbanAreaID: 0 

AgencyID: 1648 

LocDesc: Near the boat ramp on point 

opposite town of Eagle Harbor

ProgramCode: IMPROVE 

NativeSiteCode: ISLE1 

Sponsor: NPS 

Since the monitor is located at a site different than the class I area, the two sites could 

have different visibility impairment. However, based on the siting criteria in the 

Visibility Monitoring Guidance1 (see section 3.2), the monitor location fits the criteria. 

LADCO performed some modeling which estimated the deciviews on Isle Royale rather 

than the monitor location. These results can be seen in Table 2. Visibility impairment is 

slightly less at the class I area versus the monitor location, thus reaching the RPGs at the 

 

1

 USEPA, 1999, Visibility Monitoring Guidance, June 1999, 

http://www.epa.gov/ttnamti1/files/ambient/visible/r-99-003.pdf 

1
monitor location should ensure that the Class I site itself will have similar or even greater 

visibility improvements. 

Table 2. 2018 on-the-books modeling results (in dv) for Isle Royale for 20% best and 

worst days comparing the results for grid cell where the IMPROVE monitor is located 

(ISLE1) versus where the class I area is located (ISLE9). 

Worst 20% Best 20%

Monitor (ISLE1) 20.09 6.6 

Class I area 

(ISLE9) 19.84 6.52 

Difference 0.25 0.08 

Seney Wilderness Area

A description of the Seney IMPROVE site is given in the Table 3 below. The monitor 

for Seney is located on-site of the Seney Wilderness area. 

Table 3. Information from VIEWS website 

SiteCode: SENE1 

SiteName: Seney 

State: MI 

StateFIPS: 26 

CountyFIPS: 153 

Latitude: 46.2889 

Longitude: -85.9503 

ElevationMSL: 214.5 

StartDate: 11/16/1999 

EPARegion: 5 

ImproveRegionID: 3 

AQCRID: 0 

CMSAID: 0 

AirBasinID: 0 

UrbanAreaID: 0 

AgencyID: 1646 

LocDesc: Near Refuge Headquarters 

ProgramCode: IMPROVE 

NativeSiteCode: SENE1 

Sponsor: FWS 

2
Appendix 8A 

EMISSIONS INVENTORY METHODOLOGY 

SUPPORT DOCUMENTATION 

FOR THE REGIONAL HAZE SIP 
Table of Contents 

 Page

List of acronyms........................................................................................................... 2 

1. Introduction ............................................................................................................ 4 

2. EGU Point Sources ............................................................................................... 4 

3. Non-EGU Point Sources ........................................................................................ 8 

4. Stationary Non-Point Sources............................................................................... 12 

5. Non-road Mobile Sources ..................................................................................... 51 

6. On-road Mobile Sources ....................................................................................... 54 

7. Area Source Ammonia and Biogenic Emissions................................................... 55 

 1
List of Acronyms 

AEO Annual Energy Output 

AMS Area Mobile Source Codes 

AQD Michigan’s Air Quality Division 

ATADS Air Traffic Activity Data System 

CAMD Clean Air Markets Division 

CAS Chemical Abstract Service 

CEM Continuous Emissions Monitoring 

CERR Consolidated Emissions Reporting Rule 

CFC Chlorofluorocarbons 

CO carbon monoxide 

CONCEPT CONsolidated Community Emissions Processing Tool 

DLEG Michigan Department of Labor and Economic Growth 

EDMS Emissions and Dispersion Modeling System 

EIA Energy Information Agency 

EIIP Emission Inventory Improvement Program 

FAA Federal Aviation Administration 

FIFRA Federal Insecticide, Fungicide and Rodenticide Act 

FIRE Factor Information Retrieval System 

GLC Great Lakes Commission 

HAP Hazardous air pollutants 

HDGV Heavy duty gasoline vehicle 

Hg Mercury 

IPM Integrated Planning Model 

kW Kilowatt 

LDGT Light duty gasoline truck 

LPG liquefied petroleum gas 

LTO Landing-Take Offs 

MAERS Michigan Air Emissions Reporting System 

MAR Marine, air and rail 

MEGAN Model of Emissions of Gases and Aerosols from Nature 

mg/Mg milligrams/megagram 

MSW municipal solid waste 

NAICS North American Industry Classification System 

NCD NMIM County Database 

NESHAP National Emission Standards for Hazardous Air Pollutants 

NIF National Inventory Format 

NMIM National Mobile Inventory Model 

NOAA National Oceanic and Atmospheric Administration 

ODBC Open Database Connectivity

Pb Lead 

Pechan E.H. Pechan & Associates, Inc. 

PERC perchloroethylene 

psia pounds per square inch absolute 

RCRA Resource Conservation and Recovery Act 

 2
RFP reasonable further progress 

ROP rate of progress 

RPS Renewable Portfolio Standards 

RVP Reid Vapor Pressure 

SCC Source Classification Codes 

SEMCOG Southeast Michigan Counsel of Governments 

SIC Standard Industrial Classification Code 

SF 3 Summary File 3 

SSD Source Summary Database 

T3 Travel Demand Modeling [TDM] Transformation Tool 

TAF Terminal Area Forecast 

TCA trichloroethane 

TDM Travel Demand Modeling 

USDA U.S. Department of Agriculture 

VMT vehicle miles traveled 

WI DNR Wisconsin Department of Natural Resources

 3
1. Introduction 

Emissions inventory documentation support for the Regional Haze SIP is provided in 

this appendix. An inventory was prepared for all counties in Michigan. Mobile 

emissions for other counties were prepared by the Midwest Regional Planning 

Organization’s (MRPO) contractor using traffic and vehicle information provided by the 

Michigan Department of Transportation. The Lake Michigan Air Director’s Consortium 

(LADCO) is the MRPO. The focus of the inventory effort was to produce modeling 

inventories for the base year (2005) and the future years (2018). The future year 

projections take into account existing control measures and measures that are known to 

be on the way (e.g., CAIR measures). This inventory is referred to as the LADCO 

Base-M inventory. Procedures used to prepare these inventory products can be found 

in the “Regional Air Quality Analyses for Ozone, PM2.5, and Regional Haze: Technical 

Support Document,” prepared by LADCO. LADCO has produced numerous summary 

reports with State and county total emissions and has posted them on their Internet site 

at: 

http://www.ladco.org/tech/emis/current/index.php

In a related effort, the 2005 Michigan statewide inventory was submitted to the EPA by 

the Michigan Department of Environmental Quality (MDEQ) pursuant to 40 CFR 

Part 51, Subpart A – Emissions Inventory Reporting Requirements. 

2. EGU Point Sources 

2005 EGU Point Source Methodology 

The 2005 EGU point source data originated with annual emissions data provided to 

Michigan DEQ via the Michigan Air Emissions Reporting System (MAERS). Temporal 

allocation was performed by emission unit, month, day of week and hour using the 

procedures described in “Temporally Allocating Emissions with CEM Data for Chemical 

Transport and SIP Modeling,” available at: 

http://www.epa.gov/ttn/chief/conference/ei15/session4/edick.pdf

In addition to the heat input-based temporal profiles described in the paper, separate 

temporal profiles were developed based on Continuous Emissions Monitoring (CEM) 

reported emissions of NOX and SO2 and these profiles were used instead of heat input 

to temporalize annual emissions of the respective pollutants. The CEM data used as 

the basis of the profiles was that for 2004 through 2006 obtained from the EPA Clean 

Air Markets Division (CAMD) website: 

http://camddataandmaps.epa.gov/gdm/index.cfm?fuseaction=emissions.wizard

Growing EGU Point Source to 2009 

 4
The 2009 data is obtained from Integrated Planning Model (IPM) results obtained by the 

EPA and converted to a modeling inventory by LADCO. The following is a LADCO 

Integrated Planning Model discussion, which details the methodologies used to project 

the EGU emissions to 2009 using results from the IPM model: 

Specifically, future year emissions are based on EPA’s IPM3.0 modeling. Three 

CAIR scenarios were addressed: 

• Round 5a: EPA’s IPM3.0 was assumed as the future year base for EGUs. 

• Round 5b: EPA’s IPM3.0, with several “will do” adjustments identified by the 

States. These adjustments should reflect a legally binding commitment (e.g., 

signed contract, consent decree, or operating permit). 

• Round 5c: EPA’s IPM3.0, with several “may do” adjustments identified by the 

States. These adjustments reflect less rigorous criteria, but should still be some 

type of public reality (e.g., BART determination or press announcement). 

Inter-RPO IPM Global Parameter Decisions (May 11, 2005): 

The following summarizes the decisions made by VISTAS, MRPO, CENRAP, 

and MANE-VU for global assumptions to be used in EGU forecasting with IPM. 

These decisions and changes are made to IPM version 2.1.9 assumptions, which 

can be referenced via EPA’s IPM website at: 

 

http://cfpub.epa.gov/crem/knowledge_base/crem_report.cfm?deid=74919

 A. Market Assumptions 

 1. National Electricity and Peak Demand 

Decision: Use unadjusted Energy Information Agency (EIA) Annual 

Energy Output (AEO) 2005 national electricity and peak demand 

values. 

 2. Regional Electricity and Demand Breakout 

Decision: Use the existing IPM region breakdown as conducted in 

earlier modeling. 

 3. Natural Gas Supply Curve and Price Forecast 

Decision: Take existing supply curves and scale application to EIA 

AEO 2005 price point. In this approach, the EPA 2.1.9 gas supply 

curves will be scaled in such a manner that IPM will solve for AEO 

2005 gas prices when the power sector gas demand in IPM is 

consistent with AEO 2005 power sector gas demand projections. 

In instances where the power sector gas demand in IPM is lower 

than that of AEO 2005 projections, IPM will project gas prices that 

are lower than that in AEO 2005 and vice versa. 

 4. Oil Price Forecast 

 Decision: Use EIA AEO 2005 values. 

 5. Coal Supply and Price Forecast 

 5
Decision: Take existing supply curves and scale application to EIA 

AEO 2005 price points, coal supply regions, and coal grades. In 

this approach, the coal supply curves used in EPA 2.1.9 are scaled 

in such a manner that the average mine mouth coal prices that the 

IPM is solving in aggregated coal supply regions are comparable to 

AEO 2005. Due to the fact that the coal grades and supply regions 

between AEO 2005 and the EPA 2.1.9 are not directly comparable, 

this is an approximate approach and has to be performed in an 

iterative fashion. This approach does not involve updating the coal 

transportation matrix with EIA assumptions due to significant 

differences between the EPA 2.1.9 and EIA AEO 2005 coal supply 

and coal demand regions. 

 B. Technical Assumptions 

 1. Firmly Planned Capacity Assumptions 

Decision: Use revisions and new data as provided by RPOs and 

stakeholders. 

Decision: Allow North Carolina Clean Smokestacks 2009 data as 

provided to define “must run” units. 

2. Pollution Control Retrofit Cost and Performance [SO2, NOx, and 

Hg] Decision: Retain pollution control retrofit cost and performance 

values. 

 3. New Conventional Capacity cost and performance assumptions 

Decision: Use EIA AEO 2005 cost and performance assumptions 

for new conventional capacity. 

Decision: Retain existing 2.1.9 framework cost and performance for 

new renewable capacity. 

Decision: Exclude constraint on new capacity type builds (i.e., no 

new coal). 

 4. SO2 Title IV Allowance Bank 

Decision: Use existing SO2 allowance bank value (4.99 million tons) 

for 2007. 

 5. Nuclear Re-licensing and Uprate 

Decision: Use existing IPM configuration with updated EIA AEO 

2005 (~$27/kW) incurrence cost for continued operation. 

 

 C. Strategy Assumptions 

 1. Clear Air Mercury Rule (CAMR) 

 Decision: Include CAMR in future rounds of IPM modeling. 

 2. Renewable Portfolio Standards 

Decision: Model Renewable Portfolio Standards (RPS) based on 

the most recent Regional Greenhouse Gas Initiative documentation 

using a single RPS region for MA, RI, NY, NJ, MD and CT. The 

RPS requirements within these states can be met by renewable 

generation from New England, New York and PJM. EPA 2.1.9 

 6
methodology and hardwired EIA AEO 2004 projected renewable 

builds for the remainder of the country. 

 D. Other Assumptions 

 1. Run Years 

Decision: Revise runs years to 2008 [2007-08], 2009 [2009], 2012 

[2010-13], 2015 [2014-17], 2018 [2018], 2020 [2019-22], and 2026 

[2023-2030]. 

 2. Canadian Sources 

Decision: Utilize existing v.2.1.9 configuration (no Canadian site 

specific sources). 

3. Non-EGU Point Sources 

2005 Non-EGU Point Source Methodologies 

The 2005 point source data have as their original sources the 2005 Michigan point 

source emission inventory. This section of the document describes the compilation and 

processing of point source emission data submitted to comply with the Consolidated 

Emission Reporting Rule (CERR) for the EPA NEI 2005 inventory. 

The data originates with the entry of data by the reporting facilities into the MAERS. 

The electronic data received from the reporting facilities is reviewed and compiled by 

the MDEQ, and exported to the fixed-width text version of the National Inventory Format 

(NIF). After the exported data is loaded into a PostgreSQL database patterned after the 

MS Access version of the NIF, the following processing steps and checks are 

performed. 

Both emissions estimated by default calculations in MAERS and any emissions reported 

by facility operators are maintained in MAERS. For evaluation and quality assurance 

purposes, both types of records are included in the exports. To avoid double-counting, 

where a specific process/pollutant has emission records both reported directly by the 

facility operator, and estimated via MAERS calculations, the latter are excluded. 

Portable facilities, such as asphalt plants, report total throughput and emissions, plus 

operating percentages for each county in which the portable facility was located during 

the year. From this information, records are generated for each county of operation, 

and throughput and emissions are apportioned based on the operating percentages 

reported by county and process. As geographic coordinates for all operating sites are 

not reported, coordinates corresponding to the centers of the counties of operation are 

assigned. 

