state and local emission inventory system and local emission inventory system user’s guide march...

STATE AND LOCAL EMISSION

INVENTORY SYSTEM User’s Guide

March 2016

Department of Natural Resources and Environmental Control

Division of Air Quality

1

TABLE OF CONTENTS

1.0 Introduction .......................................................................................................................... 3

2.0 SLEIS Access....................................................................................................................... 3

2.1 New User .......................................................................................................................... 3

2.1.1 Registration Form ..................................................................................................... 3

2.1.2 User Roles ................................................................................................................. 3

2.1.3 Initial Login Instructions........................................................................................... 3

2.2 Returning User ................................................................................................................. 4

2.2.2 Login Instructions ..................................................................................................... 4

2.2.3 Password Reset Instructions ..................................................................................... 4

3.0 SLEIS Structure ................................................................................................................... 4

3.1 Emission Report Structure ............................................................................................... 6

3.1.1 Facility Inventory ...................................................................................................... 6

Facility ...................................................................................................................... 7

Emission Units .......................................................................................................... 7

Control Devices ........................................................................................................ 8

Release Points ........................................................................................................... 9

Unit Processes......................................................................................................... 11

3.1.2 Emissions ................................................................................................................ 14

Process Emissions................................................................................................... 14

Report Attachments ................................................................................................ 20

3.2 Submitting a Report ....................................................................................................... 20

3.3 Request an Amendment ................................................................................................. 23

4.0 Pollutants and Emission Estimation................................................................................... 24

4.1 Criteria Pollutants and Their Precursors ........................................................................ 24

4.1.1 Ozone and Precursors ............................................................................................. 24

4.1.2 Particulate Matter (PM) .......................................................................................... 24

4.1.3 PM Precursors ......................................................................................................... 25

4.2 Hazardous Air Pollutants (HAPs) .................................................................................. 25

4.2.1 Lead......................................................................................................................... 25

4.2.2 VOC or PM HAPs .................................................................................................. 25

4.3 Greenhouse Gases (GHGs) ............................................................................................ 25

2

LIST OF ATTACHMENTS

A Facility User Registration Form

B Emission Calculation Method Codes and Descriptions

C Calculating PM10 and PM2.5 Emissions

D Combustion HAPs Table

E Greenhouse Gas Table

3

1.0 INTRODUCTION The State and Local Emissions Inventory System (SLEIS) is designed to facilitate the collection

and reporting of air emissions inventory information through a web-based application. The

purpose of this document is to provide basic guidance to the facility users of SLEIS. Should a

user have any question arise that is not answered in this document, please feel free to contact the

Division of Air Quality (DAQ) at 302-739-9402.

2.0 SLEIS ACCESS

2.1 New User

2.1.1 Registration Form

In order to access SLEIS for a given facility, new users must complete the registration

process. The first step in the registration process is to complete the SLEIS User

Registration Form, which can be found as Attachment A to this document, as well as on

the SLEIS home page (http://apps.dnrec.state.de.us/sleis/). Multiple users who request

access to the same facility may register on the same registration form. Please return the

completed form via email to both Jacquelyn Cuneo ([email protected]) and

Mark Prettyman ([email protected]) at the DAQ for processing.

Note that the email address provided on the registration form will be used as the SLEIS

user ID. This email address will be used for password resets and other correspondence.

Please choose an email address you plan to use for future submittals.

2.1.2 User Roles

There are four roles that can be assigned to a facility user; however, a facility user can

only be assigned three of these roles. User roles are (1) Administrator, (2) Submitter, and

(3) Viewer or Editor. User role functions are defined as follows:

o Administrator: While the DAQ manages initial user registration, the Administrator

can edit their facility’s user information, edit their facility’s user roles, and delete

former facility users. There must be at least one Administrator assigned to each

facility. The Administrator should be an employee of the facility or corporation and

supply a company email address; consultants and contractors should not be facility

Administrators.

o Submitter: The Submitter is the only user that is able to submit an emission report to

the DAQ. There must be at least one Submitter assigned to each facility. Submitters

will be required to complete challenge questions and answers during registration to be

used when making a submission.

o Editor: The Editor can view and edit facility and emission data.

o Viewer: The Viewer can only view facility and emission data.

