APPENDIX K

Indiana Department of Environmental

Management (IDEM) - Area Source Inventory

Standard Operating Procedure
This page left intentionally blank.
IDEM Area Source Inventory

S-006-0AQ-R-MO-08-S-R1

Standard Operating Procedure

Office: Office of Air Quality

Branch: Air Programs Branch

Section: Technical Support and Modeling Section

Revised: 02/27/2008 Revision Cycle: 2 years

Effective date: 02/15/07

Scope of operations

This SOP is to identify source categories and develop emissions not calculated in point source

inventories. This data is compiled every three years as mandated by EPA.

Scope of applicability

This SOP is for the Senior Environmental Manager and the Environmental Manager in the Emissions

Group.

Authorized Signatures

I approve and authorize this Standard Operating Procedure:

Branch Chief

Scott Deloney

Typed/Printed

Section Chief

Ken Ritter

Typed/Printed

Section QA Contact

Michele Boner

Typed/Printed

Branch QA Coordinator

Chris Pedersen

Typed/Printed

Author

Michele Boner

Typed/Printed

Signature

Signature

Signature

Signature

Signature

Date

Date

Date

Date

Date

This Standard Operating Procedure is consistent with agency requirements.

Indiana Department of Environmental Management

Quality Assurance Program

Planning and Assessment

Date
Table of Contents

Scope of operations 1

Scope of applicability 1

Authorized Signatures 1

1. Overview work flow chart 3

2. Definitions 3

3. Roles 4

Responsibilities: 4

4. Description of equipment, forms, and/or software to be used .4

5. Procedure 4

5.1 Procedural Flowchart 4

5.2 Procedure 5

6. Standards and checklists 24

7. Records Management 24

8. Quality Assurance I Quality Control 24

9. Continuous Improvement Cycle 24

10. References , 24

11. History of Revisions 24

12. Appendices 24

2
1. Overview work flow chart

The process described is not part of a larger system and does not need an Overview work flow chart.

2. Definitions

AP-42 - Compilation of Air Pollutant Emission Factors AP-42, Fifth Edition, Volume I: Stationary Point

and Area Sources (January 1995) plus Supplements A - F (Updates 2001 - 2004). AP-42 can be

obtained at www.epa.gov/ttn/chief/ap421.

Area Sources - A collection of similar emission units within a geographic area that collectively represent

individual sources that are small and numerous and have not been inventoried as a specific point, mobile,

or biogenic source.

Authorized - Established by official authority and usage; as with a policy, standard operating procedure

(SOP), or quality assurance project plan (QAPP) that is signed and dated.

EIIP (Emission Inventory Improvement Program) -The EIIP is an EPA program established in 1993 to

promote the development and use of standard procedures for collecting, calculating, storing, reporting,

and sharing air emissions date.

Emission Factors - An emission factor is the estimate of the quantity of pollutant released to the

atmosphere (because of some operation or activity such as combustion or industrial production) divided

by the level of that activity.

Process - The term "process" used when describing area sources is used to name an operation or

activity that produces emissions.

NEI - National Emission Inventory Air Pollutant Emission Trends, U.S. EPA.

Standard Industrial Classification (SIC) Code - A Standard Industrial Classification code from the

series of codes devised by the United States Office of Management and Budget (OMB) to classify

establishments according to the type of economic activity in which they engage.

Source Classification Code (SCC) - Source Classification Code is a process-level code that describes

the equipment or operation emitting pollutants.

3
3. Roles

Title # of Staff Experience Qualifications Location

MS ACCESS, Emission Air Programs Senior Environmental Manager 1 N/A Inventories and familiarity

with the EIIP Branch

MS ACCESS, Emission Air Programs Environmental Manager 1 N/A Inventories and familiarity Branch with the EIIP

Responsibilities:

Senior Environmental Manager

Oversees work of the Environmental Manager and ensures that all goals are met. The Senior

Environmental Manager also does the final upload to the NEI.

Environmental Manager

The Environmental Manager calculates the Area Source Emissions using the EIIP or other EPA

guidance as provided. The Environmental Manager is also responsible for updating the SOP for

the Emissions Group.

4. Description of equipment, forms, and/or software to be used

Equipment, Fonn, &lor Software Who uses it? Location

Senior Environmental Manager and EPA's website:

AP42 http://www.epa.gov/ttn/chief/ap421index. Environmental Manager html

Emission Inventory Improvement Senior Environmental Manager and EPA's website:

http://www.epa.gov/ttn/chief/eiipltechrep Program (EIIP) Environmental Manager ort!

National Emission Inventory (NEI) Air Senior Environmental Manager and EPA's website

Pollutant Emission Trends, U.S. EPA Environmental Manager http://www.epa.gov/ttn/chiefltrendsl

5. Procedure

5.1 Procedural Flowchart

The procedural flowchart below titled "Area Source Inventory" is used to calculate non-point source

inventories. This data is compiled every three years as mandated by EPA. The guidance followed is

located in the EIIP. Emissions from area sources are calculated at the county level and consist of

individual sources that are small, numerous and that have not been inventoried as specific point, mobile,

or biogenic sources according to the EIIP.

Identify

Categories

Calculate Area Source

.>-_..:.:YE~S'-+I categories using the

EIIP or other EPA

guidance as provided

NO

Then calculate emissions using the SOP for

Receiving Emission Statements or the SOP

for On-Road Mobile Source Invent

Enter data into

NEI

4
5.2 Procedure

Category 1: Stationary Fuel Combustion

Sub-Category 1.1: Industrial Fuel Combustion

SCC: 2102002000,210200400,2102005000, 2102006000,2102007000

Follow these steps when calculating emissions from industrial fuel combustion:

1. Obtain statewide fuel consumption for "Other Industrial" for the following fuels: coal, distillate oil,

natural gas, and liquefied petroleum gas (LPG). Use the Energy Information Administration's website

at http://www.eia.doe.gov/ to find fuel consumption.

Note: As of the date of this SOP, the following steps will lead to data for fuel consumption.

a. Go to http://www.eia.doe.gov/

b. Click on link for the various types of fuel consumption

c. Click on consumption tab for state totals

2. To avoid double calculating the various fuel combustions, subtract reported source totals from the

total statewide fuel consumption by querying the total process rates for the various SCC codes using

the ACCESS data tables at K:\OAQ_INV\SteptooI\StptL02.mdb. The remaining number is the area

source fuel consumption for the state.

3. To distribute the remaining fuel to the county level, calculate the ratio of county to state employment

for the manufacturing sector by diViding the number of Manufacturing Employees for each county by

the number of manufacturing employees statewide. Use the County Business Patterns website at

http://www.census.gov/ to find the number of manufacturing employees for each county.

Note: As of the date of this SOP, the following steps will lead to data for Economic Census.

a. Go to http://www.census.gov/

b. Click on Economic Census

c. Under 2002 Reports by State, use the down arrow key to select Indiana

d. Now, select each of the counties to find the county manufacturing employees

e. Use the total of employees for manufacturing under the paid employees' column

4. Multiply the ratio calculated above in step 3 by the area source fuel consumption to distribute the fuel

to the county level. The remaining number is the process rate for each county. Multiply the process

rate by the appropriate EPA emission factors for the various fuels for industrial manufactUring found

in AP-42, Fifth Edition, Volume 1, Chapter 1, External Combustion Sources at

http://www.epa.gov/ttn/chief/ap42/ch01/.

Sub-Category 1.2: Commercial/Institutional Fuel Combustion

SCC: 2103004000,2103005000, 2103006000, 2103007000

Follow these steps when calculating emissions from commercial/institutional fuel combustion:

1. Obtain statewide fuel consumption for "Commercial" for the following fuels: distillate fuel oil, liquefied

petroleum gas (LPG), natural gas, and residual fuel oil. Use the Energy Information Administration's

website at http://www.eia.doe.gov/ to find fuel consumption.

Note: Use the steps in sub-category 1.1-1 to navigate through the Energy Information

Administration's website.

5
2. To avoid double calculating the various fuel combustions, subtract reported source totals from the

total statewide fuel consumption by querying the total process rates for the various fuels using the

SIC codes greater than 4999 using the ACCESS data tables at K:\OAQ_INV\Steptool\StptL02.mdb.

These are the SIC codes that identify all the commercial/institutional area sources.

3. To distribute the remaining fuel to the county level, calculate the ratio of county to state employment

for the commercial/institutional sector by dividing the number of commercial/institutional employees

for each county by the number of commercial/institutional employees statewide. Use the County

Business Patterns website at http://www.census.gov/ to find the number of commercial/institutional

employees for each county.

Note: Use the steps in sub-category 1.1-3 to navigate through the U.S. Census Bureau's website.

4. Multiply the ratio calculated above in step 3 by the area source fuel consumption to distribute the fuel

to the county level. The remaining number is the process rate for each county. Multiply the process

rate by the appropriate EPA emission factors for the various fuels for commercial/institutional found in

AP-42, Fifth Edition, Volume 1, Chapter 1, External Combustion Sources at

http://www.epa.gov/ttn/chief/ap42/ch01/.

Sub-Category 1.3: Residential Fuel Combustion

SCC: 2104002000,2104004000,2104006000, 2104007000

Follow these steps when calculating emissions from residential fuel combustion:

1. Obtain statewide fuel consumption for "Residential" for the following fuels: coal, distillate oil, natural

gas, and liquid petroleum gas. Use the Energy Information Administration's website at

http://www.eia.doe.gov/ to find fuel consumption.

Note: Use the steps in sub-category 1.1-1 to navigate through the Energy Information

Administration's website.

2. To distribute residential fuel to the county level, calculate the ratio of county fuel usage to statewide

fuel usage using the breakdown of fuels by household per county divided by the breakdown of fuels

by household per state using the U.S. Census Bureau's website at http://www.census.gov/ .

Note: As of the date of this SOP, the following steps will lead to data for breakdown of fuels by

household.

a. Go to http://www.census.gov/

b. On the left hand side click on "American Fact Finder"

c. Using the drop down menu, click on Indiana

d. Scroll to "Housing Characteristics" and select "show more"

e. On the left hand side, select "change geography (state, county, place... )"

f. Using the drop down menu, select county, state, and each county name to obtain housing

information

3. Multiply the ratio calculated above in step 3 by the area residential fuel use by state to distribute the

fuel to the county level. The remaining number is the process rate for each county for the various

fuels. Multiply the process rate by the appropriate EPA emission factors for the various fuels for

residential found in AP-42, Fifth Edition, Volume 1, Chapter 1 External Combustion Sources at

http://www.epa.gov/ttn/chief/ap42/ch01/.

6
Sub-Category 1.4: Residential Heating Using Wood

SCC:2104008001,2104008002,2104008003,2104008004,2104008010,2104008030,2104008050

Follow these steps when calculating emissions from residential heating using wood:

1. Obtain statewide wood consumption for "Residential" using the Energy Information Administration's

website at http://www.eia.doe.gov/. To convert the statewide wood consumption from cords of wood

consumed to tons, mUltiply the total cords consumed by 1.25.

Note: As of the date of this SOP, the following steps will lead to data for wood consumption.

a. Go to http://www.eia.doe.gov/

b. Click on Households, Buildings & Industry

c. Under Consumption Summaries, click on "Annual"

d. Now, over to the right click on "State Energy"

e. Using the drop down menu at the bottom, select "Indiana"

f. Under "Consumption" click on the "Residential" document

2. Using the ratio estimates provided by EPA found in the "Documentation For The Final 2002

NONPOINT SECTOR (FEB 06 version) NATIONAL EMISSIONS INVENTORY FOR CRITERIA AND

HAZARDOUS AIR POLLUTANTS" at

http://www.epa.gov/ttn/chief/net/2002inventory.html#documentaiton the number calculated above in

step 1 is broken out into three categories (fireplace without inserts, fireplaces with inserts and

woodstoves).

3. To distribute to the county level for the three categories above, calculate a ratio of county to state

using the statewide total of households and the county total of households that bum wood found at

the U.S. Census Bureau website http://www.census.gov/. The remaining number is the process rate

for each county. Multiply the process rate by the appropriate EPA emission factors for each of the

categories using the EIIP, Volume 3, Chapter 2, Residential Wood Combustion at

http://www.epa.gov/ttn/chief/eiip/techreportlvolume03/iii02 apr2001.pdf.

Note: Use the steps in sub-category 1.3-2 to navigate through the Energy Information

Administration's website.

Category 2: Industrial Processes

Sub-Category 2.1:

SCC: 2302050000

Bakeries

Follow these steps when calculating emissions from bakeries:

1. Calculate a per capita consumption factor using the reported weight of yeast-raised product reported

under the Bread, Cake, and Frozen Bakery Products from the Economic Census Bureau at

http://www.census.gov/econ/census02/ and the U.S. population at the U.S. Census Bureau at

http://census,gov/.