As attention has shifted from total particulate to PM10 and PM2.5, total particulate records 

are excluded from the reporting requirements. 

 7
Over 99.8 percent of total criteria emissions are accounted for by emissions reported by 

operator; therefore, exported criteria emissions estimated via MAERS calculations are 

excluded. 

In the site table, where strFacilityCategory is not set in the export, it is set to “01.” 

Mandatory geo-coordinate fields were added to the NIF specifications released in 

December 2003, well after it would have been possible to collect this information from 

the reporting facilities for 2002 operations. The following values were deemed most 

often representative and the exported data are updated accordingly for 2002 data: 

“strHorizontalCollectionMethodCode” is set to '027' 

“strHorizontalAccuracyMeasure” is set to '2000' 

“strHorizontalReferenceDatumCode” is set to '001' 

“strReferencePointCode” is set to '106' 

For 2005, these geographic data elements were requested of the facilities. The defaults 

above were applied only where data was not provided by the facility. 

 

MAERS tracks emissions of some pollutants that are of interest to the Great Lakes 

Commission, but which do not have corresponding pollutant codes in the most recent 

NIF pollutant code table. Emission records for the following pollutant codes are 

excluded: 

7440508; 8052413; DICDD,TOT; DICDF,TOT; HYDFLUORO; PERFLUORO; 

TRICDD,TO; TRICDF,TO; CH4; CO2; N20; 117840; 7783064. 

Emission records for ammonia are exported with the Chemical Abstract Service (CAS) 

number 7664417, rather than the pollutant code NH3. These pollutant codes are 

updated to NH3. Likewise, records exported with pollutant codes PAH and POM are 

updated to pollutant codes 234 and 246, respectively. 

 

All criteria and HAP emissions are reported at the process level, and the export routines 

reflect that in the strEmissionDataLevel field of the emission table. This field is set to 

null for criteria pollutant emission records per EPA guidance. 

All emissions are exported as pounds of annual emissions. The EPA guidance 

suggests that criteria pollutant emission be reported in tons. The field 

strEmissionUnitNumerator is changed to TON and the filed dblEmissionNumericValue is 

divided by two000 for criteria pollutant emission records. 

Null values in the quarterly throughput fields of process records are set to zero. 

Where quarterly throughput fields of process records sum to zero, throughput 

percentages are set to 25% for each quarter. 

 8
MAERS recognizes a control device code of '909' for a “Roll Media Fiberglass Tack 

Filter (Tacky 1 side),” which is not recognized in the NIF code tables. Where this control 

device code is exported, the “strPrimaryDeviceTypeCode” field of the control equipment 

table is updated to a value of 058. 

Because of the exclusion of emission records as described above, referential integrity of 

the exported data can be compromised. At this point, it is re-established by deleting 

records stepwise, in the following order. 

CE records without corresponding EM records 

PE records without corresponding EM records 

EP records without corresponding EM records 

ER records without corresponding EP records 

EU records without corresponding EP records 

SI records without corresponding EU records 

The data are then checked again for referential integrity and mandatory fields and then 

loaded into the MS Access shell version of the NIF via append queries that connect to 

the PostgreSQL data tables via ODBC. The Basic Content and Format Checker is run 

and its output is reviewed. Where corrections are needed, to assure consistency 

among data sources, the corrections are made in the MAERS and a full iteration of the 

export and post-processing steps are performed. 

The 2005 point source inventory was incorporated into the LADCO Base M inventory 

and serve as the basis for Michigan’s 2005 CERR submittal. 

Growing Stationary Non-EGU Point, Stationary Area, Locomotive, Shipping, and 

Aircraft Categories to 2009 

The 2009 emissions are based on work and a follow-up report (E.H. Pechan & 

Associates, Inc., Development of Growth and Control Factors for Lake Michigan Air 

Directors Consortium, Final Report, December 14, 2004) done by E.H. Pechan & 

Associates, Inc. (Pechan). This work supports LADCO’s efforts to forecast 

anthropogenic emissions for the purpose of assessing progress for air quality goals, 

including goals related to regional haze and attainment of the ozone NAAQS. The 

Pechan growth factors were used to estimate the LADCO base M future year emissions 

posted by LADCO in 2007. The future year emissions represent both emission controls 

that already exist and those that are known to be on the way (e.g., CAIR control 

measures). 

To assess progress for attaining air quality goals, LADCO requires emission activity 

growth and control data to forecast emissions from a 2005 base-year inventory to 

several future years of interest. These future years include 2009, 2012, and 2018 (e.g., 

2018 is the first milestone for regional haze reasonable progress demonstrations). 

Pechan prepared emission control factors to support forecasting for each of these 

years. Because the incremental level of effort required to develop emission activity 

 9
growth factors for each year over the 2003-2018 period was nominal, Pechan prepared 

non-EGU point and area and non-road source growth factors for each year over this 

entire period. 

The report describes Pechan efforts to develop emission growth and control data to 

support future year air quality modeling by LADCO. The report is organized into a 

background chapter and: 

Chapter II, which describes the development of the emission activity growth data; 

Chapter III, which discusses how the emission control data were compiled; 

Chapter IV, which describes the preparation of the growth and control factor files; 

Chapter V, which identifies projection issues for future consideration; and 

Chapter VI, which presents the references consulted in preparing this report. 

The Pechan Growth and Control Factor report is too lengthy to be included in this 

document, but it can be provided upon request or downloaded at: 

http://www.ladco.org/reports/rpo/emissions/ladco_2005_base_yr_growth_and_controls_

report_final.pdf

For sectors non-EGU point source, stationary area source and MAR source sectors, the 

future year emissions for the LADCO States were derived by applying growth and 

control factors to the base year inventory. As stated above, these factors were 

developed by a contractor (E.H. Pechan). Growth factors were based initially on EGAS 

(version 5.0), and were subsequently modified (for select, priority categories) by 

examining emissions activity data. 

Additional information on the procedures used to project emissions can be found in the 

“Regional Air Quality Analyses for Ozone, PM2.5, and Regional Haze: Technical Support 

Document” prepared by LADCO. 

4. Stationary Area Sources 

2005 Stationary Area Source Emission Inventory 

The following is a description of the various area source categories that were 

inventoried as part of the year 2005 emissions inventory as required by the EPA under 

the CERR. It also provides documentation as part of the development of a broader 

emissions inventory (which encompasses point, area, non-road mobile, on-road mobile, 

and biogenic sources) that is being developed for (SIP requirements for attainment with 

the 8-hour ozone and PM2.5 NAAQS and the regional haze regulations. For the purpose 

of developing state SIPs to demonstrate compliance with the ozone NAAQS, PM2.5

NAAQS and regional haze rule, states are currently required to submit base-year 

inventories, 3-year cycle update inventories, rate of progress inventories, and modeling 

inventories. In a November 18, 2002 memorandum – 2002 Base-year Emission 

 10
Inventory for SIP Planning Process, EPA identified year 2002 as the base-year for the 

SIP planning process. Within 3 years after designations are determined, states will 

need to submit SIP attainment demonstrations for the 8-hour ozone and PM2.5 NAAQS. 

The 2002 base-year inventory serves several purposes in supporting air quality 

modeling and control measure selection to determine the types and amount of emission 

reductions needed to meet reasonable further progress (RFP) and rate of progress 

(ROP) emission reduction targets and demonstrate attainment. Many of the emission 

inventory planning requirements can be found in the EPA document entitled: Emissions 

Inventory Guidance for Implementation of Ozone and Particulate Matter National 

Ambient Air Quality Standards (NAAQS) and Regional Haze Regulations. Subsequent 

to the submission of the 2002 inventory, there was considerable discussion by LADCO 

staff with states and the EPA as to the appropriateness of 2002 base-year inventory 

with respect to using a 2005 base-year inventory. At the time of the preparation of the 

year 2005 emissions inventory, these discussions were still ongoing between LADCO 

and EPA. EPA designated nonattainment areas for the 8-hour ozone NAAQS with an 

effective date of June 15, 2004, while nonattainment designations for the PM2.5 NAAQS 

were published in the Federal Register later on January 5, 2005, with an effective date 

of April 5, 2005. For those states participating in regional planning organizations, there 

are additional SIP inventory requirements for regional haze. The cascading effect of 

subsequent nonattainment designations as well as subsequent attainment 

demonstrations, existing emission reductions from NOx SIP calls, and the 

appropriateness of the base-years 2002 and 2005 were discussed by LADCO, EPA, 

and the states. The 2005 inventory was developed to fulfill both a base-year inventory 

and three-year cycle update inventories that are required by the existing CERR. 

The following chart shows the specific air pollutants that must be provided by the CERR 

and base-year inventories for the 8-hour ozone and PM2.5 NAAQS and regional haze 

regulations. 

 11
 12

Required Air Pollutants Emissions 

CO NH3 NOX Pb

PM10-

PRI 

PM25-

PRI SOX VOC 

Consolidated 

Emissions 

Reporting Rule 

(CERR) 

√ √ √ √ √ √ √ √

Ozone NAAQS √ √ √

PM2.5 NAAQS √ √ √ √ √ √

Regional haze √ √ √ √ √

In producing the 2005 emission inventory, multiple emission estimates must be provided 

to reflect temporal resolution that is required by the CERR and base-year inventories for 

the ozone and PM2.5 NAAQS. These requirements are summarized as follows: 

Temporal Resolution Requirements for Inventories 

 Statewide 

Inventory 

Summer 

Weekday 

Consolidated Emissions 

Reporting Rule (CERR) 

Required 

Ozone NAAQS Required Required 

PM2.5 NAAQS Required Optional 

Regional haze Required Optional 

Consequently, the statewide year 2005 emission estimates that are being provided 

reflect the annual and summer weekday for the referenced air pollutants. A list of the 

30 area source categories appears on the following page. EPA requires specific data 

elements to be provided via electronic data transfer using the National Emission 

Inventory NEI-NIFV3.0 format. A description of data structures can be found in the EPA 

publication NEI Input Format (NIF) Version 3.0 User’s Guide Instructions and 

Conventions of Use, April 2003. 
Summary of Area Sources and Respective Air Pollutants Inventoried for 2005 Inv

Seq # 

Area Source 

Description SCCs SIC CO NH3 NOX

1 

Crude oil production 2310010000 1311 

2 

Natural gas production 2310020000 1311 

3 Breweries 2302070001 2082 4 Cutback asphalts 2461021000 2951 5 Distilleries 2302070010 2085 6 

Emulsified asphalts 2461022000 2951 

7 Aircraft refueling 2275900000 4581 8 Commercial coal 2103002000 9999 √ √ √ 9 

Commercial distillate oil 2103004000 9999 √ √ √ 

10 

Commercial kerosene 2103011005 9999 √ √ √ 

11 

Commercial natural gas 2103006000 9999 √ √ √ 

12 

Commercial residual oil 2103005000 9999 √ √ √ 

13 

Gasoline marketing 

2505030120, 2501060100, 2501060051, 2501060052, 2501060053, 2501060200 5541 

14 Industrial coal 2102002000 3999 √ √ √ 15 

Industrial distillate oil 2102004000 3999 √ √ √ 

16 

Industrial kerosene 2102011000 3999 √ √ √ 

13
17 

Industrial natural gas 2102006000 3999 √ √ √ 

18 

Industrial residual oil 2102005000 3999 √ √ √ 

19 Residential coal 2104001000 8811 √ √ √ 20 

Residential distillate oil 2104004000 8811 √ √ √ 

21 

Residential kerosene 2104011000 8811 √ √ √ 

22 

Residential natural gas 2104006000 8811 √ √ √ 

23 

Residential propane 2199007000 8811 √ √ 

24 Municipal landfills 2620030000 4953 √ √ 25 Vessel ballasting 2505020900 4432 26 Vessel loading 

2505020120, 2505020030,2505020150, 2505020180, 2505020090, 2505020060 4432 

27 Remedial action 2660000000 9511 √ √ 28 

Traffic marking paints 2401008000 1611 

29 Wineries 2302070005 2084 30 Aviation stage I 2501080050 5541 

14
Oil and Natural Gas Production 

The oil and gas production area source category represents those VOC emissions that 

result from the exploration, drilling, and the field processing of crude oil and natural gas. 

Fugitive VOC emissions occur from control valves, relief valves, spills, pipe fittings, 

pump seals and compressor seals in the production and field processing of crude oil 

and natural gas. Individual county crude oil and natural gas production data was 

obtained from the MDEQ, Geological and Land Management Division. VOC emission 

factors were derived from the EPA publication entitled: Revision of Evaporative 

Hydrocarbon Emission Factors (EPA – 450/3-76-039). The emission factors are 107 

pounds of emitted VOC per thousand barrels of produced crude oil and 175 pounds of 

emitted VOC per million cubic feet of produced natural gas. For crude oil production, 

emission controls reflecting NESHAP application of a 45% reduction in VOC were 

considered. This control level was based on EPA determination of an overall 45% 

reduction in VOC from oil and natural gas production facilities. This control reduction 

was obtained from a 5/14/99 EPA fact sheet that was published with the Final Air Toxics 

Rules for Oil and Natural Gas Production Facilities and Natural Gas Transmission and 

Storage Facilities. Rule effectiveness of 80% was then applied, and point source 

deductions were performed to estimate the area source contribution. For natural gas, 

emission controls from Michigan air pollution control rule R336.1629 of 72% and the 

federal emission control reduction in VOC of 19% associated with NESHAP application 

to natural gas transmission and storage were applied. The 19% emission reduction was 

obtained from the 5/14/99 EPA fact sheet that was published with the Final Air Toxics 

Rules for Oil and Natural Gas Production Facilities and Natural Gas Transmission and 

Storage Facilities. The federal NESHAP rule became effective June 17, 1999. Area 

source emissions were then reported using Source Classification Codes (SCC) of 

2310010000 for crude petroleum oil production and 2310020000 for natural gas 

production. 