2.1.3 Initial Login Instructions

Upon receipt of the completed Registration Form, DAQ will enter the user information

into SLEIS. The user will then receive an email from the State of Delaware DNREC

stating the SLEIS account has been created and prompting the user with a link to create

an initial account password. The user will then need to “reset” their password by entering

http://apps.dnrec.state.de.us/sleis/

mailto:[email protected]


4

a new password, confirming the new password, and clicking submit. The user will then

be able to log on to the application using their email address and new password. If the

facility which the user requested access to is listed under “My Facilities”, the user

registration process is complete.

2.2 Returning User

2.2.2 Login Instructions

Log in to SLEIS by visiting the SLEIS home page (http://apps.dnrec.state.de.us/sleis/)

and clicking “Login” in the upper right corner of the page. Enter the email address

provided on the original registration form and previously established password.

2.2.3 Password Reset Instructions

If you have forgotten your password, click “Forgot Password” and enter your email

address. You will receive an email from the State of Delaware DNREC prompting you

with a link to complete your password reset request. The user will then need to reset their

password by entering a new password, confirming the new password, and clicking

submit. The user will then be able to log on to the application using their email address

and new password.

3.0 SLEIS STRUCTURE When entering the SLEIS webpage into your browser, you will be brought to the SLEIS Home

Page (see screen shot of Home Page below). The home page contains a “Welcome” section

which provides a general overview of the application and useful links to reference during the

reporting process; a “Register” section which contains the SLEIS Registration Form; and a

“News” section which will be periodically updated with SLEIS related information.

http://apps.dnrec.state.de.us/sleis/

5

Once you log in, you will be brought to the “My Facilities” page. Click the open button

to view reports in “My Reports” for a given facility. Click open again to view the emission

report for the desired year. There are three possible “Status” conditions for a reporting year:

An emission report with the status “Not Started” means the facility has not begun the

emissions report for that specific year.

An emission report with the status “In Process” is open for viewing and editing.

An emission report with the status “Submitted” is open for viewing, but closed for

editing.

6

3.1 Emission Report Structure

Once an emission report is opened, you will notice that the report is separated into two sections,

“Facility Inventory” and “Emissions.” Each section contains additional modules for emissions

data reporting.

3.1.1 Facility Inventory

The Facility Inventory section consists of five modules: Facility, Release Points, Control

Devices, Emission Units, and Unit Processes. Each of these five modules has multiple

fields and tabs for data entry. Users can view or edit (depending on the user

roles identified) the details of each module. This section represents the operations of the

facility. What units exist at the facility that create emissions? What processes are related

to each unit? Where does the process exhaust flow? Is the process exhaust routed

through a control device? An accurate representation of facility operations will ensure

accurate emission estimations.

To demonstrate the Facility Inventory consider the below facility:

The facility is using a boiler (Emission Unit) to heat a large plant. The boiler is

generally fueled by natural gas (Unit Process 1), and alternately has the capability to be

fueled by #6 oil (Unit Process 2), or coal (Unit Process 3). The boiler’s exhaust is

routed to a stack (Release Point) for discharge into the atmosphere. Prior to the stack,

the exhaust is routed through a Selective Non-Catalytic Reduction control device

(Control Device 1) to reduce NOx emissions, as well as an electrostatic precipitator

(Control Device 2) to reduce PMx emissions.

Emission

Unit

Unit

Process 1

Unit

Process 3

Control

Device 1

Control

Device 2

Facility Release

Point

Unit

Process 2

7

Facility

Click Facility to enter the required data in the module. General facility

information is required in this module to include: Facility Name,

Company, Description, Status (Operating, Temporarily Shutdown,

Permanently Shutdown), Status Date, NAICS Code, Facility Contacts,

Facility Street Address, and Facility Location in Latitude/Longitude

coordinates (decimal degrees) or UTM X/Y coordinates (meters).

Emission Units

Click Emission Units to review existing or add new emission unit data.

Following the example, our emission unit is the boiler. Emission Unit

Identifiers should be numbered sequentially as 001, 002, 003 etc.

Emission Unit Type is chosen from a drop-down menu; Type 999 -

Unclassified may be chosen if all other options are not applicable.

Emission Unit Description can be a very simple description. From our

example, our Emission Unit has a description of “BOILER #1.”