Note: As of the date of this SOP, the following steps will lead to data for yeast-raised product.

a. Go to http://www.census.gov

b. Under Business & Industry open "Economic Census"

c. Now open "Subject Series"

d. Under Manufacturing, open the table "Product Summary"

e. Use the yeast - raised product under Commercial Bakeries (NAICS code 311812) and Frozen cakes,

pies, and other pastries manufacturing (NAICS code 311813)

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2. Multiply the per capita consumption factor calculated above in step 1 by the Indiana population found

at the U.S. Census Bureau at http://www.census.gov.

Note: As of the date of this SOP, the following steps will lead to Indiana population data.

a. Go to http://www.census.gov

b. Under Population Finder, use the drop down menu to select Indiana

3. To avoid double calculating the amount consumed for the state, subtract the reported process rate for

both the straight-dough and sponge-dough by querying the total process rates for the SCC 30203202

(straight-dough) and SCC 30203201 (sponge-dough) using the ACCESS data tables at

K:\OAQ_INV\Steptool\StptL02.mdb.

4. Multiply the remaining process rate by the straight-dough emission factor of .5 Ibs VOC/1,OOO pounds

baked found in the EIIP, Volume 3, Area Source Method Abstracts: Baked Goods at Commercial/Retail

Bakeries at http://www.epa.gov/ttn/chief/eiip/techreport/volume03/index.html.

5. Calculate a per capita factor by dividing the Indiana population found in step 2 by the remaining process

rate. Now multiply the per capita factor by each of the county populations to calculate the VOC emissions

for each county.

Note: As of the date of this SOP, the following steps will lead to county population data.

a. Go to http://www.census.gov

b. Under Population Finder, use the drop down menu to select Indiana

c. Under "View more results", select the county table

Category 3: Solvent Utilization

Sub-Category 3.1: Architectural Coatings

SCC: 2401001000

Follow these steps when calculating emissions from architectural coatings:

1. Calculate an emission factor for architectural coating area sources first by adding all the solventbased paints together and all the water based paints together using the U.S. Census Bureau's

website http://www.census.gov. Use Table 1 to select all solvent-based paints and Table 2 to select

all water based paints.

Table 1

Nt' alonalSIoventCoat'InQ SIaes

Solvent Type 1,000 gallons

Exterior Solvent Type XX

Interior Solvent Type XX

Architectural Lacauers XX

Architectural Coating

N.S.K. XX

Total Solvents XX

Table 2

N' atlonaIWater B C S I ased oatlnO aes

Water Type 1,000 gallons

Exterior Water Type XX

Interior Water Type XX

Total Water Type XX

Note: As of the date of thiS SOP, the following steps will lead to architectural coating data.

8
a. Go to http://www.census.gov

b. Under Business & Industry, select more

c. Now select Current Industrial Reports (CIR)

d. Select CIRs by Subject

e. Tab down to find the report "Paints and Allied Products"

2. Now mUltiply the total national number for solvent-based paints by the average solvent-based coating

content number (3.87 Ibs VaC/gallon) and the total national number for water-based paints by the

average water-based coating content number (0.74 Ibs VaC/gal) found in the EIIP. Volume 3,

Chapter 3: Architectural Surface Coating at

http://www.epa.gov/ttn/chief/eiip/techreportlvolume03/archsfc.pdf.

3. Add the total solvent-based coatings and the water-based paints together for a total national vac

emission factor from architectural surface coating. Then divide this number by the total national

population using the U.S. Census Bureau's website http://www.census.gov.

4. Multiply the number calculated above in step 3 by each of the county populations to calculate the total

emissions per county.

Note: Use the steps in sub-category 2.1-5 to navigate through the Census Bureau's website.

Sub-eategory 3.2:

SCC: 2401005000

Automobile Refinishing

Follow these steps when calculating emissions from automobile refinishing:

1. To avoid double calculating, first query the employees from the reported sources using the SIC 7532-

Body Repair and Paint Shops using the ACCESS data tables at K:\aAQ_INV\Steptool\StptL02.mdb.

Subtract this number from the county employment for the same SIC using the U.S. Census Bureau's

website http://www.census.gov.

Note: As of the date of this sap, the following steps will lead to county employment data.

a. Go to http://www.census.gov

b. Under Business & Industry, select more

c. Now select the County Business Patterns report for county

d. Select Indiana

e. Select each of the counties to find the number of employees for the corresponding SIC or NAICS

code

2. MUltiply the emission factor 3,5191bs VaC/employee found in the EIIP. Volume 3, Chapter 13 Auto

Body Refinishing at http://www.epa.gov/ttn/chief/eiip/techreportlvolume03/archsfc.pdf and the county

employment found above in step 1 to calculate the vac emissions for each county.

Sub-Category 3.3:

SCC: 2401008000

Traffic Markings

Follow these steps when calculating for traffic markings:

1. First calculate the national emissions by finding the amount of sales for traffic marking paints from the

U.S. Census Bureau's website http://www.census.gov and mUltiply 3.361b VaC/gallon the national

average vac content for water and solvent-based paints from the EIIP, Volume 3, Chapter 14, Traffic

Markings at http://www.epa.gov/ttn/chief/eiip/techreportlvolume03/iii14.pdf.

Note: As of the date of this sap. the following steps will lead to traffic marking paints.

9
a. Go to http://www.census.gov

b. Under Business & Industry, select more

c. Now select Current Industrial Reports (CIR)

d. Select CIRs by Subject

e. Tab down to find the report "Paints and Allied Products"

f. Use the quantity amount in 1000/gallons under ''Traffic marking paints (all types: shelf goods and

highway department)

2. Allocate the national emissions calculated above in step 1 to the state level by dividing the amount of

money spent in Indiana by the money spent nationally on highway maintenance using the category "Total

Disbursements" at the Federal Highway Administration's website

http://www.fhwa.dot.gov/policy/ohim/hs04/htm/sf2.htm.

3. Calculate the emission factor for Indiana by dividing the state level emissions by the total number of

roadway miles in Indiana, given by contacting the Program Development Division, Highway Statistics,

Indiana Department of Transportation or the Office of Air Quality, Technical Support and Modeling

Section's mobile inventory preparer.

4. MUltiply the emission factor by the total number of roadway miles in each county using the information

supplied from above in step 3.

Sub-Category 3.4: Industrial Surface Coating (employment based emission factor)

SCC:2401015000,2401020000,2401030000,2401040000,2401045000,2401055000,2401060000,

2401065000,2401070000,2401075000,2401080000

Follow these steps when calculating for industrial surface coating using the employment based

emission factor:

1. Calculate an employee based emission factor for the following SIC's in the table below running a query

to find the point source employment for each of the SIC's and the reported VOC emissions for each

uSing the ACCESS data tables at K:\OAQ_INV\Steptool\StptL02.mdb.

SCC Description SIC's

2401015000 Factory Finished Wood 2426-2429,243-245, 2492, 2499

2401020000 Wood Furniture 25

2401030000 Paper Coating 26

2401040000 Metal Cans * 341

2401045000 Metal Coils * 3479

2401055000 Machinery and Equipment 35

2401060000 Appliances * 363

2401065000 Electronic and Other Electrical 3612,3357

2401070000 New Motor Vehicles ** 3711

2401075000 Other Transportation 37 (not 3711, 373)

2401080000 Marine Coatings 373

* Use the National default emission factor because the reporting sources are low.

** Emissions reported in point source

10
2. Divide the reported vec emissions for each of the SIC's by the reported employment for each SIC.

Use this number for the emission factor.

3. Subtract the number of reported employees found in step 1 from each of the SIC county totals using

the U.S. Census Bureau's website http://www.census.gov. Use the remaining number for the process

rate for each of the counties.

Note: Use the steps in sub-category 3.2-1 to navigate through the County Business Patterns.

4. Multiply the process rates above found for each of the SIC's in step 4 by the emission factors found in

step 3 to allocate the emissions to each of the counties.

Sub-Category 3.5: Industrial Surface Coating (default emission factor)

SCC:2401090000,2401100000,2401200000

Follow these steps when calculating emissions from industrial surface coating using the default emission

factor:

1. Calculate industrial surface coating emissions using the default emission factor in the EIIP, Volume 3, Chapter

8, Industrial Surface Coating at http://www.epa.gov/ttn/chief/eiip/techreporUvolume03/iii08.pdf and multiply by

the county populations found at the U.S. Census Bureau's website http://www.census.gov.

Note: Use the steps in 2.1-5 to navigate through U.S. Census Bureau's website.

SCC's Description Default Emission Factor

24-01-090-000 Miscellaneous Manufacturing 0.600 Ibs VaC/person

24-01-100-000 Industrial Maintenance Coatings 0.800 Ibs VaC/person

24-01-200-000 ather Special Purpose Coatings 0.800 Ibs VaC/person

Sub-Category 3.6: Degreasing

SCC: 2415230000,2415245000,2415345000, 2415360000

Follow these steps when calculating emissions from degreasing activities:

1. Use the U.S. Census Bureau to find employment numbers for each of the counties for the categories

in Table 1 below at http://www.census.gov.

11
Note: Use the steps in 2.1-5 to navigate through U.S. Census Bureau's website.

Source Classification Codes and Industries Associated with Degreasing

SCC SIC Description

2415230000 36 Electronic and other electronic equipment

25 Furniture and fixtures

33 Primary metal industries

34 Fabricated metal products

35 Industrial machinerv and eauioment

37 Transportation eauioment

38 Instruments and related oroducts

39 Miscellaneous manufacturina industries

2415245000 417 Bus Terminal and Service Facilities

423 Truckina terminal facilities

551 New and used car dealers

552 Used car dealers

554 Gasoline service stations

555 Boat dealers

556 Recreational vehicle dealers

753 Automotive repair shops

25 Furniture and fixtures

33 Primarv metal industries

2415345000 34 Fabricated metal products

35 Industrial machinery and equipment

36 Electronic and other electronic equipment

37 Transportation eauipment

2415345000 cont. 38 Instruments and related products

39 Miscellaneous manufacturing industries

417 Bus Terminal and Service Facilities

423 Trucking terminal facilities

551 New and used car dealers

2415360000 552 Used car dealers

554 Gasoline service stations

555 Boat dealers

556 Recreational vehicle dealers

753 Automotive repair shops

2. Run a query to find reported employment numbers for each of the categories in the table above using

the ACCESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb.

3. Subtract the reported employment from the U.S Census Bureau's numbers to find the process rates

for each of the counties.

4 Calculate the VOC emissions by multiplying the default emission factor in the EIIP, Volume 3, Chapter 6,

Solvent Cleaning at http://www.epa.gov/ttn/chief/eiip/techreporVvolume03/iii06fin.pdf and the process rate

for each of the counties found in step 3.

Sub-Category 3.7:

SCC: 2420010370

Dry Cleaners

Follow these steps when calculating emissions from dry cleaners:

1. Calculate an emission factor by finding the number of employees state wide and county wide for SIC

7216(Laundry and Garment Services) at the U.S. Census Bureau's website http://www.census.gov.

Note: Use the steps in 2.1-5 to navigate through U.S. Census Bureau's website

2. Take the sum of the employment from the counties, multiply by 2000, and divide by the statewide

total found in step 1. Use this number for the emission factor.

12
3. Calculate the process rate by running a query to find the number of reported employees for SIC 7216

using the ACCESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb and subtract this number from

the county total.

4. Multiply the process rate for each of the counties above by the emission factor to calculate for VOC

emissions.

Sub-Category 3.8:

SCC: 2425000000

Graphic Arts

Follow these steps when calculating emissions from graphic arts activities:

1. Multiply the per capita factor found in the EIIP, Volume 3, Chapter 7, Graphic Arts at

http://www.epa.gov/ttn/chief/eiip/techreporUvolume03/iii07.pdf by the state population from the

Census Bureau http://www.census.gov to find the total emissions for the state.

Note: Use the steps in 2.1-2 to navigate through the U.S. Census Bureau's website.

2. Develop an emission factor by subtracting point source emissions from the total emissions and

dividing by the state popUlation found in step 1.

3. Distribute to the counties by multiplying the emission factor by the population for each county.

Note: Use the steps in 2.1-5 to navigate through the U.S. Census Bureau's website.

Sub-Category 3.9:

SCC: 2430000000

Rubber and Plastics

Follow these steps when calculating emissions from rubber and plastics activities:

1. Run a query to find the total of reported emissions and number of reported employees for all SIC's

beginning with 30 using the ACCESS data tables at K:\OAQ_INV\Steptool\Stptl_02.mdb.

2. Calculate the emission factor by dividing the point source emissions by the reported employees.

3. Subtract the reported employment for SIC's beginning with 30 from total employment for each of the

counties.

Note: Use step 3.2-1 to navigate through the County Business Patterns.

4. Multiply the remaining number from above with the emission factor calculated in step 2.

Sub-Category 3.10: Miscellaneous Industrial Adhesives

SCC: 2440020000

Follow these steps when calculating emissions from industrial adhesives activities:

1. Using the guidance in the Air Pollutant Emission Trends at http://www.epa.gov/ttn/chief/trends,

calculate an emission factor by finding the total National Emissions from Industrial Adhesives and

divide by the National Manufacturing Employment from the U.S. Census Bureau's website

http://www.census.gov.