Vessel Loading/Ballasting 

Evaporative VOC occur from Great Lakes ships when being loaded with gasoline and 

petrochemicals. Vapors are also displaced when cargo tanks are loaded with water for 

ballasting. In order to estimate VOC from vessel loading/ballasting activities, a list of 

marine terminals at Michigan based ports handling petroleum products was obtained 

from the MDOT. Because of the need to acquire information on gasoline and 

petrochemical handling at each Michigan port and the time frames during vessel 

loading/ballasting occurred, a survey form was again sent to the marine terminals that 

were previously surveyed in the 2002 inventory. This State survey approach went 

beyond the EPA’s prescribed inventory procedures in Volume III, Chapter 12 of the 

Emission Inventory Improvement Program January 2001 guidance for Marine Vessel 

Loading, Ballasting and Transit. The survey form requested information on days of 

operation, seasonal fuel transfer information on gasoline, distillate fuel oil, jet naphtha, 

jet kerosene, kerosene, residual fuel oil, and crude petroleum loading into ship and 

barge cargo tanks as well as ballast operations. The survey data was then summed to 

derive individual county totals. The results of this survey revealed that there were only 

 15
two fuel types (contaminated gasoline, and residual fuel oil) where loading had 

occurred. VOC emission factors (0.00009 lbs/1000 gallons of residual fuel oil and 3.4 

lbs/1000 gallons of gasoline) were then applied to their respective fuel volumes to 

obtain the estimated emission losses. Although the EPA, on September 19, 1995, 

issued Federal Standards for Marine Tank Vessel Loading Operations and National 

Emission Standards for Hazardous Air Pollutants for Marine Vessel Loading Operations, 

the respective facilities transferring fuel were exempt from control requirements. 

Consequently, emissions estimates were based on the respective emission factors 

without the application of control measures. Individual county VOC emission estimates 

from loading and ballasting operations were reported using the following SCC codes: 

Vessel Loading/Ballasting 

Operations 

Reported 

SCC Code 

Vessel loading, distillate fuel 

oil 

2505020090 

Vessel loading, gasoline 2505020120 

Vessel loading, residual fuel 

oil 

2505020060 

Vessel loading, crude oil 2505020030 

Vessel loading, naphtha 2505020150 

Vessel loading, jet kerosene 2505020180 

Vessel loading, kerosene 2505020180 

Vessel ballasting, gasoline 2505020900 

Vessel ballasting, crude oil 2505020900 

Service Station Loading (Stage I) 

Gasoline vapor loss occurs at service stations when gasoline is unloaded from delivery 

tank trucks into underground storage tanks. The extent of vapor loss is dependent upon 

the method of filling (splash, submerge, or vapor balanced). In computing VOC 

emissions from service station loading, year 2005 gasoline throughput estimates were 

obtained from Energy Information Administration's Petroleum Marketing Monthly data. 

The monthly data was then summed to derive an estimated statewide gasoline total. 

County gasoline total estimates were then determined by apportioning the statewide 

gasoline by the percent of state gasoline sales occurring within each county. County 

gasoline sales data was obtained from the U.S. Department of Commerce, Bureau of 

Census, Michigan 1997 Economic Census, Retail Trade, Geographic Area Series. State 

gasoline throughput consumption was apportioned on a county basis using the following 

mathematical equation: 

Ct = St x Cs/Ss 

 16
Where: 

Ct = Estimated county gasoline consumption for year 2005 

St = Statewide gasoline consumption for year 2005 

Cs = County gasoline service station retail sales data 

Ss = State gasoline service station retail sales data 

VOC emission estimates were developed based upon the guidance provided in the EPA 

prescribed inventory procedures in Volume III, Chapter 11 of the Emission Inventory 

Improvement Program January 2001 guidance for Gasoline Marketing (Stage I and 

Stage II) and subsequent September 2002 Draft Summary of the Analysis of the 

Emissions Reported in the 1999 NEI for Stage I and Stage II Operations at Gasoline 

Service Stations. Year 2005 and summer weekday emission factors were developed 

based upon actual temperature, and RVP fuel volatility information for various regions of 

the State to reflect the applicable RVP control measures. Monthly temperature data 

was obtained for the year 2005 from the NOAA, National Climatic Center Local 

Climatological Data that was utilized in determining year and summer day temperatures 

for the Michigan Upper Peninsula and Michigan Lower Peninsula regions. Reid Vapor 

Pressure (RVP) data for marketed gasoline during year 2005 was obtained from the 

Michigan Department of Agriculture, Motor Fuels Quality, Laboratory Division. VOC 

mission factors were then developed for splash fill, submerge fill, and vapor balanced 

gasoline dispensing facilities on a county basis which reflected the actual temperature 

and RVP of marketed gasoline products. 

Year 2005 Temperature Summary

Lower Upper

Peninsula Peninsula

Month Month

Avg of Day Avg of Day

Month Maximum Maximum

December 33.5 24.8

January 28.0 18.9

February 33.8 29.5

March 38.2 33.2

April 59.7 53.8

May 64.8 59.3

June 82.4 77.1

July 83.5 79.4

August 81.8 77.1

September 77.3 72.5

October 62.1 55.7

November 49.4 37.1

Year Avg 57.9 51.5

Ozone Season Avg 74.9 69.9

Summer Weekday Avg 82.6 77.9

Stage I loading emission factors were 

determined using the methodology specified in 

September 2002 Draft Summary of the 

Analysis of the Emissions Reported in the 1999 

NEI for Stage I and Stage II Operations at 

Gasoline Service Stations. The following 

equation is presented: 

L = 12.46xSPM/T 

Where: 

L = Loading loss (uncontrolled), pounds per 

1000 gal of liquid 

 loaded 

S= A saturation factor where S= 0.6 for 

submerged loading 

 with no vapor balance, S = 1.00 for 

submerge loading 

 with vapor balance, and S = 1.45 = splash 

 17
 18

loading no 

 vapor balance 

P = True vapor pressure of liquid loaded, pounds per square 

 inch absolute (psia) 

M = Molecular weight of vapors, pounds per pound-mole 

T = Temperature of bulk liquid in degrees F + 460 

The quantity of county gasoline throughput that is splash filled, submerge filled, and 

vapor balanced was estimated on basis of past gasoline surveys, and the applicability of 

state regulations which require the installation of submerge fill or vapor balanced 

systems. These percentages were obtained from the year 1999 emissions inventory. 

The same county fractional percentages of splash filled, submerge filled, and vapor 

balanced were used in the year 2005 inventory for consistency with respect to prior 

emission inventory. 

The respective emission estimates were reported using the following SCC codes: 

Michigan Gasoline Marketing Stage I Emission SCC Codes 

Stage I Type SCC 

Submerge filled 

loading 

2501060051 

Splash filled 

loading 

2501060052 

Vapor balanced 

loading 

2501060053 

The EPA on December 19, 2003 issued final rule requirements for Stage I gasoline 

distribution in Standards of Performance for Bulk Gasoline Terminals and National 

Emission Standards for Gasoline Distribution Facilities (Bulk Gasoline Terminals and 

Pipeline Breakout Stations. These NESHAP requirements will be applied in point 

source inventories for bulk terminals. 
19

Calculation of Stage I Emission Factors for Year 2005

Notes: Gasoline stage I temperatures based on available data as of 5/18/06. Reid vapor pressures were derived from Michigan Dept. of Agriculture analytical data which showed higher than expected averages due to the suspension of RVP restrictions during Hurricane Katrina. 

Ozone Summer Year 2005 Year 2005 Year 2005 Year 2005 

Year 

2005 Season Weekday Ozone Summer Ozone Summer 

Annual 

4/1/05-

9/30/05 

6/1/05-

8/31/05 Year 2005 Season Weekday Year Ozone Summer 

Year 

2005 Season Weekday 

Emission Emission Emission Annual 

4/1/05-

9/30/05 

6/1/05-

8/31/05 2005 Season Weekday Annual 

4/1/05-

9/30/05 

6/1/05-

8/31/05 S

Factor Factor Factor Temperature Temperature Temperature Annual RVP RVP 

True 

Vapor True Vapor True Vapor 

Region 

lbs/1000 

gal 

lbs/1000 

gal 

lbs/1000 

gal F F F RVP 

4/1/05-

9/30/05 

6/1/05-

8/31/05 

Pressure 

P Pressure P Pressure P 

Vapor Balance Gasoline Upper Peninsula 0.76 0.91 0.99 51.1 69.9 77.9 11.2 9.6 9.0 4.82 5.82 6.4 Lower Peninsula 0.86 1.00 1.07 57.9 74.9 82.6 11.2 9.6 9.0 5.58 6.5 7 SE Michigan 0.86 0.96 0.99 57.9 74.9 82.6 11.2 9.3 8.4 5.58 6.23 6.4 Submerge Fill GasolineUpper Peninsula 4.54 5.44 5.93 51.1 69.9 77.9 11.2 9.6 9.0 4.82 5.82 6.4 Lower Peninsula 5.19 6.01 6.43 57.9 74.9 82.6 11.2 9.6 9.0 5.58 6.5 7 

SE Michigan 5.19 5.79 5.91 57.9 74.9 82.6 11.2 9.3 8.4 5.58 6.23 6.4 Splash Fill Gasoline Upper Peninsula 10.97 13.14 14.33 51.1 69.9 77.9 11.2 9.6 9.0 4.82 5.82 6.4 Lower Peninsula 12.54 14.53 15.54 57.9 74.9 82.6 11.2 9.6 9.0 5.58 6.5 7 SE Michigan 12.54 13.99 14.29 57.9 74.9 82.6 11.2 9.3 8.4 5.58 6.23 6.4 
20

Service Station Unloading/Vehicle Fueling (Stage II) 

Motor vehicle fueling at service stations results in evaporative loss of gasoline. VOC 

emissions are produced during displacement of vaporized hydrocarbons and spillage of 

gasoline during refueling. EPA guidance in Volume III, Chapter 11 of the Emission 

Inventory Improvement Program January 2001 guidance for Gasoline Marketing (Stage 

I and Stage II) recommends the MOBILE model be used to generate refueling (Stage II) 

emission factors for highway emission inventories. Additional procedures were 

presented in September 2002 Draft Summary of the Analysis of the Emissions Reported 

in the 1999 NEI for Stage I and Stage II Operations at Gasoline Service Stations. The 

MOBILE6 model was used to derive the Stage II emission factor by obtaining monthly 

emission factors in grams/VOC mile as well as fuel economy as miles per gallon and 

vehicle miles traveled mix for the different gasoline vehicle types (e.g., LDTV, LDGT, 

and HDGV). For each vehicle type, the monthly emission factor was multiplied by the 

fuel economy to obtain an emission factor in unit grams of VOC/gallon. 

 grams VOC/gallon = Grams/mile x miles/gallon 

Stage II grams/gallon refueling emission factor rates were initially prepared by 

SEMCOG using MOBILE6.2 and then later adjusted for year 2005 state specific RVP 

and temperature data. The vehicle miles traveled (VMT) mix for each vehicle types was 

used to calculate a single weighted monthly emission factor. Summer and average 

annual emission factors were then developed for Southeast Michigan, the rest of the 

Lower Peninsula, and the Upper Peninsula. SEMCOG’s Stage II grams/gallon adjusted 

emission factors are presented below. It is noted that the Stage II emission rates for 

year 2005 were greater than year 2002 rates due to the marketing of RVP exempt fuels 

created by Hurricane Katrina disruption of refinery operations. 

Year 2005 Refueling Emission Rates for State of Michigan 

Average Type and Geographical Area Grams/Gal

lon 

Summer (Average of monthly refueling emission rates for June, July & 

August, 2005) 

 Southeast Michigan (Livingston, Macomb, Monroe, Oakland, St. Clair, 

Washtenaw and Wayne counties) 

2.71 

 Rest of Lower Peninsula (All counties in Lower Peninsula except the 

7 Southeast Michigan counties) 

3.04 

 Upper Peninsula (All counties in the Upper Peninsula) 2.85 

Average Annual (Average of monthly refueling emission rates) 

 Southeast Michigan (Livingston, Macomb, Monroe, Oakland, St. Clair, 

Washtenaw and Wayne counties) 

2.94 

 Rest of Lower Peninsula (All counties in Lower Peninsula except the 

7 Southeast Michigan counties) 

3.05 

 Upper Peninsula (All counties in the Upper Peninsula) 2.94 
21

All rates were initially calculated using MOBILE6.2 model, and then later adjusted for 

year 2005 RVP and temperature conditions. 

The respective SEMCOG grams VOC/gallon were then converted to lbs/1000 gallons. 

 Lbs VOC/1000 gallons = Grams VOC/gallon x 1 lb/453 grams x 1000 gallons 

Year 2005 gasoline throughput estimates were obtained from Energy Information 

Administration's Petroleum Marketing Monthly data. The monthly data was then 

summed to derive an estimated statewide gasoline total. County gasoline total 

estimates were then determined by apportioning the statewide gasoline by the percent 

of state gasoline sales occurring within each county. County gasoline sales data was 

obtained from the U.S. Department of Commerce, Bureau of Census, Michigan 1997 

Economic Census, Retail Trade, Geographic Area Series. Total county emissions 

estimates were based on the county gasoline volume by the corresponding refueling 

emission factor. Emission rates were reported using the SCC code 2501060100. 

Service Station Tank Breathing 

Pressure changes occur within underground storage tanks as a result of temperature 

differences that exist between gasoline vapor and the liquid phases. The exchange of 

vapor within the storage tank to the atmosphere is commonly described as tank 

breathing. 