8

Control Devices

Click Control Device to review existing or add new control device data.

Following our example, our first control device is the “Selective Non-

Catalytic Reduction for NOx”. Control Device Identifiers should be

numbered sequentially as 1, 2, 3, etc. To fill in the Control Measure

field, begin typing the control device or practice; SLEIS will provide

options based on what is typed. Enter the pollutants that are controlled

by the control device and the average control efficiency.

9

Release Points

A release point is required for every emission unit process. Following

our example, our release point is the stack; we have used the description

“BOILER #1” to easily correspond the release point to the emission unit.

Release point identifiers should be numbered sequentially as 1, 2, 3, etc.

Release points are often identified as stacks, but can be classified as

being horizontal, vertical (with or without a rain cap), downward-facing

vent, gooseneck, or as fugitive emissions with no obvious dimensional release point.

Release point type is chosen from the drop-down menu. If applicable, stack parameters

are entered in this module including height, diameter, exit temperature, exit gas flow rate,

and exit gas velocity. If exit gas flow rate and stack diameter values are entered, SLEIS

10

will calculate exit gas velocity. If exit gas velocity and stack diameter values are entered,

SLEIS will calculate exit gas flow rate.

Under the Location tab, enter the Latitude/Longitude coordinates (decimal degrees) or

UTM X/Y coordinates (meters) of the release point. If unknown, select “Yes” for

“Release point utilizes facility coordinates.”

11

Unit Processes

Unit Processes relate the emission unit and throughput with release

points and any control devices. Following our example, we will relate

the Emission Unit “BOILER #1” and its throughput of natural gas with

the Control Devices “SELECTIVE NON-CATALYTIC REDUCTION

FOR NOX” and “ELECTROSTATIC PRECIPITATOR” and the

Release Point “BOILER #1”. Unit Processes should be numbered

sequentially as 1, 2, 3, etc, per unit. Under the Unit Process tab, choose the emission

unit. A Source Classification Code (SCC) is assigned to each unit process to accurately

reflect the process or activity. The Unit Process Description often reflects the activity’s

12

throughput. Following our example, our Unit Process #1 Description is “NATURAL

GAS.”

Under the Control Approach tab, enter the Capture Efficiency. The Capture Efficiency is

the effective percentage of the emission stream that flows into the control equipment, as

opposed to the amount that does not flow into the control equipment due to leaks, lack of

enclosure, etc. Select the Control Device(s) for the process.

13

Under the Release Point Apportionment tab, select the release point for the process.

Enter the percentage of the exhaust that will be routed to that particular release point.

Referring to our example, there is only one stack for this process; 100% of the exhaust

will discharge through this stack.

14

For returning users, the information in the Facility Inventory section will likely remain

unchanged. However, all users should ensure this information is up-to-date and accurate.

3.1.2 Emissions

Process Emissions

The Process Emissions module is the space where the annual emissions

data are entered. Each unit process will have associated emissions

estimates for reported pollutants. The user can view or edit (depending

on the user roles identified) the details of each process emission

estimation. Once a process is opened, three tabs run across the top of the

module: Process, Operations, and Emissions. The data in this module

15

will need to be updated for each year of operation and reporting.

Under the Process tab, the facility is required to provide “monthly throughput totals”

data. SLEIS will sum monthly throughput and display the total as annual throughput. If

monthly throughput data is unknown and only annual throughput data is available, please

estimate monthly throughputs based on your knowledge of the process, such as process

run time or production output. Please verify that the “throughput unit of measure”

corresponds to the emission factor numerator for emissions calculations (this field may be

pre-populated from year to year). If you believe the units are entered incorrectly, please

contact DAQ before making a change.

16

Because emissions are often calculated based on throughput through the use of standard

or site-specific emission factors, incorrect units may significantly impact emission

estimates. Please refer to the SLEIS Method Code 28 Emission Factor excel sheet,

located on the SLEIS Home Page, to compare standard emission factors and emission

factor units available in SLEIS for a given SCC, to ensure throughput units and emission

factor units are the same.

A common error is the incorrect reporting of natural gas usage. The natural gas fuel

usage throughputs are required in millions of cubic feet (mmcf) for all standard emission

factors, while facilities frequently report natural gas fuel usage based on bills or fuel

meters (often read in hundreds of cubic feet (ccf), thousands of cubic feet (mcf) or

Therms). Please ensure all units have been converted correctly.