13
Note: As of the date of this SOP, the following steps will lead to emission trends data for industrial

adhesives.

a. Go to http://www.epa.gov/air/airtrends/agtrnd03/

b. Select "Appendix A -Data Tables"

c. Search for industrial adhesives

Note: As of the date of this SOP, the following steps will lead to National Manufacturing Employment.

a. Go to http://www.census.gov

b. Select Economic Census

c. Now select "Businesses with paid employees"

d. Use the manufacturing number under "paid employees"

2. To avoid double calculating, run a query collecting sources reporting adhesives using the ACCESS

data tables at K:\OAQJNV\Steptool\StptL02.mdb. Subtract the reported employment from the total

amount of manufacturing employment. The remaining number is the process rate.

Sub-Category 3.11: Commercial/Consumer Solvents

SCC:2460100000,2460200000,2460400000,2460500000,2460600000,2460800000,2460900000

Follow these steps when calculating emissions from commercial/consumer solvent usage:

1. Using the EIIP, Volume 3, Chapter 5, Consumer, and Commercial Solvent Use at

http://www.epa.gov/ttn/chief/eiip/techreporUvolume03/iii05.pdf, multiply the per capita factors for each of

SCC codes by the population for each county from the U.S. Census Bureau's website

http://www.census.gov.

Note: Use the steps in 2.1-5 to navigate through the U.S. Census Bureau's website.

Emission Factors for Commercial/Consumer Solvents

Source Classification Codes Product Category Per Capita Emission Factor

(Ib VQC/person)

2460100000 Personal Care Products 2.32

2460200000 Household Products 0.79

2460400000 Automotive Aftermarket Products 1.36

2460500000 Coatings and Related Products 0.95

2460600000 Adhesives and Sealants 0.57

2460800000 FIFRA-Regulated Products 1.78

2460900000 Miscellaneous Products 0.07

Sub-Category 3.12: Asphalt Emulsions

SCC: 2461022000

Follow these steps when calculating emissions from asphalt emulsions:

1. To calculate the process rate, find the number of barrels of asphalt used for the state found at the

State Energy Data website at http://www.eia.doe.gov/emeu/states/sedsupdates.html.

14
2. Obtain the amount of roadway miles for the state and county from the Indiana Department of

Transportation's, Division of Roadway Management Section.

3. Divide the county roadway miles by the state roadway miles and multiply by the total asphalt usage for

the state found above in step 1.

4. Multiply the process rate by the default emission factor in the EIIP, Volume 3, Chapter 17, Asphalt

Paving http://www.epa.gov/ttn/chief/eiip/techreporVvolume03/iii17 apr2001.pdf.

SUb-Category 3.13: Pesticide Usage

SCC: 2461800000

Follow these steps when calculating emissions from pesticide usage:

1. Calculate pesticide usage by using a state specific emission factor. Develop the factor using a

methodology that includes the retrieval of information of pesticides used, an emission factor for each

pesticide used, a calculation about the inert ingredients in each pesticide, and an estimate of the

amount of crop oil concentrate (an adjuvant used for the application of herbicides) used in the state of

Indiana.

2. Find the amount of active ingredients for herbicides and insecticides applied to Indiana fields at the

Indiana Agricultural Statistics Service at http://www.usda.gov/nass/pubs/agr02Iacro02.htm.

3. Insert the numbers for both corn and soybeans to the Excel pesticide table found at K:OAQ_INV\lnv\pesticide.

4. Calculate the emission factor by adding the emissions from crop oil concentrates obtained in the

pesticide Excel table, pesticides, and solvent carriers and then divide by the total number of acres of

corn and soybeans in Indiana found at the National Agricultural Statistics Services, United States

Department of Agriculture http://www.nass.usda.gov/QuickStats/.

5. Multiply the emission factor by the county-specific acreage for both corn and soybeans found at the

National Agricultural Statistics Services, United States Department of Agriculture

http://www.nass.usda.gov/QuickStats/.

Category 4: Petroleum Marketing

Follow these steps when calculating emissions for bulk terminals:

Sub-Category 4.1 :

SCC: 2501050120

Bulk Terminals

1. Find the amount of gasoline sold in Indiana at the Federal Highway Administration, U.S. Department

of Transportation http://www.fhwa.dot.gov/policy/ohim/hs04/htm/mf21.htm.

2. Find the amount of gasoline sold statewide and by county using, the NAICS code 447-Gasoline

Service Station from the U.S. Census Bureau's, Economic Census at

http://www.census.gov/econ/census02/datalin/IN00044.HTM#N447.

3. Run a query to find the amount of point source reported gasoline using the ACCESS data tables at

K:\OAQ_INV\Steptool\StptL02.mdb and subtract from the amount sold statewide. Use this to

allocate to each county.

4. Allocate the amount gasoline sold to each of the counties by dividing the amount of sales in each

county by statewide sales and multiplying by the number of gallons sold statewide found above in

step 1.

15
5. EPA guidance suggests that only 25% of all gasoline consumed goes through bulk plants. To

calculate process rate, mUltiply each county by 25% to estimate the amount of fuel transferred

through bulk terminals.

6. Multiply process rate by the emission factors in the table below:

Emission Factors

Source Emission Factor

(Ib VOC/1000) gal

Storage Tanks Breathing Loss 5.0

Storage Tank Working Loss - Filling 9.6

Storage Tank Working Loss - Emptying 3.8

Gasoline Loading Racks 11.9

(Vapor balance controlled) (0.3)

Total 30.3

7. Bulk terminals also have controls set forth in the Indiana rule (326 lAC 8-4). This rule says that any

source of this type that is new after January 1, 1980 is required to make sure that any transfer

between a tank and transport uses a submerged pipe vapor balance system. Using EPA's default

rule effectiveness, multiply the number in step 2 by the Control Efficiency (CE) 38%, a Rule

Effectiveness (RE) of 80%, and a Rule Penetration (RP) of 13%, Le. process rate X emission factor X

(1-(CE x RE x RP)) X 1 ton/2000 Ib = VOC tons.

Sub-Category 4.2: Portable Fuel Containers

SCC: 2501011011,2501011012,2501011016, 2501012011,250101 2012,2501012016

Follow these steps when calculating emissions for portable fuel containers:

1. Calculate the emissions for Commercial and Residential gas cans by using the method developed by

the California Environmental Protection Agency's document Public Meeting to Consider Approval of

California's Portable Gasoline-Container Emissions Inventory. Use the excel spreadsheet found at

K:\OAQ_INV\lnv\Area Source\Gasoline.zip to calculate the emissions for permeation, diurnal, and

transport. Both the Spillage and Vapor losses are estimated in the nonroad emissions inventory by

EPA models.

2. Using the survey results below in Table 1, estimate the number of fuel containers in the state for

residential categories. The calculations are set up in an excel spreadsheet at K:\OAQ_INV\lnv\Area

Source\ Gasoline.zip\2501 01\GasCans.xls, insert the number of occupied housing, from the U.S.

Census Bureau's website at http://www.census.gov/, in the space marked "households".

Note: As of the data of this SOP, the following steps will lead to number of households in Indiana.

a. Go to http://www.census.gov/

b. On the left hand side select American Fact finder

c. Now select housing

d. Under "Occupancy Status", select occupies housing units

e. Now use the drop down menu and select Indiana

16
Table 1

Residential Survey Results

Percentage of households with at least one gas can 46%

Number of gas cans per household 1.8

Percentage of plastic cans/metal cans 76%/24%

Weighted average gas can capacity (gal) 2.34

Percentage of gas cans stored with fuel 70%

Weighted average stored fuel volume (% of capacity) 49%

Percentage of all gas cans that are plastic and stored open/dosed 23%/53%

Percentage of all gas cans that are metal and stored open/dosed 11% /13%

Percent of all cans stored open/dosed 34%/66%

3. Using the survey results below in Table 2, estimate the number of fuel containers for commercial

categories for the state. Do this by using the commercial population based on the number of identified

businesses in Table 3 and insert into the excel spreadsheet at K:\OAQ_INV\lnv\Area Source\

Gasoline.zip\2501 01 \GasCans.xls.

Table 2

Commercial Survey Results

Percentage of businesses with at least one gas can 80%

Number of gas cans per business 6.9

Percentage of plastic cans/metal cans 72%/28%

Weighted average gas can capacity (gal) 3.43

Weighted average stored fuel volume (% of capacity) 49%

Percentage of all gas cans that are plastic and stored open/closed 39%/33%

Percentage of all gas cans that are metal and stored open/dosed 10% /18%

Percent of all cans stored open/dosed 49%/51%

Table 3

Category NAICS

Agricultural 115

Automotive Club and Towing Services 48841

Service Stations 8111

Lawn and Garden Maintenance Services 81141

General Contractors 23

Construction and Rental Yards 5324

Landscaping Services 561730

4. Calculate permeable emissions separately for both residential and commercial by using the emission

rates given in the California document. Use 1.57g/gallday for plastic containers and 0.6g/gal/day for

metal containers. Insert the numbers for both residential and commercial into the excel spreadsheet at

K:\OAQ_INV\lnv\Area Source\ Gasoline.zip\2501 01 \GasCans.xls.

5. Calculate diurnal emissions by inserting the numbers for both residential and commercial into the

excel spreadsheet at K:\OAQ_INV\lnv\Area Source\ Gasoline.zip\250101\GasCans.xls.

6. Calculate transport spillage emissions by inserting the numbers for both residential and commercial into the

excel spreadsheet at K:\OAQ_INV\lnv\Area Source\ Gasoline.zip\250101\GasCans.xls

17
Sub-Category 4.3: Service Station Tank Loading or Tank Truck Unloading (Stage 1)

SCC: 2501060052 (uncontrolled), 2501060053 (controlled)

Follow these steps when calculating emissions from tank loading and unloading

1. Find the amount of gasoline sold in Indiana at the Federal Highway Administration, U.S. Department of

Transportation http://www.fhwa.dot.gov/policy/ohim/hs04/htm/mf21.htm.

2. Find the amount of gasoline sold statewide and county wide by using the NAICS code 447-Gasoline

Service Station from the U.S. Census Bureau's, Economic Census at

http://www.census.gov/econ/census02/dataiin/IN00044.HTM#N447.

3. Run a query to find the amount of point source reported gasoline using the ACCESS data tables at

K:\OAQ_INV\Steptool\StptL02.mdb and subtract from the amount sold statewide. Use this to

allocate to each county.

4. Allocate the amount sold to each of the counties by dividing the amount of sales in each county by

statewide sales and multiplying by the number of gallons sold statewide found above in step 1.

5. Find the amount of gasoline tanks from the Underground Storage Tank data files from the Office of

Land Quality, Indiana Department of Environmental Management

http://www.in.gov/idem/programslland/ust/ust.html.

6. Now copy the data into an Excel spreadsheet. Filter finding the tanks that have only gasoline. Also

filter out the tanks that are "permanently out of service", "suspended per inspection", and

"unregulated".

7. Using the Petroleum Sources Applicability Rule 326 lAC 8-4-1, filter out the tanks that are located in

Clark, Boone, Dearborn, Elkhart, Floyd, Hamilton, Hancock, Harrison, Hendricks, Johnson, Lake,

Marion, Morgan, Porter, Saint Joseph, and Shelby counties.

8. To find the amount of balanced tanks in Indiana, use the total of gasoline tanks found in step 7 and

divide by the number of tanks that constructed after 1985 through current year. Use the spreadsheet

created in step 7 and filter out the tanks that constructed prior to 1985.

9. Now apply the percentage found in step 8 to the amount of gasoline found in each county.

10. Apply the controlled emission factor to only those counties identified in 326 lAC 8-4, Le. Boone, Clark,

Dearborn, Elkhart, Hamilton, Hancock, Harrison, Hendricks, Johnson, Lake, Marion, Morgan, Porter,

Saint Joseph, and Shelby. Use the emission factors for stage 1 controlled and uncontrolled in the

EIIP, Volume 3, Chapter ii, Gasoline Marketing (Stage 1 and Stage 2)

http://www.epa.gov/ttn/chief/eiip/techreport/volume03/iii11 apr2001.pdf.

Sub-Category 4.4: Vehicle Fueling (Stage II) - Vapor Displacement

SCC: 2501060101 (uncontrolled), 2501060102 (controlled)

Follow these steps when calculating emissions from vehicle fueling - Vapor Displacement:

1. Find the amount of gasoline sold in Indiana at the Federal Highway Administration, U.S. Department

of Transportation http://www.fhwa.dot.gov/policy/ohim/hs04/htm/mf21.htm.

2. Find the amount of gasoline sold statewide and by county using the NAICS code 447-Gasoline

Service Station from the U.S. Census Bureau's, Economic Census at

http://www.census.gov/econ/census02/data/in/IN00044.HTM#N447.

18
3. Allocate the amount sold to each of the counties by dividing the amount of sales in each county by

statewide sales and multiplying by the number of gallons sold statewide found above in step 1.