Underground gasoline storage tank breathing losses were estimated by applying a 1.0 

pound per thousand gallon throughput emission factor using procedures presented in 

EPA’s Volume III, Chapter 11 of the Emission Inventory Improvement Program January 

2001 guidance for Gasoline Marketing (Stage I and Stage II) and September 2002 Draft 

Summary of the Analysis of the Emissions Reported in the 1999 NEI for Stage I and 

Stage II Operations at Gasoline Service Stations. Year 2005 county gasoline 

consumption estimates were obtained by apportionment of the statewide gasoline 

consumption based on the county percentage of state gasoline retail sales. Statewide 

gasoline consumption data was obtained from Energy Information Administration's 

Petroleum Marketing Monthly and county retail gasoline sales information was identified 

in the U.S. Department of Commerce, Bureau of Census, Michigan 1997 Economic 

Census, Retail Trade, Geographic Area Series. Emission estimates were reported 

using the SCC of 2501060200.

Gasoline Tank Truck Transit 

Breathing losses from gasoline tank trucks occurs as a result of pressure changes 

within the containment vessel. The pressure change in the containment vessel is 

caused by temperature differences between the vapor and liquid phases as well as 
22

agitation during transport. Gasoline tank trucks leak VOC vapors and liquids from 

gaskets, seals, and seams during transport. 

Because some gasoline is delivered to bulk plants rather than delivered directly to 

service stations from terminals, the amount of gasoline transferred in any area may 

exceed the total gasoline consumption, due to additional trips involved. Therefore, 

gasoline tank truck transit evaporation emissions were based on the total volume of 

gasoline transferred rather than county consumption level. 

The total gasoline transferred in a given county was obtained by taking the sum of both 

the service station volume delivery and the bulk plant gasoline transfer. The bulk plant 

gasoline transfer volume in a county was obtained from point source data. VOC 

emissions estimates were developed using the gasoline tank truck transit emission 

factors identified by EPA procedures presented in Volume III, Chapter 11 of the 

Emission Inventory Improvement Program January 2001 guidance for Gasoline 

Marketing (Stage I and Stage II) . In this document, VOC loss from gas filled tank truck 

emission factor was 0.005 lbs/1000 gallons while empty vapor-filled tank trucks were 

0.055 lbs/1000 gallons. A single emission factor of 0.06 lbs/1000 gallons was derived 

by taking the sum of the two respective factors, and then applying this emission factor to 

the total transported gasoline volume. Further emission adjustments were then made to 

the respective emission totals to reflect those delivery vessels in those counties that are 

subject to Michigan Air Pollution Control Rule R 336.1627. A control efficiency of 76% 

was considered before subsequent application of an 80% rule effectiveness and 100% 

rule penetration factors for delivery vessels in those counties subject to R336.1627. 

Emission estimates were reported using the SCC of 2505030120. 

Aviation Fuel Stage I Loading 

Gasoline vapor loss occurs at airports when gasoline is unloaded from delivery tank 

trucks into underground storage tanks. Because of the need to temporally adjust aircraft 

refueling emissions for all respective fuel types within all Michigan counties, it was 

determined that local aviation fuel sales information could only be acquired by 

contacting each fuel distributor serving each airport. Because the fleet of the aircraft 

varies at each airport, the amount of fuel type consumed will likewise be dependent on 

the types of aircraft being serviced and not just based upon Landing-Take Offs (LTOs) 

alone. 

A list of those Michigan commercial and private airports where fuels are dispensed was 

obtained from the MDOT publication 2003 Michigan Airport Directory. A survey form 

was then mail to each airport operations manager. Total fuels sales information by fuel 

type(s) and season were obtained from either airport staff or assigned fixed base 

operators. This information was then summed for each Michigan county to provide an 

estimate of the total volumes of jet kerosene, jet naphtha, and aviation gasoline handled 

at each airport facility. Stage I loading VOC emission factors for jet kerosene and jet 

naphtha were determined using the following equation: 
23

L = 12.46xSPM/T 

Where: 

L = Loading loss (uncontrolled), pounds per 1000 gal of liquid 

 loaded 

S= A saturation factor where 1.45 = splash loading 

P = True vapor pressure of liquid loaded, pounds per square 

 inch absolute (psia) 

M = Molecular weight of vapors, pounds per pound-mole 

T = Temperature of bulk liquid in degrees F + 460 

For Stage I aviation gasoline VOC emissions, an emission factor was obtained the EPA 

publication entitled: Documentation for the 2002 Nonpoint Source National Emission 

Inventory for Criteria and Hazardous Air Pollutants (January 2004 Version). The 

resultant emission factors were then applied to the total county fuel throughput after 

considering point source fuel throughput deductions. Because EPA does not have 

itemized SCC codes by fuel type, VOC emissions were added together and reported 

using a SCC of 2501080050. 

Aircraft Refueling (Stage II) 

Aircraft refueling at airports results in the evaporative loss of aviation gasoline, jet 

kerosene, and jet naphtha. VOC emissions occur when vapor laden air in a partially 

empty fuel tank is displaced to the atmosphere during refueling. The quantity of the 

vapor being displaced is dependent upon the fuel temperature, fuel vapor pressure, 

aircraft fuel tank temperature, and the fuel dispensing rate. 

Because of the need to temporally adjust aircraft refueling emissions for each 

respective fuel type within each Michigan county, it was determined that local aviation 

fuel sales information could only be acquired by contacting each fuel distributor serving 

each airport. Because the fleet of the aircraft varies at each airport, the amount of fuel 

type consumed will likewise be dependent on the types of aircraft being serviced and 

not just based upon LTOs alone. 

A list of those Michigan commercial and private airports where fuels are dispensed was 

obtained from the MDOT publication 2003 Michigan Airport Directory. A survey form 

was then mailed to each airport operations manager. Total fuels sales information by 

fuel type(s) and season were obtained from either airport staff or assigned fixed base 

operators. This information was then summed for each Michigan county to provide the 
24

total dispensed volumes of jet kerosene, jet naphtha, and aviation gasoline. VOC 

aviation refueling loss emission factors were obtained from the EPA publication 

Compilation of Air Pollutant Emission Factors, Volume 1: Stationary Point and Area 

Sources, 5th Edition and Supplements (AP-42) were then applied to the respective 

county total fuel volumes. 

Aviation Fuel 

Type 

Emission Factor as lbs of 

VOC/1000 gallons fuel 

Jet kerosene 0.08 

Jet naphtha 5.58 

Aviation 

gasoline 

12.20 

Because there is no provision currently to allow for the reporting of emissions by 

individual fuel type, emissions were then summed for all fuel types and reported using 

the SCC code 2275900000. 

Traffic Marking Coatings 

Traffic marking coatings are paints that are used to mark pavement, including dividing 

lines for traffic lanes, parking space markings, crosswalks, and arrows to direct traffic 

flow. VOC emissions result from the evaporation of organic solvents during the 

application and curing of the marking paint. 

VOC emissions were estimated for each county using the methodology identified in the 

EPA’s Volume III, Chapter 14 of the Emission Inventory Improvement Program May 

1997 Final Guidance for Traffic Markings. The preferred method was to conduct 

surveys to determine the volume of water and solvent based coating consumption, 

coating formulation (in terms of pounds of VOC content per applied gallon), and months 

of year 2005 when the coatings were applied. Survey forms were mailed to all Michigan 

county road commissions, major municipality road maintenance departments, and to 

MDOT. In those situations where a county road commission failed to submit such 

information, emission estimates were based upon results of those counties that had 

responded to the survey. An average coating application rate (total gallons of coating 

applied per road miles in county) was first determined from survey respondents. Road 

length miles were obtained for the counties that failed to respond to the survey. Total 

coating gallon consumption estimates were estimated for counties that failed to respond 

by applying the road length miles to the average coating application rate. Similarly, an 

average VOC content (as lbs/gallon) was obtained by dividing the total mass of VOC 

emissions by the total coating volume of survey respondents. The result thereof was 

then applied to the estimated coating volumes for those counties that did not respond to 

the survey. This average density was reflective of the proportions of solvent and water 

based coatings by survey respondents. Seasonal coating application was also based 
25

upon county survey results of the months during which the coatings were applied. It 

should be recognized that year 2002 was a recession year in which Michigan county 

and local governments had limited budgets. Consequently, it is likely that projected 

emissions would be greater during better economic times. Traffic marking paint 

emissions were reported using a SCC of 2401008000 

Cutback Asphalts 

Cutback asphalt is a bituminous road coating material that is prepared by blending an 

asphalt cement tar with a petroleum distillate (such as naphtha, kerosene, or other fuel 

oils). Cutback asphalt is used as a pavement sealant, tack coat, pothole filler, and a 

bonding agent between layers of paving material. Evaporative loss of the solvent from 

bitumen cement occurs as the cutback asphalt cures on the road surface. The rate at 

which VOC emissions occur is dependent both upon the temperature of the applied 

road surface, and the type of solvent used in the formulation of the cutback asphalt 

material. Gasoline or naphtha is used as a diluent in the production of “rapid cure” 

cutback asphalts. Kerosene and other low volatility fuel oils are also used as diluents in 

the production of “medium cure” and “slow cure” cutback asphalts. 

VOC emissions were estimated for each county using the methodology identified in the 

EPA’s Volume III, Chapter 17 of the Emission Inventory Improvement Program January 

2001 Final Guidance for Asphalt Paving. In this document, the preferred method was to 

conduct surveys to determine locally-specific information on cutback asphalt use on 

Michigan roads. 

In order to estimate VOC emissions from the application of cutback asphalt materials 

(rapid cure, medium cure, and slow cure), a survey was mailed to all Michigan county 

road commissions, major municipality road maintenance departments, and to MDOT. 

The survey requested information on: 

1. The quantities of rapid cure, medium cure, and slow cure cutback asphalt 

materials that were applied during year 2005; 

2. The type of petroleum distillate and volume that was used as a diluent in the 

formulation of each cutback paving material; and 

3. The months during which cutback asphalt materials were applied. 

The EPA has determined that evaporation occurs on about four months with 75 percent 

by weight of diluent evaporates in the first day for rapid cure materials while it takes 

about one week for 50 percent by weight of diluent to evaporate from medium cure 

cutback asphalt materials. Conservative estimates were made by assuming that all the 

diluent evaporates within the season during which it is applied. 
26

VOC emission estimates were based on the amount of the petroleum based diluent that 

comprises the cutback asphalt material and then applying their respective solvent 

density. Emission estimates were reported using a SCC of 2461021000. 

Emulsified Asphalts 

Emulsified asphalts are a type of liquefied road surfacing material that is used in the 

same application as cutback asphalts. Instead of blending the asphalt material with a 

petroleum distillate like their cutback asphalt counterparts, emulsified asphalts use a 

blend of water with an emulsifier (soap). Emulsified asphalts either rely on water 

evaporation to cure (anionic-high float emulsions) or ionic bonding of the emulsion and 

the aggregate surface (cationic emulsions). 

In the EPA’s Volume III, Chapter 17 of the Emission Inventory Improvement Program 

January 2001 Final Guidance for Asphalt Paving., the preferred method is conduct a 

survey of emulsified asphalt application on Michigan roads. Survey forms were mailed 

to all Michigan county road commissions, major municipality road maintenance 

departments, and to MDOT. This form requested information on the quantities of 

asphalt materials (in pounds and barrels) applied to Michigan roadways and the months 

during which they were applied. Road length miles were also obtained for all Michigan 

counties. In those situations where a county road commission failed to submit such 

information, emission estimates were based upon results of those counties that had 

responded to the survey. An average application rate (total barrels of emulsified 

asphalts applied per road miles in county) was first determined from survey 

respondents. Total barrel consumption estimates were estimated for counties that 

failed to respond by applying the road length miles to the average emulsified asphalt 

application rate. VOC emissions were obtained by applying an EPA factor of 9.2 lbs 

VOC/barrel of applied asphalt. It was further assumed that all emissions occur during 

the season that the asphalt materials were applied and reported using a SCC of 

2461022000. 

Breweries 

Breweries, microbreweries, brewpubs, and contract brewers emit VOC including 

ethanol, ethyl acetate, myrcene and other higher alcohols from various brewing 

processes. For the smaller brewers, VOC are lost by the fermentation, in brew kettles, 

hot wort, mash and lauter tuns, and through spent grain. Microbreweries and brewpubs 

typically produce beer for patron on-site consumption, although some may have limited 

keg distribution. These smaller microbreweries and brewpubs typically combine some 

processes, and canning/bottling operations typically do not exist since the beer is 

consumed on-site or stored in kegs. 

Various trade organization lists were obtained to identify brewers in the State of 

Michigan along with their beer production. Although there are some regional breweries, 

the vast majority are brewpubs and microbreweries. These facilities have very small to 
27

insignificant volatile organic compound emissions. Emission estimates were based on a 

combined emission factor rate obtained from Compilation of Air Pollutant Emission 

Factors, Volume 1: Stationary Point and Area Sources, 5th Edition and Supplements 

(AP-42) of 3.0465 lbs VOC per 1000 barrels. Consequently, this small emission factor 

and Michigan beer production rates didn’t justify the need for a survey of such 

establishments. Emissions were estimated by establishment on the basis of trade 

reported production and applying the respective emission factor. A SCC of 2302070001 

was used in reporting brewery emissions. 

Distilleries 

Distilleries include ethanol production facilities that are used in the production of 

gasohol motor fuels, grain alcohol for industrial purposes, and distilled spirits for 

personal consumption. These products are produced from the fermentation of aged 

mashed grains with distillation for the capture of desired alcohol based products. The 

fermentation products use yeast to convert grain sugars into ethanol, ethyl acetate, 

isomyl alcohol, isobutyl alcohol and carbon dioxide. Grains used in the process may 

include corn, rye, barley, and wheat. A more detailed description of distilleries and their 

emissions can be found in the EPA publication entitled: Compilation of Air Pollutant 

Emission Factors, Volume 1: Stationary Point and Area Sources, 5th Edition and 

Supplements (AP-42).