The user will notice a check box named “Process is Reported?” under this tab. By

default, this box is checked. If the process did not operate and therefore there were no

emissions for the current reporting year, this box can be unchecked. However, please be

aware that by unchecking this box, all pre-populated fields in the Process, Operations,

and Emissions tabs will be cleared. To prevent creating confusion for future years

reporting, please consider the following:

o If the user believes the process will not be active in the future, this check box may

be unchecked. Again, all fields related to this process including pollutant records

will be cleared. For example, this process is for burning coal, but coal has been

permanently eliminated from use at the facility and is now prohibited in the air

permit. In this case, unchecking the box is the best approach.

o If the user wants to retain all fields relating to this process including process

emission throughput unit of measure, throughput type, throughput material, and

pollutant records, leave the check box checked. As an example, this is the best

approach for when a facility employs fuel switching based on fuel cost, and while

the facility does not use any distillate oil this year, if the price of natural gas

increases, the facility may switch to distillate oil next year. In this case, if the

process did not have emissions to report for that given year:

Add zero (0) to the twelve monthly throughputs fields in the Process tab.

Add zero (0) to the Average Hours/Day, Average Days/Week, and

Average Weeks/Year fields in the Operations tab.

Add zero (0) to the Estimated Emissions (Tons) field in the Emissions tab

for the pollutants with calculation methods of Material Balance,

Engineering Judgement, or CEM/Stack Test.

Emissions for any pollutant that relies on the use of an emission factor will

automatically be populated with zero emissions based on zero throughput.

Under the Operations tab, the facility is required to provide time (in integers) of facility

operations in terms of Average Hours/Day, Average Days/Week, and Average

Weeks/Year. Actual Hours will be automatically calculated from those fields. If the

facility has a known Actual Hours operated value, the calculated value can be

overwritten. The facility is also required to enter ozone season days (May thru Sept), and

17

summer season days (Jun, Jul, and Aug). The seasonal operation values (as percentages)

will be calculated by SLEIS based upon the monthly throughput previously enter.

Under the Emissions tab, the following fields require data entry: Pollutant Code,

Calculation Method, Emission Factor (dependent upon Calculation Method), Emission

Factor Unit (dependent upon Calculation Method), Estimated Emissions (dependent upon

Calculation Method), and Overall Control Efficiency. The Overall Control Efficiency is

the product of Capture Efficiency (the effective percentage of the emission stream that

flows into the control equipment, as opposed to the amount that does not flow into the

control equipment due to leaks, lack of enclosure, etc.) and Control Efficiency (the

percentage of pollutant emissions reduced by the control device).

18

A pollutant code look-up table is available in SLEIS to help the user choose the correct

pollutants. Activate the look-up table by typing the first few letters of the required

pollutant into the Pollutant Code field:

19

A user has a choice of 19 different emissions calculation methods. Refer to Attachment

B of this document for a full list of the emission calculation method codes and their

descriptions. The user should use the most accurate emission calculation method based

on available information. As an example, if the facility recently performed a stack test for

NOx, then the NOx rate from the test should be used instead of a standard EPA emission

factor. Choose an Emission Calculation Method Code (MC) from the drop down menu:

There are three types of emission calculation methods:

(1) Emission Factors (EFs) are automatically populated by SLEIS (MC-28 only).

(2) EFs are entered into SLEIS by the user.

(3) Emissions are calculated by the user outside of SLEIS and are directly entered

into the Estimated Emissions field.

Emission estimates that use a method code other than MC-28 should be accompanied

with supporting information including the source of the emission factor and calculations.

20

Supporting information can be entered in the Comment field or attached in the Emission

Report Attachment module.

Report Attachments

The user can upload supporting information, calculations, and

documentation to this module. All attachments are encouraged as they

will assist DAQ in reviewing submitted data. To add a new document

simply click “Add.” From here you will be able to browse your files for

your supporting documents, add a description, and save the report

attachments.