4. Calculate an emission factor using the input files supplied from the mobile model. Table 1 and Table

2 show examples of how the emission factors for January and July for the Southern Counties were

calculated. By using these two months, the other months are distributed. Use the average of all

months for the emission factor for the Southern counties. Use the same methodology for the

Northern counties, Central Counties, Clark/Floyd, and Lake/Porter.

Table 1

January Run for Southern Counties

VTYPE GM_MILE MILES MPG VMT G/GAL Month Factor

1 0.0628 29.4642 23.89 0.463793 0.322719 1 1.01

2 0.1058 35.2923 18.77 0.070491 0.009868 2 1.14

3 0.1058 35.2923 18.77 0.234672 0.109364 3 1.28

4 0.1486 34.0851 14.31 0.071379 0.010834 4 1.41

5 0.1486 34.0851 14.31 0.032825 0.002291 5 1.55

6 0.2152 35.8919 9.88 0.028896 0.001775 6 1.69

7 0.2342 32.3617 9.08 0.001027 2.24E-06 7 1.82

8 0.2465 19.9098 8.63 0.000522 5.8E-07 8 1.69

9 0.2719 27.6093 7.82 0.001164 2.88E-06 9 1.55

10 0.2733 27.4686 7.78 0.002489 1.32E-05 10 1.41

11 0.2972 24.3758 7.15 0.001132 2.72E-Q6 11 1.28

12 0.3169 23.6257 6.71 0.000004 3.4E-11 12 1.14

25 0.3421 27.2301 6.22 0.000496 5.23E-Q7 Sum 16.97

0.456873 glgal Average 1.41

1.007222 Ib/E3gai

VTYPE

1

2

3

4

5

6

7

8

9

10

11

12

25

Table 2

July Run for Southern Counties

GM_MILE MILES MPG VMT G/GAL

0.1144 29.1752 23.9 0.456768 0.570447

0.1955 34.8826 18.75 0.071404 0.018689

0.1955 34.8826 18.75 0.237712 0.207133

0.2882 33.944 14.3 0.072838 0.021865

0.2882 33.944 14.3 0.033496 0.004624

0.4164 35.8288 9.9 0.029201 0.003515

0.4529 32.4716 9.1 0.001038 4.44E-06

0.4763 19.6757 8.66 0.000509 1.07E-06

0.5264 27.4602 7.83 0.00116 5.55E-06

0.5283 27.3328 7.8 0.002482 2.54E-05

0.5749 24.2458 7.17 0.001122 5.19E-06

0.6128 23.3718 6.73 0.000004 6.6E-11

0.6629 27.2301 6.22 0.000485 9.7E-07

0.826316 glgal

1.821697 Ib/E3gai

5. Multiply the process rate in step 4 by the emission factor found in the mobile model.

19
Sub-Category 4.5:

SCC: 2501060103

Vehicle Fueling (Stage II) - Spillage

Follow these steps when calculating emissions from vehicle fueling - Spillage:

1. Find the amount of gasoline sold in Indiana at the Federal Highway Administration, U.S. Department

of Transportation http://www.fhwa.dot.gov/policy/ohim/hs04/htm/mf21.htm.

2. Find the amount of gasoline sold statewide and by county using the NAICS code 447-Gasoline

Service Station from the U.S. Census Bureau's, Economic Census at

http://www.census.gov/econ/census02/data/in/IN00044.HTM#N447.

3. Allocate the amount sold to each of the counties by dividing the amount of sales in each county by

statewide sales and multiplying by the number of gallons sold statewide found above in step 1.

4. Apply the emission factor 0.7 Ib VOC/1000 gallons in AP-42, Fifth Edition, Volume 1, Chapter 5,

Petroleum Industry, Transportation, and Marketing of Petroleum Liquids

http://www.epa.gov/ttn/chief/ap42/ch05/final/c05s02.pdfto the process rate found in step 4.

Sub-Category 4.6:

SCC: 2501060200

Underground Tank Breathing

Follow these steps when calculating emissions from underground tank breathing:

1. Find the amount of gasoline sold in Indiana at the Federal Highway Administration, U.S. Department

of Transportation http://www.fhwa.dot.gov/policy/ohim/hs04/htm/mf21.htm.

2. Find the amount of gasoline sold statewide and by county using the NAICS code 447-Gasoline

Service Station from the U.S. Census Bureau's, Economic Census at

http://www.census.gov/econ/census02/datalin/IN00044.HTM#N447.

3. Allocate the amount sold to each of the counties by dividing the amount of sales in each county by

statewide sales and multiplying by the number of gallons sold statewide found above in step 1.

4. Apply the emission factor 1.0 Ib VOC/1 000 gallons in AP-42, Fifth Edition, Volume 1, Chapter 5,

Petroleum Industry, Transportation, and Marketing of Petroleum Liquids

http://www.epa.gov/ttn/chief/ap42/ch05/final/c05s02.pdf to the process rate found in step 4.

Sub-Category 4.7:

SCC: 2505030120

Tank Trucks in Transit

Follow these steps when calculating emissions from tank trucks in transit:

1. Find the amount of gasoline sold in Indiana at the Federal Highway Administration, U.S. Department

of Transportation http://www.fhwa.dot.gov/policy/ohim/hs04/htm/mf21.htm.

2. Find the amount of gasoline sold statewide and by county using the NAICS code 447-Gasoline

Service Station from the U.S. Census Bureau's, Economic Census at

http://www.census.gov/econ/census02/datalin/IN00044.HTM#N447.

3. Allocate the amount sold to each of the counties by dividing the amount of sales in each county by

statewide sales and mUltiplying by the number of gallons sold statewide found above in step 1.

20
4. Using the guidance in the EIIP, Volume 3, Chapter 11, Gasoline Marketing (Stage I and State II) at

http://www.epa.gov/ttn/chief/eiip/techreportivolume03/iii11 apr2001.pdf), multiply the activity rate 1.25

by the amount sold per county found in step 4.

5. Now multiply the process rate found in step 5 by the emission factor .06 Ib VaC/gallon transported

using the EIIP guidance above.

Category 5: Waste Management Practices

Sub-Category 5.1: Solid Waste Incineration

5.1.1 : Industrial Solid Waste Incineration

SCC: 2601010000

Follow these steps when calculating emissions from industrial solid waste incineration:

1. Find the number of manufacturing employees, NAICS code 31, for each county using the County Business Patterns

at the U.S. Census Bureau's website http://censtats.census.gov/cgi-bin/cbpnaic/cbpsel.pl.

Note: Use the steps in 3.2-1 to navigate through the county business patterns.

2. Multiply the county manufacturing employment by the default fuel-loading factor 420 tons /1,000

manufacturing employees.

3. Multiply the process rate in step 2 by AP-42, Fifth Edition, Volume 1, Chapter 2-1.12, Solid Waste

Disposal at http://www.epa.gov/ttn/chief/ap42/ch02/index.html.

5.1.2: Commercial Solid Waste Incineration

SCC: 2601020000

Follow these steps when calculating emissions from commercial solid waste incineration:

1. Find the population for each county at the U.S. Census Bureau's website http://www.census.gov/.

Note: Use steps 2.1-5 to navigate through the U.S. Census Bureau's website.

2. Next find the default factor of .65Ib/person/day from U.S. EPA Municipal Solid Waste Report

http://www.epa.gov/epaoswer/non-hw/muncpllmsw99.htm.

3. Find the percent of commercial solid waste from the U.S. EPA Municipal Solid Waste Report above.

4. Now, calculate the process rate for commercial solid waste incineration by multiplying population by

the default factor of .65Ib/person/day by the percent of commercial solid waste and number of days in

a year.

5. Multiply the process rate in step 4 by AP-42, Fifth Edition, Volume 1, Chapter 2-1.12, Solid Waste

Disposal at http://www.epa.gov/ttn/chief/ap42/ch02/index.html.

5.1.3: Residential Solid Waste Incineration

SCC: 2601030000

21
Follow these steps when calculating emissions from residential solid waste incineration:

1. Find the population for each county at the U.S. Census Bureau's website http://www.census.gov/.

Note: Use step 2.1-5 to navigate through the U.S. Census Bureau's website.

2. Next find the default factor of .65Ib/person/day from U.S. EPA Municipal Solid Waste Report

http://www.epa.gov/epaoswer/non-hw/muncpl/msw99.htm.

3. Find the percent of residential solid waste from the U.S. EPA Municipal Solid Waste Report above.

4. Now, calculate the process rate for residential solid waste incineration by multiplying population by

the default factor of .65Ib/person/day by the percent of commercial solid waste and number of days in

a year.

5. Multiply the process rate in step 4 by AP-42, Fifth Edition, Volume 1, Chapter 2-1.12, Solid Waste

Disposal at http://www.epa.gov/ttn/chief/ap42/ch02/index.html.

Sub-Category 5.2: Residential Open Burning

5.2.1: Leaf and Brush Burning

SCC: 2610000100 and 2610000400

Follow theses step when calculating emissions from leaf and brush burning:

1. Find a per capita factor for leaf burning and a per capita for brush burning by using the U.S. EPA's

Solid Waste Report at http://www.epa.gov/epaoswer/non-hw/muncpl/msw99.htm.

2. Allocate the amount burned by adjusting the per capita factor for leaves at 25% and for brush at 25%.

Of the total waste generated only 28% burns.

3. Once all the percentages from above are calculated, multiply the adjusted per capita factor by the rural

population for each county from the U.S. Census Bureau at http://www.census.gov/

Note: As of the data of this SOP, the following steps will lead to county rural population.

a. Go to http://www.census.gov/

b. On the left hand side, select American Fact Finder

c. Select data sets

d. Detailed tables

e. County

f. Indiana

g. All counties

4 Use the table below to adjust the amount of waste generated to account for the percentage of forest

in each county. The percentages come from a document from the United States Department of

Agriculture at http://ncrs.fs.fed.us/pubs/rb/rb nc253b.pdf.

Percent Forested Acres per County Adjusted for Yard Waste Generated

<10% 0% generated

>= 10%, and < 50% 50% generated

>=50% 100% generated

22
5. Now, multiply the amount of leaves and brush by the emission factors found in AP-42, Fifth Edition,

Volume 1, Chapter 2, Solid Waste Disposal, Table 2.5-5, and Table 2.5-6 at

http://www.epa.gov/ttn/chief/ap42/ch02/finaVc02s05.pdf.

5.2.2: Residential Waste Incineration

SCC: 2610030000

Follow these steps when calculating emissions from for residential waste incineration:

1. Find a per capita factor for residential waste incineration by using the U.S. EPA's Solid Waste Report

at http://www.epa.gov/epaoswer/non-hw/muncpllpubs/mswchar05.pdf.

2. Using the Solid Waste Report above, subtract the percentage of recycled and composted material

from the per capita factor above.

3. Now, subtract the percentages of combustibles Le. glass, metal, yard trimmings, and other waste.

4. Using a document from EPA, it states that only 28% of waste generated by rural population burns and

of that percent, 49% is actually combusted. Using this information multiply the per capita factor by

0.28 and then multiply that number by 0.49 actually burned in rural counties.

5. Once all the percentages are calculated, multiply the adjusted per capita factor by the rural population

for each county from the U.S. Census Bureau at http://www.census.gov/.

Note: Use steps 5.2.1-3 to find county rural population.

6. Calculate the amount of residential waste by the emission factors in the EIIP, Volume 3, Chapter 16,

Open Burning at http://www.epa.gov/ttn/chief/eiip/techreport/volume03/index.html.

Sub-Category 5.3:

SCC: 2630020000

Public Owned Treatment Works (POTW's)

Follow these steps when calculating emissions from POTW's:

1. To calculate the amount of annual flow for public owned treatment works, obtain the amount of

monthly flow rate for each county. This is data is supplied by the Office of Water Quality. To

calculate for annual flow multiply the monthly flow by the default of 0.16 that represents the amount of

industrial flow.

2. Calculate the process rate above by the emission factors in FIRE 6.25 using the SCC code

2630020000.

Sub-Category 5.4:

SCC: 2640000004

Treatment, Storage, and Disposal Facilities

Follow these steps when calculating emissions from treatment, storage, and disposal facilities:

1. Obtain a list of treatment facilities and the amount of ignitable waste from each facility from IDEM's

Office of Land Quality.

2. Using the list of facilities from step 1, run a query using the ACCESS data tables at

K:\OAQ_INV\Steptool\Stptl_02.mdb to obtain the amount of ignitable waste reported to IDEM's Office

of Air Quality.

23
3. Compare the two lists obtained in step 1 and step 2, for each facility subtract any quantity reported to

OAQ from the quantity reported to OlQ. Do this in order to avoid double counting quantities reported

to both offices. Combine the quantities reported from facilities within the same counties. Use these

quantities as the process rate for each county.