During year 2005, there was only one ethanol production facility in operation. The 

Michigan Ethanol LLC - Caro, Michigan facility was already being reported as a point 

source. Consequently, the area source contribution from distilleries using SCC 

2302070010 had zero emissions for all Michigan counties. A number of new ethanol 

plants were under construction, but did not operate in the 2005 inventory year. 

Wineries 

Wineries produce alcohol beverages from the fermentation of fruit juices. The major 

processes in vinification include fruit harvesting, crushing, pressing, fermentation, 

clarification, aging, finishing, and bottling. During this fermentation process of both red 

and white wines, primarily ethanol and smaller quantities of methyl alcohol, n-propyl 

alcohol, butyl alcohol, isoamyl alcohol, and acetaldehydes are produced along with 

carbon dioxide. This process involves the reaction of a yeast with glucose and fructose 

sugars to produce ethanol and carbon dioxide. The EPA emission factors are reflective 

of VOC evolved during fermentation in vinification. 

County estimates of wine production were based upon wine volume information of 

Michigan Department of Treasury tax receipt information supplied to the Michigan 

Grape and Wine Industry Council. A VOC emission factor was obtained from 

Compilation of Air Pollutant Emission Factors, Volume 1: Stationary Point and Area 

Sources, 5th Edition and Supplements (AP-42).of 4.6263 lbs VOC/ 1000 gallons This 

emission factor is a sum of ethyl alcohol, methyl alcohol, n-propyl alcohol, n-butyl 
28

alcohol, sec-butyl alcohol, isobutyl alcohol, isoamyl alcohol and acetaldehyde for red 

wine from AP-42. Emission estimates were reported using a SCC of 230207005 

Stationary Source Fossil Fuel Combustion 

The combustion of natural gas, propane-LPG, distillate fuel oil, kerosene, and residual 

fuel oil in small boilers, furnaces, heaters, and stoves are also a source of VOC, NOx, 

particulates, sulfur dioxide, and ammonia emissions. Because these sources are so 

numerous to be identified in point source inventories, this area source category 

attempts to provide a collective estimate of emissions from these smaller energy 

consumption sources by subtracting all fuel used by point sources from total fuel 

consumption. Procedures for the estimation of these smaller sources are presented in 

the EPA’s documents entitled: 

1. Volume II, Chapter 2 of the Emission Inventory Improvement Program January 

2001 Preferred and Alternate Methods for Estimating Air Emissions from Boilers. 

2. Emission Inventory Improvement Program –April 6, 1999, Area Source Category 

Abstract- Fuel Oil and Kerosene Combustion 

3. Emission Inventory Improvement Program –April 6, 1999, Area Source Category 

Abstract-Natural Gas and LPG Combustion

4. Emission Inventory Improvement Program –April 6, 1999, Area Source Category 

Abstract-Coal Combustion

5. Documentation for the Draft 1999 National Emissions Inventory (Version 3.0) for 

Criteria Air Pollutants and Ammonia

6. Hanke, B.H, manuscript prepared for U.S Environmental Protection Agency 

entitled: A National Methodology and Emission Inventory for Residential Fuel 

Combustion

This documentation involves determination of total fuel consumption over an area with 

subsequent fuel deductions made for point source fuel consumption, and then applying 

emissions factors to estimate fuel emissions. 

Total fuel consumption information was based on data supplied from U.S. Department 

of Energy, EIA documents. This unaccounted fuel consumption was then apportioned to 

individual counties using U.S. Census Bureau information for the individual end use 

sector fuel types based upon LADCO states methodology. Area source fuel emissions 

were reported for the following residential, commercial/institutional, and industrial end 

use sectors. Since utility boilers are accounted as point sources, area source emissions 

are not reported for this end use sector. 
29

Residential Boilers & Furnaces 

County emission estimates for the residential end use sector was based upon the 

consumption of natural gas, propane-LPG, distillate fuel oil, kerosene, and coal. This 

energy consumption information was obtained from U.S. Department of Energy, EIA 

data. Since the EIA merely provides statewide fuel consumption totals, county fuel 

consumption estimates were obtained by apportioning the fuel consumption based upon 

the number of year 2000 occupied household census counts using the given fuel. 

Emission estimates were calculated using the following mathematical equation: 

 Cf = Ch/Sh x Sf 

Where 

Cf = Estimated county residential sector consumption of a given fuel type for year 2005 

Ch = Number of year 2000 census occupied households in a given county that utilize a 

given fuel type 

Sh = Total number of year 2000 census occupied households statewide that utilize a 

given fuel type 

Sf = Total statewide residential sector consumption of a given fuel type 

Michigan Residential Fuel Consumption Information Sources 

Residential Fuel 

Type 

U.S. Dept of Energy, EIA Data Sources 

Natural gas Natural Gas Annual 2005, Michigan Table 48 

Propane LPG Petroleum Marketing Annual, 2005, Table 49: Prime 

Supplier Sales Volumes of Aviation Fuels, Propane and 

Residual Fuel Oil by PAD District and State 

Distillate fuel oil Fuel Oil and Kerosene Sales 2005 Report, Table 19: 

Adjusted Sales for Residential Use: Distillate Fuel Oil and 

Kerosene, 2005 

Kerosene Fuel Oil and Kerosene Sales 2005 Report, Table 18: 

Adjusted Sales of Kerosene by Energy Use 

Coal EIA Annual Coal Report 2005, Table 26 U.S. Coal 

Consumption by End Use Sector, by Census Division and 

State 2005, 2004 (Thousand Short Tons) 
30

Upon obtaining county residential fuel consumption estimates for the various fuel types 

in all Michigan counties Cf, emission estimates were obtained by applying an emission 

factor that is specific to that fuel type. These emission factors were obtained from 

various EPA publications. 

Michigan Residential Fuel Emission Factors 

Residential 

Fuel Type 

Units CO NH3 NOx PM10-

PRI 

PM25-

PRI 

SO2 VOC

Natural gas Lbs/million 

cubic feet 

40 0.49 94 7.6 7.6 0.6 5.5 

Propane 

LPG 

Lbs/1000 

gal 

3.2 13 0.68 0.68 0.1 0.5 

Distillate 

fuel oil 

Lbs/1000 

gal 

5.0 0.8 18 2.38 2.13 42.60 0.7 

Kerosene Lbs/1000 

gal 

4.8 0.8 17.4 2.38 2.13 41.1 0.7 

Coal Lbs/ton 275 0.000565 3.0 18.63 4.86 37.83 10 

Sources of Emission Factors: 

1. U.S. Environmental Protection Agency Documentation for the Draft 1999 

National Emissions Inventory (Version 3.0) for Criteria Air Pollutants and 

Ammonia

2. Hanke, B.H, manuscript prepared for U.S Environmental Protection Agency 

entitled: A National Methodology and Emission Inventory for Residential Fuel 

Combustion

3. U.S. Environmental Protection Agency. Final Report on Development and 

Selection of Ammonia Emission Factors

The resulting emission estimates were reported by individual fuel type using the 

following SCC codes. 
31

Michigan Residential Combustion Emission SCC Codes 

Residential Fuel 

Type 

SCC 

Natural gas 2104006000 

Propane LPG 2199007000 

Distillate fuel oil 2104004000 

Kerosene 2104011000 

Coal 2104001000 

Commercial/Institutional Boilers and Furnaces 

Estimation of fuel combustion by the commercial/institutional sector was performed 

using an adaptation of a methodology presented in the U.S. Environmental Protection 

Agency publications: 

1. Emission Inventory Improvement Program –April 6, 1999, Area Source Category 

Abstract- Fuel Oil and Kerosene Combustion 

2. Emission Inventory Improvement Program –April 6, 1999, Area Source Category 

Abstract-Natural Gas and LPG Combustion

3. Emission Inventory Improvement Program –April 6, 1999, Area Source Category 

Abstract-Coal Combustion

County emission estimates for the commercial/institutional end use sector were based 

upon the consumption of natural gas, residual fuel oil, distillate fuel oil, kerosene, and 

coal. This energy consumption information was obtained from U.S. Department of 

Energy, EIA data. Fuels were subtracted for point sources, and the net area fuel 

contribution was apportioned or allocated using procedures instructed by LADCO. This 

procedure involved statewide commercial/ institutional fuel apportionment to a county 

level using the commercial/institutional employment data as obtained from U.S. 

Department of Commerce, Bureau of Census publication entitled: County Business 

Patterns, Michigan: 2003 (CBP/03-24 issued September, 2005). County fuel estimates 

of individual fuel types were estimated using the following equation: 

 Cf = Ce/Se x Sf 

Cf = Estimated county commercial/institutional sector consumption of a given fuel type 

Ce= Total county employment in the commercial/institutional sector 

Se= Statewide employment in commercial/institutional sector 

Sf= Statewide commercial/institutional sector consumption of a given fuel type 
32

Because the Energy Information data includes diesel fuel totals within the distillate fuel 

oil total, these motor vehicle fuels were deducted to provide only an estimate of #1, #2, 

and #4 fuel oils. 

Michigan Commercial/Institutional Fuel Consumption Information Sources 

Fuel Type U.S. Dept of Energy, EIA Data Sources 

Natural gas Natural Gas Annual 2005, Michigan Table 48 

Residual fuel oil Fuel Oil and Kerosene Sales 2005 Report, Table 17: 

Adjusted Sales of Residual Oil by Energy Use, 2004 and 

2005 

Distillate fuel oil Fuel Oil and Kerosene Sales 2005 Report, Table 20: 

Adjusted Sales for Commercial Use: Distillate Fuel Oil, 

Residual Fuel Oil and Kerosene 2005 

Kerosene Fuel Oil and Kerosene Sales 2005 Report, Table 18: 

Adjusted Sales of Kerosene by Energy Use 

Coal EIA Annual Coal Report 2005, Table 26 U.S. Coal 

Consumption by End Use Sector, by Census Division and 

State 2005, 2004 (Thousand Short Tons) 

Upon obtaining county commercial/institutional fuel consumption estimates for the 

various fuel types in all Michigan counties Cf, emission estimates were obtained by 

applying an emission factor that is specific to that fuel type. These emission factors 

were obtained from various EPA publications. 

Michigan Commercial/Institutional Fuel Emission Factors 

Commercial/Institutional 

Fuel Type 

Units CO NH3 NOx PM10-

PRI 

PM25-

PRI 

SO2 VOC 

Natural gas Lbs/million 

cubic feet 

84 0.49 100 7.6 7.6 0.6 5.5 

Residual fuel oil Lbs/1000 

gal 

5 0.80 55 9.07 3.37 194.05 1.13 

Distillate fuel oil Lbs/1000 

gal 

5 0.80 20 2.38 2.13 53.96 0.34 

Kerosene Lbs/1000 

gal 

5 0.80 18 2.38 2.13 41.1 0.713

Coal Lbs/ton 6 0.000565 7.5 6.0 2.2 36.86 0.05 
33

Sources of Emission Factors: 

1. LADCO state uniform adopted emission factors for commercial/institutional 

natural gas combustion 

2. U.S. Environmental Protection Agency. FIRES database 

3. U.S. Environmental Protection Agency. Compilation of Air Pollutant Emission 

Factors, Volume 1: Stationary Point and Area Sources, 5th Edition and 

Supplements (AP-42)

4. U.S. Environmental Protection Agency. Final Report on Development and 

Selection of Ammonia Emission Factors

The resulting emission estimates were reported by individual fuel type using the 

following SCC codes. 

Michigan Commercial/Institutional Combustion Emission SCC Codes 

 Fuel Type SCC 

Natural gas 2103006000 

Residual fuel oil 2103005000 

Distillate fuel oil 2103004000 

Kerosene 2103011005 

Coal 2103002000 

Industrial Boilers and Furnaces 

Estimation of fuel combustion emissions of industrial boilers and furnaces was 

performed in similar manner as the commercial/institutional sector. Statewide industrial 

fuel consumption information was obtained from the U.S. Department of Energy, EIA 

publications. Point source deductions were made for each fuel type to obtain the area 

contribution which was then apportioned to the county level using LADCO prescribed 

procedures. 

 

County fuel consumption estimates of natural gas, residual fuel oil, distillate fuel oil, 

kerosene, and coal were based upon the following mathematical equation: 

 Cf = Ce/Se x Sf 
34

Cf = Estimated county industrial sector consumption of a given fuel type 

Ce= Total county employment in the industrial sector 

Se= Statewide employment in industrial sector 

Sf= Statewide industrial sector consumption of a given fuel type 

Michigan Industrial Fuel Consumption Information Sources 

Industrial Fuel 

Type 

U.S. Dept of Energy, EIA Data Sources 

Natural gas Natural Gas Annual 2005, Michigan Table 48 

Residual fuel oil Fuel Oil and Kerosene Sales 2005 Report, Table 17: 

Adjusted Sales of Residual Oil by Energy Use, 2004 and 

2005 

Distillate fuel oil Fuel Oil and Kerosene Sales 2005 Report, Table 21 

Adjusted Sales for Industrial Use: Distillate Fuel Oil, 

Residual Fuel Oil, and Kerosene (#1, #2, and #4 fuel 

oils– excludes diesel oil) 

Kerosene Fuel Oil and Kerosene Sales 2005 Report, , Table 18: 

Adjusted Sales of Kerosene by Energy Use 

Coal EIA Annual Coal Report 2005, Table 26 U.S. Coal 

Consumption by End Use Sector, by Census Division and 

State 2005, 2004 (Thousand Short Tons) 

County employment data was obtained from the U.S. Department of Commerce, 

Bureau of Census publication entitled: County Business Patterns, Michigan: 2003 

(CBP/03-24 issued September, 2005). Upon obtaining county industrial fuel 

consumption estimates for the various fuel types in all Michigan counties Cf, emission 

estimates were obtained by applying an emission factor that is specific to that fuel type. 