3.2 Submitting a Report

Once emissions and other data and information have been entered into, or calculated by, SLEIS

for all emission units and processes, the user should “submit” a validated emissions report to

DAQ through SLEIS. When a submission is completed, no further changes can be made to the

emission report without first making an Amendment Request. To open an emissions report, go

to “My Facilities,” click the open button for a specific facility to view reports in “My Reports,”

and click open again to view the emission report for the desired year. Once the emissions report

is open, click “Validate Report” under More Actions.

The application will then check the report for errors. If errors exist, an error report file will be

created to help the user identify and repair the errors.

21

Once an error-free validated report has been received, mark the report as “Ready for

Submission.” The report will then be displayed on the “My Facilities” page for users with the

Submitter role for the facility.

The facility’s Submitter will now see “Submission Review” when the emission report is opened.

Click “View Electronic Document” to create and download a Copy of Record file. Click

“Continue” to proceed.

22

The Submitter will then be prompted to certify Submission Agreements, answer their Challenge

Questions, and enter a password. The password requested is the same as the login password.

The emission report submission has been completed. From this report, the DAQ will review the

data, create an Emissions Statement (an emissions summary of criteria pollutants by emission

unit), and send the Emissions Statement to the facility’s main contact via email for signature by

the facility’s Responsible Official. The signed report should be sent back to DAQ, preferably as

a scanned pdf file, via e-mail or mailed to Jacquelyn Cuneo at:

23

DNREC, Division of Air Quality,

Attn: Airshed Planning and Inventory Program

State Street Commons

100 W. Water Street, Suite 6A

Dover, DE 19904

3.3 Request an Amendment

A facility or DAQ may identify an error or an omission after a submission is made. In this case

the facility should submit an amendment request by clicking “Request Amendment” after

opening the emission report in question.

Enter a brief description for the reason of your amendment request and click the Submit button.

24

DAQ will unlock the report, at which time the facility will receive an email indicating that their

report is now open. The facility now can make the necessary changes to their emission report,

then follow the same submission steps as before.

4.0 POLLUTANTS AND EMISSION ESTIMATION The pollutants to be reported by facilities to DAQ to support Federal and State requirements and

activities include criteria pollutants, criteria pollutant precursors, hazardous air pollutants

(HAPs), and greenhouse gases (GHGs).

4.1 Criteria Pollutants and Their Precursors

Criteria pollutants include ozone, nitrogen dioxide, carbon monoxide, sulfur dioxide, particulate

matter, and lead.

4.1.1 Ozone and Precursors

Ozone is a criteria pollutant for which Delaware currently does not meet the Federal

National Ambient Air Quality Standard (NAAQS). Ozone is typically not emitted by

facilities, but rather is created in the atmosphere as a result of photochemical reactions of

Volatile Organic Compounds (VOCs) and Nitrogen Oxides (NOx).

4.1.2 Particulate Matter (PM)

There are two PM NAAQS; one for PM equal to or less than 10 microns in diameter and

the other for PM that is equal to or less than 2.5 microns in diameter. PM2.5 is commonly

known as fine particulate. Each of these pollutants consists of filterable (FIL) and

condensable (CON) fractions, depending on the emission source. As a result, the

following five PM pollutants are required to be reported: PM-CON, PM10-FIL, PM10-

PRI, PM25-FIL, and PM25-PRI. For purposes of emissions inventory, the following

definitions apply to these pollutants:

o PM-CON is defined as condensable particulate matter. It is the material that is in

vapor phase at stack conditions, but which condenses upon cooling in the ambient air

to form solid or liquid PM immediately after discharge from the stack. PM-CON is a

component of both PM10-PRI and PM25-PRI, and is always considered to be less

than 1 micron is diameter.

o PM10-FIL is filterable particulate matter with a diameter less than or equal to 10

microns.

o PM10-PRI is the sum of PM10-FIL and PM-CON. PM10-FIL may equal PM10-PRI

if there is no condensable component.

o PM25-FIL is filterable particulate matter with a diameter less than or equal to 2.5

microns.

o PM25-PRI is the sum of PM25-FIL and PM-CON. PM25-FIL may equal PM25-PRI

if there is no condensable component.