4. Multiply the process rate above with the combined emission factor in the table below:

Emission Source Emission Factor in AP-42 Emission Factor Used

(Ib VOClTon) (Ib VOClTon)

Storage Tank Vent 0.004-0.09 0.09

Spillage (filling) 0.20 0.20

Loading (filling) 0.00024-1.42 1.42

Spillage (emptying) 0.20 0.20

Loading (emptying) 0.00024-1.42 1.42

Combined Emission Factor 3.33

Category 6: Submit Data to EPA

Submit data in a format that is acceptable to EPA. At the present time the format is the

National Emission Inventory (NEI).

6. Standards and checklists

The Emission Reporting program does not have any checklist for the Area Source Inventory at this time.

The Emission Group does this electronically through an excel spreadsheet that is created when needed.

7. Records Management

The Area Source Inventory files are kept electronically at K:\OAQ_INV\lnv\Area Source.

The Branch Contact for the Air Programs Branch and the Section contact for the Technical Support and

Modeling Section will keep copies of the SOPs for the Technical Support and Modeling Section to be

referenced as needed. An electronic copy will also be available on K:\OAQ_INV\SOPs.

8. Quality Assurance I Quality Control

Comparisons are made against the emissions estimates made by The U.S. EPA in the NEI.

9. Continuous Improvement Cycle

A periodic review will be completed per updates and changes made to the EIIP.

10. References

The Area Source Inventory is a requirement of 40 CFR Part 51 Subpart A - Emission Inventory Reporting

Requirements.

11. History of Revisions

Date Revision Number Description Month/day/year

02/27/2008 1 Revised using new SOP template.

12. Appendices

None

24
APPENDIX L

Lake Michigan Air Directors Consortium

Emission Estimates Technical Support

Document
February 27, 2008

Base M Strategy Modeling: Emissions (Revised)

The purpose of this document is to summarize the emission estimates prepared for LADCO's

latest (Base M) 2005 base year and 2008, 2009, 2012, and 2018 future year modeling. Base

year emissions by state and source sector for Base K (2002) and Base M (2005) are compared

in Figure 1. A more detailed state and source sector summary is provided in Attachment 1.

Additional emission reports are available on the LADCO website:

http://www.ladco.orgltech/emis/r5/round5reports.htm.

voe NOx 502

12000

10000

8000

6000 OWl

4000 .OH

2000 MI

IN

0

2002 2005 2002 2005 2002 2005 .IL

(K) (M) (K) (M) (K) (M)

12000

10000 o Area

8000 • Nonroad+MAR

6000 111I Onroad

4000 [J Non-EGU

2000 .EGU

0

2002 2005 2002 2005 2002 2005

(K) (M) (K) (M) (K) (M)

Figure 1. Base K and Base M Emissions for 5-State LADCO Region: VOC, NOx, and 502 (TPD, July weekday)

Base Year Emissions

In micl-2006, LADCO completed modeling analyses for a 2002 base year and several future

year control strategies (LADCO, 2006a and LADCO, 2006b). Following those analyses, a

decision was made to conduct additional modeling using a more current base year (2005).

Examination of multiple base years provides for a more complete technical assessment. All

modeling was conducted in accordance with USEPA modeling guidelines (USEPA, 2007).
February 27, 2008

For on-road, ammonia, and biogenic sources, 2005 emissions were estimated by emission

models. For other sectors in the LADCO States, 2005 emissions were either supplied by a

contractor (railroads and commercial marine) or by the States (point sources, area sources, and

aircraft). For other sectors in non-LADCO States, a contractor obtained the latest base (2002)

and future year emission files (2009, 2018) from the other Regional Planning Organizations

(RPOs) (Alpine, 2007a). Specifically, the following versions of these emissions files were used:

MANE-VU: Version 3.1, WRAP: Pre2002d, CENRAP: Base F, and VISTAS: Base F. The 2005

emissions were then estimated by linearly interpolating between the 2002 and 2009 emissions.

Further discussion of the development of the 2005 base year emissions is provided below:

On-Road: CONCEPT was run by a contractor using transportation data (e.g., VMT and vehicle

speeds) for 24 networks supplied by the state and local planning agencies in the LADCO States

and Minnesota (Environ, 2008). These data were first processed with T3 (Travel Demand

Modeling [TDM] Transformation Tool) to provide input files for CONCEPT. For some networks,

the VMT outputs from T3 were adjusted to match 2005 HPMS data. CONCEPT was then run

with meteorological data for a July and January weekday, Saturday, and Sunday (July 15 - 17

and January 16 -18) to produce link-specific, hourly emission estimates. A spatial plots of

emissions for July 15 are provided in Figure 2.

voe Emissions

O.lO 393 ===""-::------~----,---,

0.18

0.15

0.12

0.10

0.08

0.05

0.03

NOx Emissions O.~O 393 ==:?...----rr-.......----,------,

0.18

0.15

0.12

0.10

0.08

0.05

0.03

0.00 1 L~L_ _i:.===r:::=:I==~~ 0.00 1 L~L_ _i::.===c=:::I:=.s....---.J .... _-,~...... _..... -_I~_..

Figure 2. July 15, 2005 motor vehicle emissions for VOC (left) and NOx (right)

For the non-LADCO States, CONCEPT was run by a contractor using RPO-based HPMS

county-level data (2002 and 2009) and MOBILE6 inputs (2002) compiled by another contractor

(Environ, 2008). HPMS VMT for 2005 were generated by linearly interpolating between the

2002 and 2009 data. The 2002 MOBILE6 inputs were used for the 2005 modeling, with a few

adjustments (e.g., fuel sulfur content was set to 30 ppm, as required by the Tier 2/low sulfur

regulations). Meteorological data for a July and January weekday, Saturday, and Sunday (July

15 - 17 and January 16 - 18) were used.

For other months (for both LADCO and non-LADCO States), weekday, Saturday, and Sunday

emissions were linearly interpolated based on the January and July emissions.
February 27, 2008

Off-Road: NMIM2005 was run by Grant Hetherington (Wisconsin DNR) to produce emissions

for most off-road sectors for the LADCO States plus Minnesota, Iowa, and Missouri. Improved

model inputs included local data for construction and agricultural equipment prepared by a

contractor were incorporated (E.H. Pechan, 2004), and 2005 gasoline parameters. (Note,

model updates prepared by AIR to address evaporative emissions were not included.)

EMS was run by LADCO 'using Grant Hetherington's NMIM2005 data and, for the no~LADCO

States, using emission fi,les supplied by Alpine based on data from the other RPOs to produce

weekday, Saturday, and Sunday emissions for each month.

Additional off-road sectors (i.e., commercial marine, aircraft, and railroads [MAR]) were handled

separately. Aircraft emissions were supplied by the LADCO States. Updated information for

railroads and commercial marine for the LADCO States was prepared by a contractor (Environ,

2007a and Environ 2007b). Table 1 compares the new 2005 emissions with the previous 2002

emission estimates. The new 2005 emissions reflect substantially lower commercial marine

emissions and lower locomotive NOx emissions.

EMS was run by LADCO using the contractor and state data and, for the no~LADCO States,

using emission files supplied by Alpine based on data from the other RPOs to produce

weekday, Saturday, and Sunday emissions for each month.

Table 1. Locomotive and Commercial Marine Emissions for 2002 and 2005 Base Year

Railroads (TPY) Commercial Marine (TPY)

2002 2005 2002 2005

VOC 7,890 7,625 1,562 828

CO 20,121 20,017 8,823 6,727

NOx 182226 145,132 64,441 42336

PM 5,049 4,845 3,113 1,413

802 12274 12,173 25,929 8637

NH3 86 85 - -

Area: EMS was run by LADCO using 2005 data supplied by the LADCO States and, for the

no~LADCO States, using emission files supplied by Alpine based on data from the other RPOs

to produce weekday, Saturday, and Sunday emissions for each month. Special attention was

given to two source categories: industrial adhesive and sealant solvent emissions and outdoor

wood boilers.

Industrial Adhesives and Sealants: The NEI shoY.5 this to be a large VOC

emissions category in the LADCO States (Le.. , 50,000 TPY) USEPA

subsequently determined that "(f)or the Region V states, we no longer believe

that there are any activities in the Industrial Adhesives and Sealants category

(SCC 2440020000) that have not been inventoried either in the point source

Industrial Adhesives and Sealants category or under the Consumer and

Commercial Adhesives and Sealants nonpoint category (SCC 2460600000 - all

adhesives and sealants)." (USEPA, 2007b) Consequently, this category was

omitted from the 2005 regional emissions inventory.
February 27, 2008

Outdoor Wood Boilers: Over the past several years, the installation and

operation of outdoor wood boilers for residential use has increased dramatically

in many northern states. Relying on an emission estimation methodology

prepared by Bart Sponseller (WDNR, 2006), emissions were calculated by the

other states for this category.

EGU Point:EMS was run by LADCO using 2005 data supplied by the LADCO States and, for

the non-LADCO States, using emission files supplied by Alpine based on data from the other

RPOs to produce weekday, Saturday, and Sunday emissions for each month. 2005 EGU

emissions were temporalized for modeling purposes using profiles prepared by Scott Edick

(Michigan DEQ) based on CEM data for the period 2004-2006. Profiles were generated for

monthly weekday/Saturday/Sunday based on the median hourly emissions for that month, day,

and hour of the day for the three years. Over 90% of NOX and S02 emissions from EGUs in the

LADCO states were assigned profiles. In non-Ladco states, the annual EGUs emissions were

replaced with the 2005 sum of hourly emissions for all 365 days.

Non-EGU Point: EMS was run by LADCO using 2005 data supplied by the LADCO States and,

for the non-LADCO States, using emission files supplied by Alpine based on data from the other

RPOs to produce weekday, Saturday, and Sunday emissions for each month. EGUs were

removed from this point source file.

Other improvements to the base year inventory included:

Canadian Emissions: Previous modeling inventories for Canadian sources were flawed due to

problems with emissions (e.g., LADCO inventories omitted ammonia emissions) or stack

parameters (e.g., VISTAS inventories failed to include proper stack parameters, resulting in

emissions getting dumped in the surface layer of the model). For Base M, Scott Edick

(Michigan DEQ) processed the 2005 Canadian National Pollutant Release Inventory (NPRIsee http://wv.iw.ec.gc.c::alpdb/Ilpri/). r ~cifically, a subset of the NPRI data which are relevant to

the air quality modeling were reformatted. A number of emission reports are available on the

LADCO website (http://www.ladco.ol\g/tech/emis/basem/caAada/~ndex.htr:il).x.6ircle plot of point

source emissions are presented in Figure 3.

Circle Plot of S02 Sources CASE: pl_-"'__ Circle Plot of NOX Sources

c
Circle Plot of ROO Sources

February 27, 2008

Circle Plot of PM25-PRI Sources

Figure 3. Base year emission plots for Canada

Biogenic Emissions: A contractor provided an updated version of the CONCEPT/MEGAN

(Model of Emissions of Gases and Aerosols from Nature - see http://baLacd.wcar.edu/Megari/)eqan/

biogenics model, which was used to produce base year biogenic emission estimates (Alpine,

2007b). MEGAN includes functions for soil moisture plant stress, a more complete canopy

model, full plant growth cycle emissions calculations, and state of the science emission rates.

Subsequent to deliver of the updated CONCEPT/MEGAN code, it was found that more recent

data sets and model formulations were available. For the purposes of the Round 5 modeling,

LADCO simply scaled the emission estimates from the updated code to reflect these newer

data. This resulted in lower emissions for several organic aerosol species and NOx

Compared to the EMS/BlOME emissions used for Base K, there is more regional isoprene with

MEGAN (see Figure 4). Also, with the secondary organic aerosol updates to the CAMx air

quality model, Base M includes emissions for monoterpenes and sesquiterpenes, which are precursors of secondary PM2.5 organic carbon mass.

soooo

10000

sooo

1000

soo

100

o 1

MOLESJHR 1 97 1

Figure 4. Isoprene emissions for Base M (left) v. Base K (right)

97
February 27, 2008

Ammonia Emissions: The CMU-based 2002 (Base K) annual ammonia emissions were

projected to 2005 using growth factors from the Round 4 emissions modeling. These annual

emissions were then adjusted by applying monthly temporal factors based on the processbased ammonia emissions model (http://www.conceptmodel.oro/nh3/nh3index..html). The

model was run for the following list of model farms using 2002 meteorological data: Dairy

(California, Wisconsin), Swine (Iowa, Wisconsin), and Beef (Texas, Washington, Wisconsin).

Because the model was not complete for the poultry housing model, swine was use in its place

given that both use confined operations.

Each model farms' emissions were used to generate monthly average day emissions and a

monthly profile. The profiles were applied to geographies most associated with that farm type

(e.g., all LADCD states used the Wisconsin farm results). The following figure shows the daily

variation in emissions for the model farms.

Wisconsin - dairy Wisconsin - swine

I I

h- l ... f--------

t,... t om t--------..------:I-ftiII:I~ I I

Washington - beef Texas - beef

!..... 1 J--..,.----,,,......----i---+-----l

l l t---------il-1Ir--H----l I.... t r----.....--~f_T:r______I I ,... I ,om t----t--it

Figure 5. Daily emissions for 2002 for various model farms
February 27, 2008

A plot of the resulting average daily emissions by state and month is provided in Figure 6.