These emission factors were generally based on the LADCO adopted emissions 

factors. 
35

Michigan Industrial Fuel Emission Factors 

Industrial 

Fuel Type 

Units CO NH3 NOx PM10-

PRI 

PM25-

PRI 

SO2 VOC 

Natural 

gas 

Lbs/million 

cubic feet 

84 3.2 100 7.6 7.6 0.6 5.5 

Residual 

fuel oil 

Lbs/1000 

gal 

5.0 0.8 55 7.17 4.67 157 0.28 

Distillate 

fuel oil 

Lbs/1000 

gal 

5.0 0.8 20 2.3 1.55 53.96 0.2 

Kerosene Lbs/1000 

gal 

5.0 0.8 18 2.38 2.13 41.1 0.713

Coal Lbs/ton 6 0.00057 7.5 6.0 2.2 38 0.05 

Sources of Emission Factors: 

1. LADCO state uniform adopted emission factors for industrial natural gas, residual 

fuel oil, distillate fuel oil, and coal combustion 

2. U.S. Environmental Protection Agency. FIRES database 

3. U.S. Environmental Protection Agency. Compilation of Air Pollutant Emission 

Factors, Volume 1: Stationary Point and Area Sources, 5th Edition and 

Supplements (AP-42)

4. U.S. Environmental Protection Agency. Final Report on Development and 

Selection of Ammonia Emission Factors

Emission estimates were reported using the following SCC codes: 

Michigan Industrial Combustion Emission SCC Codes 

Industrial Fuel 

Type 

SCC 

Natural gas 2102006000 

Residual fuel oil 2102005000 

Distillate fuel oil 2102004000 

Kerosene 2102011000 

Coal 2102002000 
36

Remedial Action, Site Clean Up & Leaking Storage Tanks 

Evaporative VOC emissions occur during remediation and clean up at those sites of 

environmental contamination. Such remediation activities may include air stripping or 

sparging of a VOC from contaminated groundwater or incineration of a spoil material 

removed from a contaminated site. In some instances carbon adsorption may be 

required to reduce VOC emitted during air stripping or spraying operations. 

Estimation of VOC loss from remedial action activities was determined by summing the 

allowable emissions from permits to those parties that were engaged in such activities 

as provided by the MDEQ, Air Quality Division, Permit Section. Although site 

remediation activities are subject to NESHAPs, these requirements did not apply at the 

time of the year 2005 emissions inventory. Emissions were reported using a SCC of 

2660000000. 

Municipal Waste Landfills 

A municipal solid waste landfill is defined as any facility that is regulated under Subtitle 

D of the Resource Conservation and Recovery Act (RCRA) which receives primarily 

household and/or commercial wastes. 

VOC are produced from municipal solid waste by: the volatilization of the waste 

material itself, the microbiological (anaerobic) putrefaction of organic waste materials 

that result in the formation of organic acids and alcohols that are vaporized, and the 

chemical reaction of one or more waste materials or chemical decomposition 

intermediate. The rate at which VOCs are emitted from a landfill is dependent upon the 

structural design of cells, the waste composition (physical/chemical properties), the 

moisture content of the waste, the amount of waste disposed, temperature, age of the 

landfill, the chemical reactivity of the waste, the microbiological toxicity of the waste, and 

the effectiveness of landfill gas collection systems. Where landfill gas is collected for 

use in boilers, internal combustion engines (reciprocating and turbines) or flared at the 

landfill site, there are additional air pollutants such as NOx, particulates (PM2.5 and 

PM10), and carbon monoxide produced from incomplete combustion. 

Estimation of VOC emissions from municipal landfills were based on the revised 

technical procedures presented in the EPA publication entitled: Volume III, Chapter 15 

of the Emission Inventory Improvement Program January 2001 Revised Final Guidance 

for Landfills. In this publication, the preferred method for the estimation of area source 

emissions is to use the LandGem model or the equations from the Compilation of Air 

Pollutant Emission Factors, Volume 1: Stationary Point and Area Sources, 5th Edition 

and Supplements (AP-42) section on landfills. LandGem is a computer based model 

that uses the same equations as that of AP-42. The emissions calculation for the 

estimation of landfill gas requires site specific information including: landfill design 

capacity, accumulated waste totals from operation of the landfill, and existing control 

requirements from landfill gas collection systems. Landfills may be subject to either 
37

new source performance standards (40 Code of Federal Regulations part 60 Subpart 

WWW) or emission guidelines (40 Code of Federal Regulations, part 60, Subpart Cc). 

Landfills are now also subject to NESHAPs which became effective on January 16, 

2003. For those landfills that were not being reported in the point source inventory, 

area emission estimates were reported on the basis on LandGem model simulations 

using the SCC of 2620030000. These simulations reflected total waste receipts under 

the prior year 1999 inventory with addition made for waste receipts for years 2000-2005 

as obtained from annual reports by the MDEQ, Waste and Hazardous Division Report 

of Solid Waste Landfilled in Michigan. For those landfills that operated landfill gas 

collection/combustion systems, emission estimates considered tables 2.4-3 and 2.4-5 

of AP-42 with adjustments considered for a landfill gas methane collection efficiency of 

75% of LandGem model predicted methane generation at a given landfill site. 

Non-Methane Organic Compound Control Efficiencies for Landfill Gas 

Combustion from AP-42 

Combustion Control 

Device 

Typical Control Efficiency (%) 

Boilers 98 

Flares 99.2 

Gas Turbines 94.4 

IC Engine 97.2 

Emission Rates for Secondary Compounds from Landfill Gas Combustion 

(Based upon lbs/ Million Cubic Feet of Landfill Gas Combusted) 

Combustion Control 

Device 

NOX PM2.5-

PRI 

PM10-

PRI 

CO 

Flare 40 17 17 750 

IC Engine 250 48 48 470 

Boiler 33 8.2 8.2 5.7 

Gas Turbines 87 22 22 230 

Architectural Surface Coating, 2005 

Alternative method one was chosen from the guidance document Emission Inventory 

Improvement Program (EIIP), Volume III, Area Sources Preferred and Alternative 

Methods, Chapter 3: Architectural Surface Coating. Data was readily available for the 

use of per capita emission factors. 

MDEQ, Air Quality Division staff determined per capita usage factors by dividing the 

2004 national total architectural surface quantities for solvent and water based coatings 

(U.S. Census Bureau MA325F, Paint and Allied Products) by the U.S. population for 

2004 (U.S. Census Bureau, http://www.census.gov). 
38

http://www.census.gov/industry/1/ma325f04.pdf

http://www.census.gov/popest/national/files/NST_EST2005_ALLDATA.csv

Solvent-Based Paint 

Solvent-based paints produced and shipped in the U.S. in 2004, the most recent 

available year, were totaled (includes architectural lacquers and architectural coatings, 

n.s.k.). The resulting number was divided by the 2005 U.S. population to produce a per 

capita solvent-based paint usage factor of 0.5265 gallons per person. 

The resulting solvent paint use, in gallons per county, was multiplied by a VOC emission 

factor of 3.87 lb/gal, from Table 5-2 of the EIIP guidance, Volume III, Area Sources 

Preferred and Alternative Methods, Chapter 3: Architectural Surface Coating. This 

produced total VOC emissions from solvent-based paint. The VOC was then speciated 

for toxics, utilizing speciation factors from Table 5-4 from the EIIP guidance. Acetone, 

listed in the methodology prepared by the Great Lakes states, was removed because it 

is not a toxic. 

Water-Based Paint 

Water-based paints produced and shipped in the U.S. in 2004 were totaled. The 

resulting number was divided by the 2005 U.S. population to produce a per capita 

water-based paint usage factor of 2.2473 gallons per person. 

The resulting water-based paint use in gallons per county was multiplied by a VOC 

emission factor of 0.74 lb/gal, from Table 5-2 from the EIIP guidance, Volume III, Area 

Sources Preferred and Alternative Methods, Chapter 3: Architectural Surface Coating. 

This produced total VOC emissions from water-based paint. The VOC was speciated 

for toxics, utilizing speciation factors from Table 5-3 from the EIIP guidance.

No point source deductions were performed, as none were needed for this category. 

Autobody Refinishing in Michigan, 2005 

Alternate method 3 of the EIIP document, Volume III, Area Sources Preferred and 

Alternative Methods, Chapter 13: Auto Body Refinishing was followed by Michigan. 

National emissions for the category were allocated to the county level based on census 

data. 

79,429.59 tons of VOC were estimated nationally for this category based on 1997, 1998 

and 1999 data, as indicated within the GLC methodology. The estimate of national 

VOC emissions from autobody refinishing was divided by a 2005 national population 

estimate of 296,410,404 to produce a VOC emission factor of 0.54 lbs/person. 
39

Area source estimations were adjusted by deducting point source VOC emissions. 

A seasonal adjustment factor of 1.0 was made for this category for the ozone season. 

The category of auto refinishing was considered to be uniform throughout the year, per 

Table 5.8.1 of the EPA document Procedures for the Preparation of Emission 

Inventories for Carbon Monoxide and Precursors of Ozone, Volume I: General 

Guidance for Stationary Sources. Ozone season daily emissions were calculated per 

the example on page 5-23 of this document. Ozone season throughput was also 

calculated. 5 activity days per week were selected, per Table 5.8.1. Annually, 260 days 

of operation were assumed. NOx and CO emissions were not calculated, as this 

category is not considered a source of NOx or CO. 

References 

1. Emission Inventory Improvement Program, Volume 3, Chapter 13, Auto Body 

Refinishing, January 2000. 

2. Fire 6.23 database 

3. U.S. Census Bureau, Population Division. 2006. Population Estimates Program. 

Washington, DC 20233. 

4. Annual County Business Patterns data are available through U.S. census at: 

 http://www.census.gov/epcd/cbp/view/cbpview.html 

5. Section 3.8 of Procedures for the Preparation of Emission Inventories for Carbon 

Monoxide and Precursors of Ozone, Volume I (1991)

Estimating Emissions from Consumer and Commercial Solvent Use

The GLC methodology, a portion of which is included below, was based on the EIIP 

guidance document, Volume III, Area Sources Preferred and Alternative Methods, 

Chapter 5: Consumer and Commercial Solvent Use. Michigan used the EIIP and GLC 

guidance for the estimation of criteria and toxic pollutants for this category for 2005. 

Michigan chose to use the preferred method with per capita emission factors, adjusted 

for the federal VOC reduction rule as provided in Table 2 of the EIIP guidance. 
40

SCCs

The following SCCs were utilized by Michigan, per LADCO’s recommendations: 

2460100000 personal care 

products 

2460200000 household 

Products 

2460400000 automotive 

aftermarket 

2460600000 adhesives and 

sealants 

2460800000 FIFRA-regulated 

products 

2460500000 coatings and 

related products 

2460900000 miscellaneous 

products 

From GLC methodology: 

Overview

All quotes and information contained within are from the source, Emission Inventory 

Improvement Program, Volume 3, Chapter 5, Consumer and Commercial Solvent Use, 

August 1996. The consumer and commercial solvent source category includes a wide 

array of products including personal care products, household cleaning products and 

household pesticides. However, all VOC emitting products used by businesses, 

institutions and numerous industrial manufacturing operations are also included. A 

detailed list of products included in this category can be found on page 5.2-3 of the 

1996 EIIP document. The majority of VOCs introduced into the atmosphere from this 

category is a result of evaporation of the solvent contained in the product or from the 

propellant released during product use. 

Dry cleaning Area Source Emissions for Michigan, 2005 

Standard Industrial Classification (SIC) 7215 (coin-operated dry cleaning 

establishments) was not considered for this inventory. The AQD’s dry cleaning staff in 

the Technical Programs Unit indicated that virtually all coin-operated dry cleaning 

machines in Michigan have been discontinued due to the large cost of keeping them 

supplied with perchloroethylene (per Elden Dickinson, AQD). SIC 7216 (dry cleaning 

establishments, excluding coin-operated facilities) was considered instead. Under the 

North American Industrial Classification System (NAICS), SIC 7216 is known as NAICS 

812320. 
41

To calculate 2002 VOC emissions, Michigan utilized alternative method two, per 

employee emission factor. 2003 county employment data was obtained from the U.S. 

Census Bureau’s document, 2003 Michigan County Business Patterns. 2005 data was 

not available, and was not expected for some time. 

Dry cleaning has a uniform seasonal adjustment factor (1.0), remaining constant during 

the ozone season, per EPA’s Procedures for the Preparation of Emission Inventories for 

Carbon Monoxide and Precursors of Ozone, Volume I: General Guidance for Stationary 

Sources. 

2003 employment data, the latest from the U.S. Census Bureau’s County Business 

Patterns, was obtained for NAICS 812320, for each county where it was available. 

Where available, employment data for the broader category of NAICS 812 was also 

obtained. 

The next step was to determine a ratio between the number of employees under NAICS 

812320, and the number of employees under NAICS 812. For counties that had 

employment numbers for NAICS 812, this ratio was used to estimate how many of the 

employees would fall under the code 812320. 

The next task was to develop an employment number for those counties where 

drycleaner employment numbers were not available from the County Business Patterns. 

Using population numbers for those counties where employment data was available, a 

per capita number of dry cleaning employees was calculated. As certain counties have 

no perchloroethylene drycleaners (per lists of perc dry cleaners from Randy Johnson, 

AQD), values of zero were entered for those counties. 

Reports from Michigan’s 2005 point source emission inventory (the latest complete 

inventory) were reviewed to determine if any counties had point source employment for 

SIC 7216 (NAICS 812320). Berrien, Ingham and Jackson (NAICS 8123) counties did 

have point sources under SIC 7216, and the number of employees at each source was 

obtained from the emission inventory. Each source’s employment number was 

subtracted from the appropriate county’s employment number. 