Additionally, the following relationships between PM pollutants must be followed:

o PM2.5-FIL ≤ PM10-FIL

o PM2.5-PRI ≤ PM10-PRI

o PM2.5-FIL + PM-CON = PM2.5-PRI

o PM10-FIL + PM-CON = PM10-PRI

25

SLEIS can calculate many combustion-related PMx emission estimates based on EPA

emission factors available in SLEIS. However, SLEIS cannot correctly calculate PMx

emission estimates for combustion units burning #4, #5, #6 residual oils or coal. This is

because the emission estimate depends on an equation with fuel sulfur content as a

variable. Guidance on calculating particulate emissions of #4, #5, #6 residual oils and

coal using EPA emission factor formulas are included as Attachment C to this document.

4.1.3 PM Precursors

PM precursors include NOx, sulfur dioxide (SO2), and ammonia (NH3).

4.2 Hazardous Air Pollutants (HAPs)

The Clean Air Act Amendments of 1990 listed 188 HAPs in Section 112(b) of the Act. Facilities

are required to submit emissions estimations for all HAPs emitted. For a list of pertinent HAPs

relating to combustion processes, please refer to Attachment D of this document.

SLEIS can calculate combustion HAP emission estimates using standard EPA emission factors

contained in SLEIS. If the facility has more specific combustion HAP data, such as emission

estimates developed for TRI reporting, stack test data, or fuels analysis, please replace the

system default emissions values with that data.

To estimate HAP and VOC emissions from fixed-roof and floating-roof storage tanks, DAQ

suggests the use of the TANKS software

(http://www.epa.gov/ttn/chief/software/tanks/index.html). TANKS is a Windows-based

computer software for emissions estimation. The most current version of the TANKS software

is Version 4.09D. EPA notes the TANKS model was developed using a software that is now

outdated. Because of this, the model is not reliably functional on computers using certain

operating systems such as Windows Vista or Windows 7. EPA recommends the use of

equations/algorithms specified in AP-42 Chapter 7 for estimating VOC emissions from storage

tanks. The equations specified in AP-42 Chapter 7

(http://www.epa.gov/ttn/chief/ap42/ch07/index.html) can be employed with many current

spreadsheets/software programs.

4.2.1 Lead

Lead is both a criteria pollutant and a HAP. Lead should be treated as a HAP and is

reported as elemental Lead with CAS number for the metal Lead, CAS #7439921.

4.2.2 VOC or PM HAPs

Many HAP compounds are reportable as VOC or PM. These HAP compounds should be

reported as an individual HAP as well as reported in total VOC or PM emissions.

4.3 Greenhouse Gases (GHGs)

DAQ requires the reporting of internationally recognized GHGs, including Carbon Dioxide

(CO2), Methane (CH4), Nitrous Oxide (N2O), Perfluorocarbons (PFCs), Hydrofluorocarbons

(HFC), and Sulfur Hexafluoride (SF6) For most combustion equipment and some other

processes, the database has been pre-populated with CO2, N2O, and CH4 emission factors. Refer

to Attachment E for a full list of Greenhouse Gases to be reported.

http://www.epa.gov/ttn/chief/software/tanks/index.html

http://www.epa.gov/ttn/chief/ap42/ch07/index.html

ATTACHMENT A – REGISTRATION FORM

STATE OF DELAWARE DEPARTMENT OF NATURAL RESOURCES

& ENVIRONMENTAL CONTROL

DIVISION OF AIR QUALITY 100 WEST WATER STREET, SUITE 6A

DOVER, DELAWARE 19904

DIVISION OF AIR QUALITY TELEPHONE: (302) 739 - 9402

FAX NO.: (302) 739 - 3106

STATE AND LOCAL EMISSIONS INVENTORY SYSTEM

USER REGISTRATION FORM

In order to access the State and Local Emissions Inventory System (SLEIS) for a given facility, users

must complete the registration process. First, please complete the attached SLEIS User Registration

form. Multiple users wanting to access the same facility can register on the same registration form. On

the registration form, user roles must be identified. There are four roles that can be assigned to a facility

user; however, a facility user can only be assigned three of these roles. User roles are (1) Administrator,

(2) Submitter, and (3) Viewer or Editor. User role functions are defined as follows:

Administrator: While the Division of Air Quality (DAQ) manages initial user registration, the

Administrator can edit their facility’s user information, edit their facility’s user roles, and delete

former facility users. There must be at least one Administrator assigned to each facility. An

Administrator should be an employee of the facility or corporation and supply a company email

address; consultants and contractors should not be facility Administrators.