1800,----------------------------------,

1500 -t------------J~------------------___l

1200 -t--------I----\,---------------I--\---___l

900 -f--------/

Jan Feci March Apr May Jun Jul Aug Sept Oct Nov Dec

-+- Illinois __ Indiana

---.- Minnesota Ohio

-.-Iowa Michigan

_Wisconsin

Figure 6. Average daily ammonia emissions for Midwest States by month for 2005

Fires: For Base K, a contractor (EC/R, 2004) developed a 2001,2002, and 2003 fire emissions

inventory for eight Midwest States (five LADCO states plus Iowa, Minnesota, and Missouri),

including emissions from wild fires, prescribed fires, and agricultural burns. Projected emissions

were also developed for 2010 and 2018 assuming "no smoke managemenf and "optimal smoke

managemenf scenarios. An early model sensitivity run showed very little difference in modeled

PM2.5 concentrations. Consequently, the fire emissions were not included in subsequent

modeling runs (Le., they were not in the Base K or Base M modeling inventories).
February 27, 2008

Future Year Emissions

Complete emission inventories were developed for tv.o future years: 2009 and 20181

. Source

sector emission summaries for the base years (2002 - Base K and 2005 - Base M) and future

years are shown in Figure 7. A more detailed state and source sector summary is provided in

Attachment 1. Additional emission reports are available on the LADCO website

(http://64.27.125.175/tecn/emis/r5/round5 re~orts(htm1s.hIm

VOC NOx S02

12000 ..--------------.-------------------,

9000 t------------------i

6000

3000

o

[J Area

[J On-roadl

• Nonroadl

DNon-€GU

.EGU

2002 2005 2009 2012 2015 2018 2002 2005 2009 2012 2015 2018 2002 2005 2009 2012 2015 2018

Figure 7. Base year and future year emissions for 5-5tate LADCO Region (TPD, July weekday)

1 A 2008 proxy inventory was prepared to support a preliminary 2008 modeling analysis to assess

attainment for the basic nonattainment areas (Le, for areas with a 2009 attainment date, the appropriate

panning year is 2008). This inventory reflects the following assumptions:

On-road: scale 2005 base year emissions using the Base K 2002 - 2009 trend (except for the

Cincinnati-Dayton area, where 2008 emissions were generated using CONCEPT and 2008 data

supplied by the local planning agency)

Off-road and area: scale 2005 base year emissions using the Base K 2002-2009 trend

Point - EGU: use 2005 base year emissions, with slight adjustment (-10%)

Point - Non-EGU: use 2005 base year emissions (note: Base K 2002-2009 trend suggests little

change)

Biogenics: use new 2005 base year emissions

A 2012 proxy inventory was prepared to support a preliminary 2012 modeling analysis to assess the

effect of further emission reductions from existing controls. This inventory was derived by interpolating

between 2009 and 2018 emissions for all sectors, except point sources (for which, the 2009 emissions

were used).
February 27, 2008

For on-road, off-road, and EGU sources, the future year emissions were estimated by models

(Le., CONCEPT, NMIM2005, and IPM, respectively) and then processed by LADCO with EMS.

For other sectors (area, MAR, and non-EGU point sources), the future year emissions for the

LADCO States were derived by applying growth and control factors to the base year inventory.

These factors were developed by a contractor (E.H. Pechan, 2007). Growth factors were

based initially on EGAS (version 5.0), and were subsequently modified (for select, priority

categories) by examining emissions activity data. For the non-LADCO States, future year

emission files were supplied by Alpine based on data from the other RPOs. Due to a lack of

information on future year conditions, the biogenic VOC and NOx emissions, and all Canadian

emissions were assumed to remain constant between the base year and future years.

A "base" control scenario was prepared for each future year based on the following "on the

books" controls (E.H. Pechan, 2007):

On-Highway Mobile Sources

• Federal motor vehicle emission control program, low sulfur gasoline, and ultra-low

sulfur diesel fuel

• Inspection/Maintenance programs (nonattainment areas)

• Reformulated gasoline (nonattainment areas)

Off-Highway Mobile Sources

• Federal control programs incorporated into NONROAD model (e.g., nonroad diesel

rule), plus the evaporative Large Spark Ignition and Recreational Vehicle standards

• Heavy-duty diesel (2007) engine standard/Low sulfur fuel

• Federal railroadllocomotive standards

• Federal commercial marine vessel engine standards

Area Sources

• Consumer solvents

• AIM coatings

• Aerosol coatings

• Portable fuel containers

Power Plants

• Title IV (Phases I and II)

• NOx SIP Call

• Clean Air Interstate Rule

• Clean Air Mercury Rule

Other Point Sources

• VOC 2-, 4-,7-, and 10-year MACT standards2

• Combustion turbine MACT

• Consent decrees (refineries, ethanol plants, and ALCOA)3

2 E.H. Pechan's original control file included EPA-default control factor information. Alternative control

factors were developed by Wisconsin for a few MACT categories, and were also applied to the other four

LADCD States.
February 27, 2008

• Other (Illinois and Ohio NOx RACT4, and BART in IN and WI)

Further discussion of the development of the future year emissions is provided below:

On-Road: 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 (Environ, 2008). CONCEPT was only run with meteorological data for a July weekday

(July 15). The emissions for Saturday and Sunday were derived by using scaling factors based

on the 2005 emissions. The state-level emissions for the five LADCO States plus Minnesota

are summarized in Table 25

.

For the non-LADCO States, CONCEPT was run by Environ using HPMS county-level data and

MOBILE6 inputs compiled by another contractor for VISTAS. Note, the emissions modeling for

lA, MO, and OK was redone for 2009 to reflect the state-developed registration distribution data.

(The initial modeling for 2009 used national default values for registration distribution assumed

by VISTAS' contractor. CENRAP's contractor developed emissions inventories for 2002 and

2018 using the state-developed data. For consistency, Environ's remodeling for these three

states for 2009 also used the state-developed data.) Meteorological data for a July weekday

(July 15) were used. The emissions for Saturday and Sunday were derived by using scaling

factors based on the 2005 emissions.

For other months (for both LADCO and non-LADCO States), January weekday, Saturday, and

Sunday emissions were derived based on the July:January ratios for 2005, and then the

weekday, Saturday, and Sunday emissions for other months were linearly interpolated based on

the January and July emissions.

3 E.H. Pechan's original control file included control factors for three sources in Wayne County, MI.

These control factors were not applied in the regional-scale modeling to avoid double-counting with the

State's local-scale analysis for PM2.5.

4 WI believes that NOx RACT for their sources is already included in the 2005 basecase and EGU "will

do· scenario, and IN provided NOx RACT information for inclusion as a no-EGU "may do· scenario.

5 For northeastern IL (CATS region), 2009 and 2018 emissions were increases by 9% and 8%,

respectively, to reflect newer transportation modeling by CATS.
February 27, 2008

Table 2. Summa I'Y 01,fO- - --dEml ----- - - - - --- (TPD - July 15, 2005)

Year State CO-tpd TOG-tpd NOx-tpd PM2.5-lpd S02-lpd NH3-lpd SumofVMT

2005 IL 3,684.3 341.5 748.2 12.9 9.6 35.9 344,087,819.6

IN 3,384.9 282.0 541.1 8.9 11.1 25.7 245,537,231.9

MI 4,210.3 351.9 722.0 12.4 13.9 35.3 340,834,025.9

MN 2,569.1 218.7 380.5 6.3 7.6 17.7 170,024,599.7

OH 6113.4 679.8 933.6 16.2 18.8 36.5 360,521,068.6

WI 2,206.0 175.1 457.5 7.8 9.2 19.7 189,123,964.3

Total 22,168.0 2,049.0 3,782.9 64.5 70.2 170.8 1,650,128,709.9

2009 IL 2,824.4 268.0 527.8 10.1 4.2 38.9 372,132,591.1

IN 2,839.5 234.9 401.9 6.7 2.8 26.1 249,817,026.3

MI 3,172.0 269.2 500.9 9.2 4.0 37.1 356,347,010.5

MN 2,256.8 206.3 307.5 5.1 2.3 21.5 204,443,017.8

OH 4,619.2 423.7 693.5 11.8 4.7 39.5 387,428,127.2

WI 1,673.4 119.4 322.1 5.7 2.3 20.6 197,729,964.9

Total 17,385.3 1,521.5 2,753.6 48.7 20.3 183.6 1,767,897,737.8

2018 IL 2084.7 151.5 200.7 6.3 3.7 43.1 413,887,887.3

IN 2,217.3 138.4 173.0 4.4 2.6 30.2 288,042,232.1

MI 2,434.3 163.5 204.1 5.9 3.6 40.5 388,128,431.8

MN 1,799.6 123.1 137.1 3.6 2.2 24.9 237,022,213.7

OH 3,361.5 242.5 274.1 6.8 4.0 43.1 421,694,093.4

WI 1,255.5 68.4 138.5 3.9 2.0 22.2 218,277,167.5

Total 13,152.9 887.5 1,127.5 30.8 18.1 203.9 1,967,052,025.8
February 27, 2008

EGU Point: Future year emissions were based on EPA's IPM3.0 modeling6

. Three CAIR

scenarios were addressed:

5a: EPA's IPM3.0 was assumed as the future year base for EGUs.

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).?

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). .

Table 3 summarizes the S02 and NOx emissions for the three scenarios. The individual

facilities affected by the "will do" and "may do" adjustments are identified in Attachment 2. The

net effect of these adjustments is a small increase in regional S02 and NOx emissions.

Based on initial discussions with USEPA, a decision was made to use the 2010 IPM emissions

in the 2009 modeling. USEPA subsequently insisted that 2009 modeling must represent 2009

conditions. Because 2009 and 2010 EGU NOx emissions are expected to be similar (note:

CAIR Phase I compliance date for NOx is 2009), the Round 5.1 ozone modeling was not

redone.

USEPA believes that 2009 and 2010 EGU S02 emissions may be significantly different (note:

CAIR Phase I compliance date for S02 is 2010). In particular, USEPA noted that information on

projected scrubber installations identifies several facilities are not expected to be completed

until 2010. A model sensitivity run was conducted with adjusted (higher) EGU S02 emissions.

6 The second set of new IPM runs by EPA were used. These runs were performed at the request of the

RPOs and reflect the addition of run years 2012 and 2018, and the use of four load segments for 2032 to

decrease model size (instead of six segments). Comparing the results in this run with EPA's initial v3.0,

showed small differences Below is a quick summary of the run year differences.

EPA Base Case for IPM v.3.0

2010: 2009-2012

2015: 2013-2017

2020: 2018-2022

2025: 2023-2027

2032: 2028-2035

Base Case RPO Run for IPM v3.0 (added 2012 and 2018 run years, 2020 run year merged with the 2025

run year, and four load segments us~ for the 2032 run year)

2010: 2009-2011

2012: 2012-2012

2015: 2013-2017

2018: 2018-2019

2025: 2020-2028

2032: 2029-2035

7 Scenario 5b and 5c also reflect changes in Minnesota, Missouri, and North Dakota.
February 27, 2008

Table 4 provides information from USEPAs Clean Air Markets Division (CAMD) on scrubber

installation dates. This information is based on various sources, including company

announcements, consent decrees, vendors, and organizations that track scrubber installations.

While there may be uncertainty in any projection of control installations, USEPA considers these

adequate projections for SIP planning purposes.