Once estimates of employment for SIC 7216 were available for each county, an 

emission factor for VOC of 1,800 lb/yr/employee was obtained from Table 4.5-1 of EIIP 

Vol. III, Chapter 4. 
42

From EIIP 

Subcategory Reactive VOC 

(lb/year/employee

) 

Total Organics 

(lb/year/employee

) 

All solvents (total) 1,800 2,300 

Halogenated Solvents 

 PERC, TCA and CFC 

113 

 Coin Operated 

 Commercial/Industrial 

980 

52 

1,200 

Mineral Spirits and Other 

Unspecified Solvents 

1,800 1,800 

On a per-unit basis: 0.8 tons/facility-year (assumes that average coin-op facility has two 

dry cleaning units and each emits 0.4 tons of PERC per year). 

From AP-42 

 Commercial: 1.3 lb/year/person (all nonmethane VOC) 

 Coin Operated: 0.4 lb/year/person (all nonmethane VOC) 

A rule for perchloroethylene dry cleaning air emissions became effective late 1996 

(58FR49354. National Emission Standards for Hazardous Air Pollutants for Source 

Categories: Perchloro-ethylene Dry Cleaning Facilities. Final Rule. September 22, 

1993.). EPA estimates the rule reduces perchloroethylene emissions from dry cleaning 

operations by 44%. Depending on the methodology used to estimate air emissions 

from perchloroethylene dry cleaning operations the effectiveness of this rule may need 

to be factored into the calculation. 

References: 

U.S. Census Bureau, 2003 Michigan County Business Patterns 

Emission Inventory Improvement Program Vol. III, Area Sources: Preferred and 

Alternative Methods, Chapter 4, Dry cleaning. May 1996. 

Elden Dickinson, Dry Cleaning Unit, Drinking Water and Radiological Protection 

Division, Michigan DEQ. Personal communication, 5/07/01. 

US EPA. Procedures for the Preparation of Emission Inventories for Carbon Monoxide 

and Precursors of Ozone, Volume I: General Guidance for Stationary Sources. May 

1991. EPA –450/4-91-016. 
43

Graphic Arts Criteria and Toxics, 2005 

The EIIP area source guidance document, dated November 18, 1996, was followed. 

The EIIP preferred method was not utilized, as it required a survey of facilities. 

Alternative Method 1, ink sales emission factor method, was found to be not feasible for 

Michigan, as (during calculation of the 1999 inventory) point sources used more ink than 

the state proportion of national ink production was calculated to be. 

Per Alternative Method 2, the population of the inventory region was obtained from state 

data for 2005, and multiplied by the per capita emission factor provided in the EIIP 

guidance. This produced total uncontrolled emissions from all graphic arts facilities with 

less than 100 tons per year of VOC emissions, for the entire state. This method used a 

1991 EPA emission factor of 0.00065 tons VOC per capita. 

Total uncontrolled VOC emissions from area source graphic arts facilities (those with 

less than 100 tons per year of VOC emissions) was then estimated for each county. 

This was done by obtaining uncontrolled VOC emissions from point sources with less 

than 100 tons per year of VOC, from the 2005 EI. SICs 2711, 2721, 2752 and 2754 

(NAICS 51111, 511112, 323114, and 323111) were the SIC codes queried. This 

number was then subtracted from total uncontrolled emissions from graphic arts 

facilities, on a county by county basis. The remaining number is the area source VOC 

emissions per year. 

Solvent Cleaning 2005 (criteria) 

In this category, the use of solvents is broken into two broad classifications. The 

classifications are solvent cleaning (which is composed of cold cleaning and vapor/inline cleaning), and solvent cleanup (predominantly wipe cleaning of external surfaces). 

EIIP Alternative Method 

Solvent Cleaning Equipment (both Cold Cleaners and Vapor/In-line Cleaners):

Emission factors: 

EIIP Table 6.5-2 provides per capita and per employee emission factors, as reproduced 

below. 

Recommended Method for Solvent Cleaning Equipment

Michigan chose to use the per employment factors available in Table 6.5-2 from 

Procedures for the Preparation of Emission Inventories for Carbon Monoxide and 

Precursors of Ozone: Volume I: General Guidance for Stationary Sources (EPA, 1991), 

for the 2005 emissions inventory. Employee data was obtained from the U.S. Bureau 
44

of the Census document, County Business Patterns, Michigan: 2003, which was the 

most recent version at the time the category was estimated. Area source emissions 

were then determined by subtracting point source emissions from total emissions. 

When the result was a negative number, area source emissions were set to zero. 

The following SCCs, per email from Grant Hetherington, WI DNR on 9/19/05, were 

utilized for reporting the emissions to be consistent with the other LADCO states: 

2415360000 - Auto Repair Services (SIC 75): Cold Cleaning 

2415345000 - Miscellaneous Manufacturing (SIC 39): Cold Cleaning 

2415245000 - Miscellaneous Manufacturing (SIC 39): Conveyerized Degreasing 

241523000 - Electronic and Other Elec. (SIC 36): Conveyerized Degreasing 
45

Table 6.5-2: Per Capita and Per Employee Solvent Cleaning Emission Factors 

(EPA, 1991) 

Per Capita 

Factor 

Per Employee 

Factor 

(lb/yr/person) (lb/yr/person) 

Subcategory SIC Codes VOCs Organic

s 

VOCs Organic

s 

Solvent 

cleaning 

25, 33-39, 

417 

4.3 7.2 87 144 

(total) 423, 551, 

552, 

554-556, 

753 

Cold Cleaning 

Automobile 

Repair 

417, 423, 

551, 

2.5 2.5 270 270 

552, 554-

556, 

753 

Manufacturing 25, 33-39 1.1 1.1 24 24 

Vapor and In-Line Cleaning

Electronics and 36 0.21 1.1 29 150 

Electrical 

Other 25, 33-39, 

417, 

0.49 25 9.8 49 

423, 551, 

552, 

554-556, 

753 

2005 point source employment data was obtained from MAERS. These values were 

then deducted from the total emissions estimated by using the per capita emission 

factor and 2005 Michigan county population data. 

References 

EPA. Procedures for the Preparation of Emission Inventories for Carbon Monoxide and 

Precursors of Ozone: Volume I: General Guidance for Stationary Sources (May 1991). 

EPA. STAPPA-ALAPCO-EPA Emission Inventory Improvement Program (EIIP). 

Volume III - Area Sources Preferred and Alternative Methods. Chapter 6, Solvent 

Cleaning. September 1997. 
46

US Department of Commerce, Bureau of the Census. County Business Patterns, 

Michigan: 2003. September 2005. 

Industrial Surface Coatings, Toxics, 2005 

The GLC methodology was followed by Michigan for estimating toxics for 2005. The 

GLC methodology is based on EIIP, Volume III, Area Sources Preferred and Alternative 

Methods, Chapter 8: Industrial Surface Coating. In most cases alternative method one, 

default per employee factors, were used, except for SCCs where the per employeebased emission factors yielded unrealistically high values of pollutants. The MDEQ, Air 

Quality Division staff believe that the point source employee deductions performed for 

each affected SCC (based on NAICS information from U.S. Census Bureau’s County 

Business Patterns, and the Air Quality Division’s point source inventory) do not account 

for all of the point source employees, resulting in the high values. 

For the SCCs 2401050000 (miscellaneous finished metal) and 2401070000 (motor 

vehicles), it was decided that per capita based emission estimates would be utilized 

instead of the per employment based methods which yielded large values of 486 million 

lbs VOC (935 tons per summer weekday) and 57 million lbs VOC, respectively. The per 

capita methods yielded more realistic numbers of 4.6 million and 10.9 million lbs VOC. 

For the SCC 2401020000 (furniture and fixtures), the employment based method 

resulted in an estimate of 31 million lbs (60 tons per summer weekday). The per capita 

method resulted in an estimate of 20 million lbs. As the estimates for 2401020000 

appeared unrealistically large with either method, this category was omitted from the 

inventory. 

Total area source VOC emissions for industrial surface coating for 2005 were 

approximately 50 million lbs. 

From the GLC methodology: 

Source Identification

Searching through the Standard Industrial Classification Code List (SIC), the 

North American Industry Classification System (NAICS), through the Factor 

Information Retrieval System (FIRE 6.23) and table 8.5-1 of the Volume III 

Chapter 8 Industrial Surface Coating September 1997 publication of EPA, the 

following codes were identified for each of the fifteen industrial surface coating 

category. 

Factory Finished Wood - A2401015000

SIC 2426-2429, 243-245, 2492, 2499 

NAICS 321113, 321912, 32192, 321911, 321918, 33711, 321212, 321214, 

321213, 321991, 321992, 33999, 333414, 321999, 321211 
47

Wood Furniture - A2401020000

SIC 25 

NAICS 337122, 337121, 337124, 337214, 33791, 337129, 337125, 337211, 

33636, 339942, 

337127, 337212, 337215, 33792, 

Metal Cans - A2401040000

SIC 3411 

NAICS 332431 

Misc Finished Metals - 240105000

SIC 34xx(exclude 341 and 3498) 

NAICS 332211, 332212, 332213, 332999, 332722, 332117, 332912, 332611, 

332998, 332913, 332439, 33251, 332919, 332312, 322225, 332618, 332321, 

332313, 33242, 332612, 332322, 332311, 339911, 333924, 332114, 332721, 

332994, 334518, 332111, 332112, 33637, 332115, 332116, 332214, 332813, 

339914, 339912, 332812, 332992, 332993, 332995, 332911 

Machinery and Equipment - A2401055000

SIC 35 

NAICS 333611, 333618, 333111, 332323, 333312, 333112, 33312, 333131, 

336311, 333995 

333132, 333921, 333922, 333923, 333924, 333513, 332997, 333514, 333511, 

333515, 333516, 333992, 333518, 333292, 33321, 333291, 333293, 333294, 

33322, 33241, 333295, 333911, 332991, 333912, 333411, 333993, 333612, 

333994, 333613, 314999, 334418, 333996, 333997, 33271, 333999, 334119, 

334518, 333512, 333991, 333412, 336391, 333415, 333913, 

Large Appliances - A240106000

SIC 363 

NAICS 335221, 335222, 335224, 335211, 339999, 333414, 335212, 333298, 

335228, 

Electronic and Other Electrical - 2401065000

SIC 36,123,357 

NAICS 334111, 334112, 334113, 33422, 334418, 334613, 333992, 335129, 

333311, 333313, 339942, 51222, 335311, 335313, 335312, 335991, 335314, 

335999, 33511, 335931, 335932, 335121, 335122, 334613, 336321, 335129, 

33431, 334612, 334419, 335911, 335912, 333319, 

334411, 334412, 334414, 336322, 334415, 334416, 334417, 333618, 33429, 

33421, 

Motor Vehicles - 240107000

SIC 3711 
48

NAICS 33611, 336112, 33612, 336211 

Other Transportation Coatings - 2401075000

SIC 37(not 3711,373) 

NAICS 336213, 336312, 336322, 33633, 33634, 33635, 336399, 336212, 

336415, 336411, 336412, 54171, 332912, 336999, 336413, 333911, 333924, 

33651, 336991, 336414, 336419, 336214, 336992 

Marine Coatings - 240108000

SIC 373 

NAICS 48839, 336611, 336612, 81149 

Misc. Product Coatings Manufacturing - 240109000

SIC

NAICS 339 

Industrial High Performance Maintenance Coatings- 2401100000

SIC

NAICS 811 

Other Special Purpose Coatings - 2401200000 

SIC 

NAICS

VOC factors from Table 8.5-1 of the EIIP guidance were applied to employment 

estimates based on the U.S. Bureau of the Census document, County Business 

Patterns: Michigan, 2003, which was the most recent data available at the time 

the estimates were created. 

References

EPA. STAPPA-ALAPCO-EPA Emission Inventory Improvement Program (EIIP). 

Volume III: Chapter 8 Industrial Surface Coating September 1997. 

U. S. Census web site http://www.census.gov/ 
49

Open Burning: Municipal Solid Waste, 2005 Criteria Pollutants 

For the category of open burning of municipal solid waste (MSW), EPA’s methodology 

from Appendix A of Documentation for the Final 2002 Nonpoint Sector (Feb 06 Version) 

National Emission Inventory for Criteria and Hazardous Air Pollutants was followed. 

The ratio of urban to rural population was obtained from 2000 U.S. Census data, per the 

EPA’s method, then multiplied by a 2005 U.S. Census Bureau estimate of the county 

population in Michigan to obtain an estimate of rural population in 2005. Per capita 

emission factors were used, after first excluding those counties where the population 

was greater than 80% urban under EPA’s presumption that open burning of MSW would 

not occur there. 

Outdoor Wood Boilers, 2005 criteria pollutant estimates 

The Wisconsin methodology distributed by Bart Sponseller was followed. Per that 

methodology, the MARAMA emission factor of 13.82 g/kg wood burned was used. 

An estimate of 11.68 cords/yr/unit in Michigan was obtained from Brian Brady, MDEQ 

Air Quality Division. Brian serves as the MDEQ, Air Quality Division’s outdoor wood 

boiler expert. 

Michigan estimated an average weighted density of 1.65 tons/cord of wood, based on 

information contained within Table 8 of the USDA survey report “Residential Fuelwood 

Consumption and Production in Michigan, 1992.” 

Per the Wisconsin methodology, it was assumed that 90% of outdoor wood boilers are 

used in rural areas and 10% are used in urban areas. To determine which counties 

were urban and which were rural, staff reviewed the list of counties, which are part of 

Michigan’s Consolidated Statistical Areas (metropolitan areas) and determined that the 

22 affected counties should be considered as urban. Ten percent of the 29,568 

Michigan outdoor wood boilers were apportioned to the urban counties by population. 

The remaining 90% of the outdoor wood boilers were apportioned to the 61 rural 

counties by population. 

Residential Wood Burning, 2005

Michigan utilized the EIIP methodology’s alternative method for estimating emissions 

from residential woodburning, by apportioning data from the U.S. Census Bureau and 

the EIA. 