Submitter: The Submitter is the only user that is able to submit an emission report to the DAQ.

There must be at least one Submitter assigned to each facility. Submitters will be required to

complete challenge questions and answers during registration to be used when making a

submission.

Editor: The Editor can view and edit facility and emission data.

Viewer: The Viewer can only view facility and emission data.

Return completed forms via email to both Jacquelyn Cuneo ([email protected]) and Mark

Prettyman ([email protected]) at the DAQ. DAQ staff will then enter the user registration

information into SLEIS. Once this step is completed, the user will receive an email from the State of

Delaware DNREC stating the SLEIS account has been created and prompting the user with a link to

create an initial account password. The user will then be prompted to “reset” their password by entering a

new password, confirming the new password, and clicking submit. The user will then be able log in to

the system using their email address and new password. If the facility which the user wants to access is

listed under “My Facilities”, the registration process is complete.








FAX NO.: (302) 739 - 3106

Facility User #1

Facility Name:

Facility Id#:

User’s Name:

E-mail Address: (This address will be used to login into the system and for user correspondence.)

Title:

Organization:

Street Address:

City: State: Zip:

Telephone Number:

Fax Number:

Mobile Number:

Role (Y or N): Administrator:

Submitter:

Editor: OR Viewer:

Facility User #2

Facility Name:

Facility Id#:

User’s Name:


Title:

Organization:

Street Address:

City: State: Zip:

Telephone Number:

Fax Number:

Mobile Number:


Submitter:

Editor: OR Viewer:






FAX NO.: (302) 739 - 3106

Facility User #3

Facility Name:

Facility Id#:

User’s Name:


Title:

Organization:

Street Address:

City: State: Zip:

Telephone Number:

Fax Number:

Mobile Number:


Submitter:

Editor: OR Viewer:

Facility User #4

Facility Name:

Facility Id#:

User’s Name:


Title:

Organization:

Street Address:

City: State: Zip:

Telephone Number:

Fax Number:

Mobile Number:


Submitter:

Editor: OR Viewer:

ATTACHMENT B – EMISSIONS CALCULATION METHOD CODES AND

DESCRIPTIONS

SLEIS Emissions

Calculation

Method Code

(MC)

Description of Emissions Calculation

Method

Emissions Factor

(EF)

Emissions Factor

Table Look Up

SLEIS Will

Calculate

Emissions

Control

Information Can

Be Provided

Controls Applied

in Calculations

1 CEMS N N N Y N

2 Engineering Judgement N N N Y N

3 Material Balance N N N Y N

4 Stack Test (Post-Control) N N N Y N

6 S/L/T Speciation Profile Y

7 Manufacturer Specification N N N Y N

8 USEPA EF (Post-Control)1

Y Y Y Y N

9 S/L/T EF (Post-Control)1

Y Y Y Y N

10 Site Specific EF (Post-Control) Y N Y Y N

11 Vendor Specific EF (Post-Control) Y N Y Y N

12 Trade Group EF (Post-Control) Y N Y Y N

13 Other EF (Post-Control) Y N Y Y N

24 Stack Test (Pre-Control) N N N Y N

28 USEPA EF (Pre-Control)2

Y Y Y Y Y

29 S/L/T EF (Pre-Control)1

Y Y Y Y Y

30 Site Specific EF (Pre-Control) Y N Y Y Y

31 Vendor Specific EF (Pre-Control)

32 Trade Group EF (Pre-Control) y N Y Y Y

33 Other EF (Pre-Control) Y N Y Y Y

Notes: 1. No factors for these methods are currently in the system.