USEPA identified six plants which: (1) are projected in IPM3.0 to have scrubbers in place by

201 0 (or 2011), but will not be completed by 2009, and (2) are most likely to impact PM2.5 air

quality in the upper Midwest (see highlighting in Table 4). To reflect uncontrolled (2009)

emissions for those facilities (and units), LADCO substituted actual 2005 emissions for the

IPM3.0 projected 2010 emissions. The revised (2009) S02 emissions for the six facilities (see

Table 5) represent a 5-6% increase in domainwide S02 emissions.
February 27, 2008

Table 3. Comparison of EGU Emissions for Base (5a), Will Do (5b), and Will Do (5c) Scenarios

2010 2018

502 5a 5b 5c 5a 5b 5c

IL 958 881 881 869 433 433

IN 1033 1318 1318 1036 1194 1194

MI 667 667 667 725 725 725

OH 1326 1410 1410 983 1127 1127

WI 460 460 421 435 499 . 235

4444 4736 4697 4048 3978 3714

MN 162 148 148 187 167 157

NOx 5a 5b 5c 5a 5b 5c

IL 275 247 247 224 195 195

IN 370 372 372 255 266 266

MI 242 242 242 243 243 243

OH 281 305 305 285 310 310

WI 165 164 155 176 172 145

1333 1330 1321 1183 1186· 1159

MN 116 142 142 132 157 125
February 27, 2008

Table 4. Facilities Anticipating 502 Controls in 2009 and 2010

ORIS Unit Capacity Scrubber Scrubber

State Name Plant Name UniquelD Final Code ID MW OnlineYear OnlineMonth

Alabama Barry 3 B 5 3 5 768 2010

Alabama E C Gaston 26 B 5 26 5 861 2010

Arizona Cholla 113 B 3 113 3 271 2009

Florida Crystal River 628 B 4 628 4 720 2010

Florida Crist 641 B6 641 6 302 2010

Florida Crist 641 B 7 641 7 477 2010

Florida Crystal River 628 B 5 628 5 717 2009 5

Florida Deerhaven Generating Station 663 B B2 663 B2 228 2009 5

Georgia Bowen 703 B 1BLR 703 1BLR 713 2010

Georgia Wansley 6052 B 2 6052 2 892 2009 5

Georgia Bowen 703 B 2BLR 703 2BLR 718 2009 4

Indiana Clifty Creek 983 B 1 983 1 217 2010

Indiana Clifty Creek 983 B 2 983 2 217 2010

Indiana Clifty Creek 983 B 3 983 3 217 2010

Indiana Clifty Creek 983 B 4 983 4 217 2010

Indiana Clifty Creek 983 B 5 983 5 217 2010

Indiana Clifty Creek 983 B 6 983 6 217 2010

Indiana Warrick 6705 B 4 6705 4 300 2010

Kentucky Big Sandy 1353 B BSU2 1353 BSU2 800 2009 11

Kentucky EWBrown 1355 B 1 1355 1 94 2009 1

Kentucky EWBrown 1355 B 2 1355 2 160 2009 1

Kentucky EWBrown 1355 B 3 1355 3 422 2009 1

Kentucky H L Spurlock 6041 B 1 6041 1 315 2009

Maryland Brandon Shores 602 B 1 602 1 643 2010

Marvland Brandon Shores 602 B 2 602 2 643 2010

Maryland Chalk Point LLC 1571 B 1 1571 1 341 2010

Maryland Chalk Point LLC 1571 B 2 1571 2 342 2010

Marvland Dickerson 1572 B 1 1572 1 182 2010

Marvland Dickerson 1572 B 2 1572 2 182 2010

Marvland Dickerson 1572 B 3 1572 3 182 2010

Maryland Morgantown Generating Plant 1573 B 1 1573 1 624 2009

Maryland Morgantown Generating Plant 1573 B 2 1573 2 620 2009

2009

Michigan Monroe 1733 B 4 1733 4 775 (2010?)

Missouri Sioux 2107 B 1 2107 1 497 2010

Missouri Sioux 2107 B 2 2107 2 497 2010

New Jersey PSEG Mercer Gen. Station 2408 B 1 2408 1 315.3 2010

New Jersey PSEG Mercer Gen. Station 2408 B 2 2408 2 309.9 2010

New York AES Westover 2526 B 11 2526 11 21.85 2010

New York AES Westover 2526 B 12 2526 12 21.85 2010

New York AES Westover 2526 B 13 2526 13 84 2010

New York AES Greenidge LLC 2527 B 4 2527 4 26.5 2010

New York AES Greenidge LLC 2527 B 5 2527 5 26.5 2010

NorthCarolina Cliffside 2721 B 1 2721 1 38 2010
February 27, 2008

NorthCarolina Cliffside 2721 B 2 2721 2 38 2010

NorthCarolina Cliffside 2721 B 3 2721 3 61 2010

NorthCarolina Cliffside 2721 B 4 2721 4 61 2010

NorthCarolina Cliffside 2721 B 5 2721 5 550 2010

NorthCarolina GGAlien 2718 B 1 2718 1 161.73 2009 5

NorthCarolina Roxboro 2712 B 1 2712 1 369 2009

NorthCarolina GGAlien 2718 B 2 2718 2 161.73 2009

NorthCarolina G GAlien 2718 B 3 2718 3 259.77 2009

NorthCarolina G GAlien 2718 B 4 2718 4 274.77 2009

NorthCarolina G GAlien 2718 B 5 2718 5 265 2009

NorthCarolina Mayo 6250 B 1A 6250 1A 361.5 2009

NorthCarolina Mayo 6250 B 1B 6250 1B 361.5 2009

Ohio WHSammis 2866 B 6 2866 6 630 2011

Ohio WHSammis 2866 B 7 2866 7 630 2011

Ohio R E Burger 2864 B 7 2864 7 156 2010

Ohio R E Burger 2864 B 8 2864 8 156 2010

Ohio KYQerCreek 2876 B 1 2876 1 217 2010

Ohio KYQerCreek 2876 B 2 2876 2 217 2010

Ohio KYaerCreek 2876 B 3 2876 3 217 2010

Ohio Kyger Creek 2876 B 4 2876 4 217 2010

Ohio Kyger Creek 2876 B 5 2876 5 217 2010

Ohio Conesville 2840 B 4 2840 4 780 2009 4

Ohio Bay Shore 2878 B 4 2878 4 215 2009

Pennsylvania Cheswick Power Plant 8226 B 1 8226 1 580 2010

Pennsylvania Hatfields Ferry Power Station 3179 B 1 3179 1 530 2009 1

Pennsylvania Hatfields Ferry Power Station 3179 B 2 3179 2 530 2009 1

Pennsylvania Hatfields Ferry Power Station 3179 B 3 3179 3 530 2009 1

Pennsylvania Keystone 3136 B 1 3136 1 850 2009

Pennsylvania Keysbne 3136 B 2 3136 2 850 2009

PennsYlvania PPL Brunner Island 3140 B 1 3140 1 321 2009

Pennsylvania PPL Brunner Island 3140 B 2 3140 2 378 2009

Tennessee Kingston 3407 B 1 3407 1 135 2010

Tennessee Kingston 3407 B 2 3407 2 135 2010

Tennessee Kingston 3407 B 3 3407 3 135 2010

Tennessee KinQston 3407 B 4 3407 4 135 2010

Tennessee Kingston 3407 B 5 3407 5 177 2010

Tennessee Kinaston 3407 B 6 3407 6 177 2010

Tennessee Kingston 3407 B 7 3407 7 177 2010

Tennessee Kingston 3407 B 8 3407 8 177 2010

Tennessee KinQston 3407 B 9 3407 9 178 2010

Tennessee Bull Run 3396 B 1 3396 1 881 2009 1

Texas Fayette Power Project 6179 B 1 6179 1 598 2009

Texas Fayette Power Project 6179 B 2 6179 2 598 2009

Virginia Chesterfield 3797 B 5 3797 5 310 2010

Virginia Yorktown 3809 B 1 3809 1 159 2010
February 27, 2008

Table 5. Summary of Adjusted EGU S02 Emissions (TPD)

State Plant 2010lPM 2005 BY

Indiana Clifty Creek 41.41 225.32

Missouri Ameren Sioux 22.25 141.92

Ohio Kyger Creek 21.53 197.68

Ohio Sammis 147.97 305.90

Pennsylvania Cheswick 11.53 103.98

Tennessee KinQston 41.15 155.20
February 27, 2008

References

Alpine Geophysics, 2007a, "Emissions Inventory Assistance: 2005 Base Year Biogenic and

Other (non-LADCO) State Emissions, Preparation and Delivery of Non-MRPO Emission Files<

March 12,2007.

Alpine Geophysics, 2007b, Updated CONCEPT code with new (MEGAN) biogenic emissions

delivered via e-mail from James Wilkinson on February 9,2007.

EC/R, Incorporated, 2004, "Fire Emissions Inventory Development for the Midwest Regional

Planning Organization", Final Report, September 30,2004.

EH. Pechan, 2004, "LADCO Nonroad Emissions Inventory Project - Development of Local

Data for Construction and Agricultural Equipment", Final Report, September 10, 2004

EH. Pechan, 2005, "Development of Updated Growth and Control Factors for Lake Michigan

Air Directors Consortium (LADCO)", Draft Report, December 29,2005.

E H. Pechan, 2007, "Development of 2005 Base Year Growth and Control Factors for Lake

Michigan Air Directors Consortium (LADCO)", Final Report, September 2007.

Environ, 2004, "LADCO Nonroad Emissions Inventory Project for Locomotive, Commercial

Marine, and Recreational Marine Emission Sources, Final Report, December 2004.

Environ, 2007a, "LADCO 2005 Locomotive Emissions·, Draft, February 2007.

Environ, 2007b, "LADCO 2005 Commercial Marine Emissions·, Draft, March 2, 2007.

Environ, 2008, "LADCO On-Road Emission Inventory Development Using CONCEPT MV",

January 2008.

LADCO, 2006a, "Base KlRound 4 Strategy Modeling" Emissions", May 16, 2006.

LADCO, 2006b, "Base KlRound 4 Modeling: Summary", August 31, 2006.

Mansell, G, Z. Wang, R. Zhang, J. Fadel, T. Ramsey, H. Xin, Y. Liang, and J. Arogo, 2005, "An

Improved Process-Based Ammonia Emissions Model for Agricultural Sources - Emission

Estimates"

USEPA, 2007a, "Guidance for on the Use of Models and Other Analyses for Demonstrating

Attainment of Air Quality Goals for Ozone, PM2.5, and Regional Haze", EPA-454/B07-002, April

2007.

USEPA, 2007b, E-mail from Dennis Beauregard (OAQPS) dated February 22,2007.

Zhang, R, T. Ramsey, J. Fadel, J. Arogo, Z. Wang, G. Mansell, and H. Xin, 2005, "An Improved

Process-Based Ammonia Emissions Model for Agricultural Sources - Model Developmenf

WDNR, 2006, "Wisconsin Draft 2005 Outdoor Wood Boiler Methodology", PowerPoint

presentation by Bart Sponseller, November 13, 2006.
Web Sites:

http://www.ladco.orgltech/emislbaseklBase~RePOr1S:htmts.htm

http://wWw.ladco.org/techlemislr5/rournCfS~rep6rts.htmts.htm

h.ttp://www.ladco.or.gltech/emislbasem/eanada/index.•htm~x.htm

http://www.ec.gc.calpC!ib/nprilb/npri/

http://bai;accLllcar.edu/Megarill egan

http://www.cOli\ceptmodeIJorqlnh3/nh31:iridex.html·x.html

February 27, 2008
February 27, 2008

ATTACHMENT 1

Emissions Summaries
VOC BasoM BaseK BasaM BaseK BaseK BaseM NOx BaseM BaseK Base 1.4 BaseK BaseK Base 1.4 SOX BaseM BaseK Base 1.4 BaseK BaseK Base 1.4 PM2.5 BaseM BaseK Base M BaseK BaseK Base 1.4

July 2002 2005 2009 2009 2012 2018 2018 2002 2005 2009 2009 2012 2018 2018 2002 2005 2009 2009 2012 2018 2018 2002 2005 2009 2009 2012 2018 2018

Nonroad

II.. 224 321 164 257 149 130 213 324 333 263 275 224 154 155 31 33 5 5 0.6 0.4 0.4 30 24 14

IN 125 195 94 160 95 95 128 178 191 142 158 141 141 89 17 19 3 3 3 0.3 0.2 17 13 7

MI 348 414 307 350 276 222 271 205 239 159 197 133 93 112 19 22 3 3 0.5 0.3 03 22 18 11

OH 222 356 161 294 145 126 238 253 304 195 248 162 109 135 23 29 4 5 0.5 0.3 0.4 27 22 13

WI 214 238 194 203 175 140 157 145 157 114 129 97 69 77 13 15 2 2 0.3 0.2 02 14 12 7

~taleTotal 1133 1524 920 1264 840 713 1007 1105 1224 873 1005 757 566 568 103 118 17 18 4.9 1.5 15 110 89 52

U.S. Tolal 8463 9815 5442 8448 5244 6581 6041 9080 6057 8120 5832 5100 505 654 117 153 104 13 573 750 475

MAR

II.. 10 11 10 10 10 10 6 277 246 201 228 195 188 165 0 22 0 19 0 0 17 7 6 4

IN 5 5 5 5 5 5 3 123 93 89 87 87 84 65 0.2 8 0.2 7 0.2 0.2 6 2 2 2

1.41 7 7 7 7 7 8 7 114 87 112 82 111 110 65 0.6 21 0.7 14 0.7 0.8 8 3 3 2

OH 8 7 8 7 8 8 5 177 134 128 126 126 122 94 0.4 14 0.3 12 0.3 0.3 10 4 4 2

WI 4 4 4 4 4 4 3 79 58 59 54 59 57 41 12.7 8 9.5 6 9.5 8.7 5 2 2 1

5-Stale Total 34 34 34 33 34 35 24 770 618 589 577 578 559 430 13.9 73 10.7 58 10.7 10 46 18 17 11

U.S. Total 307 317 321 157 329 346 334 4968 4515 4002 1813 3964 3919 3812 620 512 509 122 509 503 290 147 57 165