Two options were available to estimate woodburning households per county. 
50

Housing Units with Wood Heat by County was determined by using 1990 U.S. Census 

Data, Database C90STF3C1, Summary Level State, for House Heating Fuel for 

Occupied Housing Units (http://factfinder.census.gov/home/saff/main.html?_lang=en).

• Although this data is for the 1990 year, it did provide a value for each county. 

• Housing Units with Wood Heat by County was determined by using the U.S. 

Census Bureau’s DP-4, Profile of Selected Housing Characteristics: 2000, Data 

Set: Census 2000 Summary File 3 (SF 3) for Michigan. This file provided a total

value of households using wood heating. However, no breakdown was given by 

county. 

The MDEQ, Air Quality Division staff used the 2000 number of total wood burning 

households in Michigan, and used the 1990 county proportions of the 1990 total to 

apportion the 2000 value to the county level. 

Then, based on county value for number of wood burning households, the value for 

state wood use in cords was apportioned to each county. The 2003 state wood use in 

cords data came from the US 
51

MAP States Page, Table 8, Residential Energy Consumption Estimates, Selected Years 

1960-2003, Michigan, from the U.S. Department of Energy, EIA: 

http://www.eia.doe.gov/emeu/states/sep_use/res/use_res_mi.html

Data for 2005 was not yet available. 

Once county wood use in cords was produced, the next step was to determine the wood 

weight in tons for each county. Wood weight was determined by estimating a weighted 

average wood weight of 1.65 tons per cord, from species and consumption data from 

Table 8 of the USDA report, “Residential Fuelwood Consumption and Production in 

Michigan, 1992.” 

Michigan did not have data available on the number of catalytic and non-catalytic 

woodstoves in Michigan, but did utilize 1993 survey data which showed the proportions 

of fireplaces to woodstoves by county in Michigan. This was used to apportion wood 

weight per county between wood stoves and fireplaces. SCCs and emission factors 

were selected for fireplaces – cordwood (2104008001), and woodstoves – general 

(2104008010). 

No ozone season activity was estimated, as staff felt it was unlikely that residents would 

utilize their fireplaces or wood stoves between June 1 and August 31 of each year. 

FIRE 6.23 (Factor Information Retrieval System Version 6.23) and Source Summary 

Database (SSD) list the following Area Mobile Source Codes (AMS): 

 A2104008000: Total wood stoves and fireplaces 

 A2104008001: (lb/ton dry wood burned): Fireplaces - general 

 A2104008010: (mg/Mg dry wood burned): Wood stoves - general 

 A2104008030: (lb/ton dry wood burned): Catalytic wood stoves - general 

 A2104008050: (lb/ton dry wood burned): Non-catalytic wood stoves - general 

 A2104008051: (lb/ton dry wood burned): Non-catalytic wood stoves - 

conventional 

 A2104008052: (lb/ton dry wood burned): Non-catalytic wood stoves - low emitting 

 A2104008053: (lb/ton dry wood burned): Non-catalytic wood stoves - pellet fired 

Michigan selected AMS codes A2104008001 and A2104008010. These were the most 

appropriate codes, as data exists for the proportion of woodstoves to fireplaces per 

county in Michigan, but data was not available on numbers of catalytic or non-catalytic 

wood stoves. Emission factors for A2104008010 were converted from mg/Mg to lb/ton 

by multiplying by the conversion factor of 2.00E-06. 
52

References 

1. USEPA, “Factor Information Retrieval System Version 6.23”, U.S. Environmental 

Protection Agency, 2000. 

2. EPA, STAPPA, ALAPCO, Emission Inventory Improvement Program (EIIP), Volume 

III, July 1997, Chapter 2. 

Structure Fires, 2005 Criteria Emissions 

The EIIP guidance from EIIP Volume III, Chapter 18: Structure Fires, was followed. The 

preferred method for estimating emissions was used, due to the availability of county 

level structure fire data for 2002. More recent data was not available; the fire statistics 

data, which was originally kept by the Michigan State Police Fire Marshall Division, is 

now kept by the Michigan Department of Labor and Economic Growth. DLEG staff 

were unable to locate more recent county level data on structure fires. The 2002 data 

was re-used from the 2002 area source submittal. However, it did not provide any detail 

on the extent of each structure fire, or indicate if the structure was residential or 

commercial. 

The default fuel loading factor provided in the EIIP guidance (1.15 tons of fuel per 

structure fire) was used. Emission factors for VOC, CO, and NOx were obtained from 

Table 18.4-1. 

Year 2009 Stationary Area Source Emission Inventory Projections: 

See Growing Stationary Non-EGU Point, Stationary Area, Locomotive, Shipping, 

and Aircraft Categories for the Years 2009 in the Non-EGU Point Sources section

for reference and methodology for projecting the Stationary Area Source inventory. 

5. Non-Road Mobile 

Non-Road Emissions Estimation exclusive of Locomotive, Shipping, and Aircraft 

Emissions 

Non-road emission estimates for 2005 and 2009 were obtained from the EPA’s National 

Mobile Inventory Model (NMIM). The model uses a database to store the information 

about individual counties, referred to as the NMIM County Database (NCD); the current 

version is NCD20051207. 
53

Recent updates to the model were made by the EPA and can be found at: 

www.epa.gov/omswww/models/nonrdmdl/nonrdmdl2005/readme.htm, (NONROAD2005 Update Chronology). 

One of the updates included in this modeling was a correction in the NON-ROAD.EXE 

file that includes modifications for permeation. Changes were also made in the external 

files (15 files) to incorporate recommendations of SEMCOG and LADCO consultants 

regarding fuel data. Program files for emissions and population data were modified. 

These changes were made to improve the accuracy of the model estimates and to 

produce emission values that will be consistent with those that will be used for future 

ozone and fine particulate SIP demonstrations. 

The Non-road emissions estimates were prepared by Wisconsin for all LADCO States, 

including Michigan. Additional details on the procedures used to prepare these 

inventory products can be found in the “Regional Air Quality Analyses for Ozone, PM2.5, 

and Regional Haze: Technical Support Document” prepared by LADCO. 

2005 Aircraft Emissions Estimation 

In order to estimate aircraft emissions, aircraft activity was obtained for Michigan 

airports. Historically this information was obtained from MDOT. However MDOT was 

unable to provide updated information for year 2005. In the absence of updated MDOT 

2005 aircraft activity data, commercial aircraft and commercial air freight departure 

information by aircraft model type was obtained from FAA airport records. For 

determining airport LTO cycles, the Air Traffic Activity Data System (ATADS) air traffic 

count database of larger towered airports, Terminal Area Forecast (TAF) air traffic 

operations database of towered and non-towered airports, and G.C.R. & Associates 

airport activity data were used. Since ATADS provides aircraft operations for a limited 

number of the States’ airports, TAF aircraft operations estimates were considered 

where ATADS information was unavailable. G.C.R. & Associates, Inc. consultant data 

was used for the smaller airports of which FAA aircraft operations information was 

unavailable. The following information from the respective sources was considered in 

the development of emission estimates: 

 1. Commercial scheduled and non-scheduled aircraft air carrier activity and 

commercial air freight activity by aircraft model types, 

 2. General aviation and air taxi annual local and itinerant operations for year 

2005, 

 3. Military annual local and itinerant operations for year 2005. Due to need 

to have aircraft operations information expressed as LTO cycles, the 

following assumptions were made: 
54

a. For commercial aircraft and commercial air freight activity, the number of 

annual aircraft annual LTO cycles was assumed to be equal to the number 

of departures. The daily LTO cycle frequency was then obtained by 

dividing the yearly LTO cycles by 365. 

b. For general aircraft annual local and itinerant airport operations, each 

respective operations total was divided by two to obtain the corresponding 

year local and itinerant LTO cycles. The expected daily local and itinerant 

LTO cycles then were obtained by dividing these annual totals by 365. 

c. For military annual local and itinerant operations, each respective 

operations total was divided by two to obtain the corresponding year local 

and itinerant LTO cycles. The expected military daily local and itinerant 

LTO cycles then were obtained by dividing these annual totals by 365. 

Airport LTO cycles were further categorized into commercial aircraft by plane and 

engine type, general aviation itinerant aircraft of unknown aircraft type, general aviation 

local aircraft of unknown aircraft type, and military aircraft. This was necessary in order 

to utilize the U.S. Department of Transportation, FAA EDMS 4.5 Emissions and 

Dispersion Modeling System. A description of this model can be found in the FAA 

publication entitled: Emissions and Dispersion Modeling System (EDMS) User Manual 

(September 2004). Commercial and air freight aircraft emission factors per LTO cycle 

were determined using EDMS 4.5 for each commercial aircraft type models where 

possible were used at each towered airport. Default commercial aircraft engine type, 

and EPA default time in mode values for takeoff, approach, and landing roll times were 

used in the EDMS 4.5 model simulations. 

For those aircraft types that could not be determined using the EDMS 4.5 emissions 

model, aircraft emission factors based upon EPA alternative fleet average procedures 

were then used to estimate their emissions. These included general aviation and air 

taxi itinerant aircraft of unknown aircraft type, general aviation local aircraft of unknown 

aircraft type, and military aircraft. Conversion from total hydrocarbons to VOC was 

performed and based upon the EPA guidance. 

Aircraft emissions were then obtained by adding emissions contributions from 

commercial, itinerant general, and local general aircraft, and were reported using the 

following SCC codes. 
55

Michigan Aircraft Emission SCC Codes 

Aircraft Type SCC 

Military 2275001000 

Commercial 2275020000 

General Aviation 2275050000 

2005 Locomotive and Shipping Emissions Estimation 

The 2005 non-road shipping and Locomotive emissions were prepared using the same 

techniques used for the 2002 emissions. These estimates are based on work and a 

follow-up report (Environ Report for LADCO, April 2004, 2002 Shipping Emissions 

Sources) completed by Environ to support LADCO’s efforts to prepare a 2002 Air 

Emissions Inventory. The report describes Environ efforts to develop a shipping 2002 

air emissions estimates to support air quality modeling. The Environ report is too long to 

be included in this document, but it can be provided upon request or downloaded at: 

http://www.ladco.org/reports/rpo/emissions/nonroad_locomotive_commercial_marine_re

creational_marine_final_report_environ.pdf

The estimate of 2005 locomotive and shipping emissions was made by LADCO in the 

same manner as the 2002 inventory described above. The 2005 estimates are part of 

LADCO’s base M inventory. 

Non-Road Mobile Source Emission Inventory Projections to 2009

The non-road source categories exclusive of locomotive, shipping, and aircraft were 

grown in the EPA Mobile source model NMIM. The locomotive, shipping, and aircraft 

non-NMIM source categories were grown using growth factors provided in the report 

(E.H. Pechan & Associates, Inc., Development of Growth and Control Factors for Lake 

Michigan Air Directors Consortium, Final Report, December 14, 2004) done by E.H. 

Pechan & Associates, Inc. for LADCO and available upon request. 

See Growing Stationary Non-EGU Point, Stationary Area, Locomotive, Shipping, 

and Aircraft Categories for the Years 2009 in the Non-EGU Point Sources section

for references and methodology for projecting the Locomotive, Shipping and Aircraft 

emissions inventory. 
56

6. On-Road Mobile

For the 2005 base year, the emissions model CONCEPT was run by a LADCO 

contractor (Environ) using transportation data (e.g., VMT and vehicle speeds) supplied 

by the state (MDOT) and local planning agencies (SEMCOG) in the LADCO States and 

Minnesota for 24 networks. These data were first processed with T3 (Travel Demand 

Modeling [TDM] Transformation Tool) to provide input files for CONCEPT to calculate 

link specific, hourly emission estimates. CONCEPT was run with meteorological data for 

a July and January weekday, Saturday, and Sunday (July 15 – 17 and January 16 – 

18). The six days were used to derive the weekday, Sat, and Sun values for the other 

months, and then (for each month) were multiplied by the number of weekdays, Sat, 

and Sun to get the annual totals. 

Similar to the base year modeling, CONCEPT was run using transportation data (e.g., 

VMT and vehicle speeds) supplied by the state and local planning agencies for 2009 

and 2018. CONCEPT was only run with meteorological data for a weekday. The 

emissions for Saturday and Sunday were derived by using scaling factors based on the 

2005 emissions. 

Additional details on the procedures used to prepare these inventory products can be 

found in the Environ report “LADCO On-Road Emissions Inventory Development Using 

Concept MV” which can be found at 

 

http://www.ladco.org/reports/rpo/emissions/NREL_LADCO_FinalReport09.pdf

 

and “Regional Air Quality Analyses for Ozone, PM2.5, and Regional Haze: Technical 

Support Document” prepared by LADCO. 

7. Area Source Ammonia and Biogenic Emissions

Ammonia Emissions 

LADCO estimated area source ammonia emissions for all member states, including 

Michigan. The CMU-based 2002 (Base K) ammonia emissions were projected to 2005 

using growth factors from the Round 4 emissions modeling. These emissions were then 

adjusted by applying temporal factors by month based on the process-based ammonia 

emissions model. 

Biogenic Emissions 

A LADCO contractor (Alpine) provided an updated version of the CONCEPT/MEGAN4 

(Model of Emissions of Gases and Aerosols from Nature) biogenics model, which was 
57

used to produce 2005 base year biogenic emission estimates. Model improvements 

included: (a) reduced model run times, (b) improved ability to run successive days, and 

(c) enhanced meteorological input processing5. 

Compared to the previous (EMS/BIOME) emissions, there is more regional isoprene 

using MEGAN compared to the BIOME estimates used for Base K. Also, with the 

secondary organic aerosol updates to the CAMx air quality model, Base M includes 

emissions for monoterpenes and sesquiterpenes, which are pre-cursors of secondary 

PM2.5 organic carbon mass. 

Additional details on the procedures used to prepare these inventory products can be 

found in the “Regional Air Quality Analyses for Ozone, PM2.5, and Regional Haze: 

Technical Support Document” prepared by LADCO.