O1herArea

IL 679 675 688 594 700 738 582 62 48 68 48 70 73 49 11 11 12 16 12 13 16 40 64 69

IN 354 391 365 358 373 398 384 62 56 65 58 67 69 59 158 32 150 32 151 153 32 2 2 2

MI 518 652 516 562 520 541 549 49 49 52 50 53 54 51 71 29 68 29 68 68 28 111 114 120

OH 546 604 550 506 558 593 487 50 93 59 108 60 62 108 22 6 34 15 35 35 14 19 35 34

WI 458 315 467 290 474 506 293 32 37 34 37 34 35 37 9 17 9 13 10 10 13 11 12 12

5-Stale Total 2555 2637 2586 2310 2625 2776 2295 255 283 278 301 284 293 304 271 95 273 105 276 279 103 183 227 237

U.S. Tolal 17876 21093 18638 18683 20512 24300 3856 4899 4100 4220 4418 5357 2075 2947 2062 2559 2189 2709 2735 2621 2570

On-Road

IL 446 341 314 268 260 197 151 890 748 578 528 474 300 201 9 4 3 13 10 6

IN 405 282 237 235 193 150 138 703 541 425 402 313 187 173 11 3 2 9 7 2

1.41 522 351 335 269 303 217 163 926 722 680 501 619 385 204 14 4 3 12 9 3

OH 574 680 365 424 340 238 242 1035 934 609 693 512 270 274 18 4 4 16 12 4

WI 238 175 144 119 117 88 68 481 457 303 322 226 116 138 9 2 2 8 6 2

5-Stale Total 2185 1829 1395 1315 1213 890 762 4035 3402 2595 2446 2144 1260 990 61 17 14 58 44 17

U.S. Total 14263 7825 23499 13170

EGU

IL 9 7 8 6 8 9 7 712 305 227 275 244 231 224 1310 1158 944 958 789 810 869 13 34 77

IN 6 6 6 6 7 6 6 830 393 406 370 424 283 255 2499 2614 1267 1033 1263 1048 1036 16 73 74

1.41 12 6 11 4 11 12 4 448 393 218 242 219 247 243 1103 1251 1022 667 1031 1058 725 15 25 29

OH 5 4 6 5 7 7 6 1139 408 330 280 322 271 285 3131 3405 1463 1326 994 701 983 28 94 80

WI 3 5 3 2 4 4 3 293 213 146 165 139 147 177 602 545 512 460 492 500 435 0 22 25

5-Slale Total 35 28 34 23 37 38 26 3422 1712 1327 1332 1348 1179 1184 8645 8973 5208 4444 4569 4117 4048 72 248 285

U.S. Total 214 140 195 124 197 215 138 14371 10316 7746 7274 7721 7007 6095 31839 34545 20163 16903 17629 14727 14133 685 1131 1571

Non-EGU

IL 313 221 286 218 305 350 258 356 330 334 218 338 343 235 373 423 251 335 257 249 346 16 17 19

IN 150 130 160 137 170 199 167 238 179 212 175 216 225 178 292 218 270 216 274 290 180 35 36 44

1.41 123 116 115 119 122 139 140 216 240 208 242 214 229 271 162 158 166 148 171 185 163 20 21 25

OH 77 84 75 87 79 90 104 177 175 157 166 160 167 178 240 289 231 288 210 216 293 27 28 33

WI 88 84 97 87 104 120 106 98 97 91 93 92 94 81 163 156 154 152 155 156 85 0 01 01

5-Stale Total 751 635 733 648 780 898 775 1085 1021 1002 894 1020 1058 943 1230 1244 1072 1139 1067 1096 1067 98 102 121

U.S. Tolal 4087 3877 4409 4700 5378 8446 6730 6129 6435 6952 5759 5630 6093 6340 6970 1444 1777

IL 1681 1576 1470 1353 1432 1434 1217 2621 2010 1671 1572 1545 1287 1029 1725 1656 1212 1337 1059 1072 1251 119 155 189

IN 1045 1009 867 901 843 853 826 2134 1453 1339 1250 1248 989 819 2966 2902 1690 1294 1691 1492 1256 81 133 131

1.41 1530 1546 1291 1311 1239 1139 1134 1958 1730 1429 1314 1349 1118 946 1356 1495 1260 865 1271 1312 927 183 190 190

OH 1432 1735 1165 1323 1137 1082 1082 2831 2048 1478 1619 1342 1001 1074 3416 3761 1732 1650 1240 953 1304 121 195 166

WI 1005 821 909 705 878 862 630 1128 1019 747 800 647 520 551 800 750 687 635 667 675 540 35 54 47

5-Stale Total 6693 6687 5702 5593 5529 5350 4889 10672 8260 6664 6555 6131 4915 4419 10263 10564 6581 5781 5928 5504 5280 539 727 723
February 27, 2008

ATTACHMENT 2

"Will Do" and "May Do" EGU Facility Emissions
February 27, 2008

2009 - Difference between base (Sa) and "will do" (5b) scenarios

The SAS System 09:55 Wednesday, February 27, 2008 1

------------------------------------------------------------ polid=NOX --------------------------------------------------------

Obs cntryid stid cyid fcid name polid aceebase aceenew diff

1 US 17 97 097190AAC MIDWEST GENERAT NOX 11.54 6.28 -5.266

2 US 17 197 197810AAK MIDWEST GENERAT NOX 21.11 9.46 -11. 652

3 US 18 73 00008 NIPSCO - R.M. S NOX 26.50 24.81 -1.691

4 US 18 77 00001 IKEC - CLIFTY C NOX 11.58 16.42 4.836

5 US 18 89 00117 NIPSCO - DEAN H NOX 20.51 19.13 -1. 384

6 US 27 37 2703700003 NSP dba Xce1 En NOX 8.03 26.74 18.709

7 US 27 61 2706100004 Minnesota Power NOX 15.43 18.40 2.969

8 US 27 163 2716300005 Xce1 Energy - A NOX 4.21 5.92 1.718

9 US 29 183 0001 AMERENUE-SIOUX NOX 28.47 12.81 -15.658

10 US 38 55 126 Coal Creek Stat NOX 30.49 30.36 -0.132

11 US 38 57 12 Leland Olds Sta NOX 11.32 36.67 25.348

12 US 38 57 125 Stanton Station NOX 6.11 6.11 0.002

13 US 38 57 13 Antelope Valley NOX 33.00 36.39 3.385

14 US 38 57 289 Coyote NOX 35.12 36.95 1. 839

15 US 38 59 172 RM Heskett Stat NOX 5.45 4.72 -0.727

16 US 38 65 165 M R Young Stati NOX 6.02 71.10 65.081

17 US 39 93 0247030013 AVON LAKE POWER NOX 3.98 20.54 16.561

18 US 39 129 0165000006 NOX 1. 69

19 US 55 11 606034110 DAIRYLAND POWER NOX 19.24 18.96 -0.279

20 US 55 21 111003090 Alliant Energy- NOX 14.23 17.16 2.927

21 US 55 43 122014530 Alliant Energy- NOX 7.61 7.77 0.160

22 US 55 59 230006260 WIS ELECTRIC PO NOX 7.39 14.03 6.647

23 US 55 71 436035930 MANITOWOC PUBLI NOX 2.06 1. 80 -0.259

24 US 55 79 241007690 WIS ELECTRIC PO NOX 15.25 15.41 0.166

25 US 55 79 241007800 WIS ELECTRIC PO NOX 7.87 6.07 -1. 801

26 US 55 117 460033090 WP & L Alliant NOX 19.06 11.85 -7.215

27 US 55 123 663020930 DAIRYLAND POWER NOX 10.47 8.52 -1. 955 -------- ------- --------

po1id 382.05 486.07 102.327
February 27, 2008

------------------------------------------------------------ po1id=S02 --------------------------------------------------------

Obs cntryid stid cyid fcid name polid aceebase aceenew diff

28 US 17 97 097190AAC MIDWEST GENERAT S02 49.91 29.27 -20.636

29 US 17 197 197810AAK MIDWEST GENERAT S02 91.90 62.70 -29.198

30 US 18 29 00002 AMERICAN ELECTR S02 66.34 102.72 36.389

31 US 18 43 00004 PSI ENERGY - GA S02 25.53 66.01 40.488

32 US 18 73 00008 NIPSCO - R.M. S S02 82.52 63.71 -18.817

33 US 18 147 00020 INDIANA MICHIGA S02 71. 67 198.71 127.042

34 US 18 167 00021 PSI ENERGY - WA S02 76.09 175.87 99.786

35 US 27 31 2703100001 Minnesota Power S02 12.27 5.75 -6.512

36 US 27 61 2706100004 Minnesota Power S02 30.76 20.79 -9.968

37 US 27 163 2716300005 Xcel Energy - A S02 5.33 7.11 1.777

38 US 29 183 0001 AMERENUE-SIOUX S02 22.25 8.34 -13.903

39 US 38 55 126 Coal Creek Stat S02 27.45 75.37 47.926

40 US 38 57 12 Leland 01ds Sta S02 108.15 126.06 17.906

41 US 38 57 125 Stanton Station S02 25.29 12.37 -12.922

42 US 38 57 13 Antelope Valley S02 26.60 43.72 17.128

43 US 38 57 289 Coyote S02 19.26 53.19 33.932

44 US 38 59 172 RM Heskett Stat S02 9.23 30.11 20.872

45 US 38 65 165 M R Young Stati S02 27.98 82.23 54.249

46 US 39 81 0641160017 W. H. SAMMIS PL S02 147.97 55.61 -92.363

47 US 39 93 0247030013 AVON LAKE POWER S02 7.62 127.04 119.417

48 US 39 129 0165000006 S02 16.55

49 US 55 21 111003090 A11iant Energy- S02 61. 97 74.80 12.822

50 US 55 43 122014530 A1liant Energy- S02 11. 49 42.60 31.111

51 US 55 59 . 230006260 WIS ELECTRIC PO S02 7.39 12.34 4.949

52 US 55 71 436035930 MANITOWOC PUBLI S02 5.90 9.95 4.050

53 US 55 79 241007690 WIS ELECTRIC PO S02 59.72 41.19 -18.535

54 US 55 79 241007800 WIS ELECTRIC PO S02 38.79 21. 36 -17.433

55 US 55 123 663020930 DAIRYLAND POWER S02 19.56 3.79 -15.772

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

polid 1138.93 1569.26 413.785

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

1520.97 2055.32 516.112
February 27, 2008

2009 - Difference between "will do" (5b) and "may do" (5c) scenarios

2008 1

The SAS System 09:55 Wednesday, February 27,

------------------------------------------------------------ po1id=NOX --------------------------------------------------------

Obs cntryid sUd cyid fcid name polid aceebas~ aceenew diff

1 US 19 139 70-01-011 MUSCATINE POWER NOX 5.649 3.926 -1.7226

2 US 55 9 405031990 WI PUBLIC SERVI NOX 9.234 7.786 -1.4476

3 US 55 11 606034110 DAIRYLAND POWER NOX 18.957 18.994 0.0377

4 US 55 21 111003090 A11iant Energy- NOX 17 .158 17 .156 -0.0021

5 US 55 25 113004430 MADISON GAS & E NOX 3.886 2.639 -1.2470

6 US 55 43 122014530 A11iant Energy- NOX 7.765 7.756 -0.0091

7 US 55 59 230006260 WIS ELECTRIC PO NOX 14.034 9.826 -4.2074

8 US 55 71 436035930 MANITOWOC PUBLI NOX 1.800 0.439 -1.3610

9 US 55 79 241007690 WIS ELECTRIC PO NOX 15.413 15.435 0.0219

10 US 55 79 241007800 WIS ELECTRIC PO NOX 6.068 6.072 0.0041

11 US 55 117 460033090 WP & L Alliant NOX 11.847 11.892 0.0456

12 US 55 123 663020930 DAIRYLAND POWER NOX 8.517 8.482 -0.0343

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

polid 120.325 110.404 -9.9218

------------------------------------------------------------ po1id=S02 --------------------------------------------------------

Obs cntryid stid cyid fcid name polid aceebase aceenew diff

13 US 19 139 70-01-011 MUSCATINE POWER S02 6.237 11.178 4.9415

14 US 55 9 405031990 WI PUBLIC SERVI S02 21.750 18.074 -3.6753

15 US 55 21 111003090 Alliant Energy- S02 74.796 74.988 0.1924

16 US 55 25 113004430 MADISON GAS & E S02 16.331 0.063 -16.2672

17 US 55 43 122014530 Alliant Energy- S02 42.604 42.640 0.0362

18 US 55 59 230006260 WIS ELECTRIC PO S02 12.336 9.850 -2.4867

19 US 55 71 436035930 MANITOWOC PUBLI 502 9.949 3.001 -6.9477

20 US 55 79 241007690 WIS ELECTRIC PO S02 41.189 41. 210 0.0207

21 US 55 79 241007800 WIS ELECTRIC PO S02 21. 360 21. 430 0.0699

22 US 55 123 663020930 DAIRYLAND POWER S02 3.785 3.716 -0.0694

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

polid 250.336 226.151 -24.1856

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

370.662 336.554 -34.1074