2. Only MC-28 has Efs available for automatic look-up

ATTACHMENT C – CALCULATING PM10 AND PM2.5 EMISSIONS FOR

#4, #5, AND #6 FUEL OILS USING EPA FIRE 6.24 FORMULAS

1

Calculating PM10 and PM2.5 Emissions For #4, #5 and #6 Fuel Oils Using EPA FIRE 6.24 Formulas The following information should be used to calculate uncontrolled emissions for PM10-PRI (Primary PM10), PM10-FIL (Filterable PM10), PM2.5-PRI (Primary PM2.5) and PM-FIL2.5 (Filterable PM2.5) and Source Classification Codes (SCCs) listed. This information should be used when stack test, CEM (Continuous Emission Monitoring) or other information acceptable to the Emissions Inventory Development group is not available. PM Condesible can be automatically calculated in the i-STEPS system for the SCCs listed below. There has been some confusion, when calculating PMx emissions for Residual Oil burning combustion equipment using formula in EPA’s FIRE database. The Factor Information REtrieval (FIRE) Data System is a database containing EPA's emission estimation factors. Part of the reason for the confusion is historically when calculating emissions the variable “A” has represented the % Ash in the fuel. In the underlined formula in the table below this is not the case. “A” is a variable represented by a formula. “A” = ((x * S) + the constant 0.37). For #6 oil x=1.12. See the Notes column for more information. Please note that EPA has determined states shall use the identifiers PM25-FIL and PM25-PRI when reporting PM2.5 Filterable and PM2.5 Primary. See the instructions included in the cover letter to the facilities for additional information on Particulate Matter emissions. SCC Pollutant Units EPA FIRE 6.24 Notes EPA FIRE 6.24 Formula 10100401 PM10-FIL 1000 Gallons Burned S=% Sulfur 5.9E0*(1.12*S+0.37) 10100401 PM10-PRI 1000 Gallons Burned Sum of PM10-FIL and PM-CON emission

factors (5.9E0*(1.12*S+0.37))+(1.500E0)

10100401 PM25-FIL 1000 Gallons Burned S=% Sulfur 4.3E0*(1.12*S+0.37) 10100401 PM25-PRI 1000 Gallons Burned Sum of PM25-FIL and PM-CON emission

factors (4.3E0*(1.12*S+0.37))+(1.500E0)

10100404 PM10-FIL 1000 Gallons Burned S=% Sulfur 5.9E0*(1.12*S+0.37) 10100404 PM10-PRI 1000 Gallons Burned Sum of PM10-FIL and PM-CON emission

factors (5.9E0*(1.12*S+0.37))+(1.500E0)

10100404 PM25-FIL 1000 Gallons Burned S=% Sulfur. 4.3E0*(1.12*S+0.37) 10100404 PM25-PRI 1000 Gallons Burned Sum of PM25-FIL and PM-CON emission

factors (4.3E0*(1.12*S+0.37))+(1.500E0)

10100405 PM10-FIL 1000 Gallons Burned Particulate emission factors for residual oil 5.9E0*A

2

combustion without emission controls are, on average, a function of fuel oil grade and sulfur content where S is the weight % of sulfur in the oil. For example, if the fuel is 1.00% sulfur, then S=1. For Number 6 Oil: A=1.12(S)+0.37. For Number 5 Oil: A=1.2. For Number 4 Oil: A=0.84.; (Factor is derived: 71% of the PM, filterable factor)

10100405 PM10-PRI 1000 Gallons Burned Sum of PM10-FIL and PM-CON emission factors

(5.9E0*A)+(1.50E0)

10100405 PM25-FIL 1000 Gallons Burned Particulate emission factors for residual oil combustion without emission controls are, on average, a function of fuel oil grade and sulfur content where S is the weight % of sulfur in the oil. For example, if the fuel is 1.00% sulfur, then S=1. For Number 6 Oil: A=1.12(S)+0.37. For Number 5 Oil: A=1.2. For Number 4 Oil: A=0.84.; (Factor is derived: 52% of the PM, filterable factor)

4.3E0*A


(4.3E0*A)+(1.50E0)


5.9E0*A

10100406 PM10-PRI 1000 Gallons Burned Sum of PM10-FIL and PM-CON emission (5.9E0*A)+(1.50E0)

3

factors 10100406 PM25-FIL 1000 Gallons Burned Particulate emission factors for residual oil

combustion without emission controls are, on average, a function of fuel oil grade and sulfur content where S is the weight % of sulfur in the oil. For example, if the fuel is 1.00% sulfur, then S=1. For Number 6 Oil: A=1.12(S)+0.37. For Number 5 Oil: A=1.2. For Number 4 Oil: A=0.84. ; (Factor is derived: 52% of the PM, filterable factor)

4.3E0*A


(4.3E0*A)+(1.50E0)


5.9E0*A


(5.9E0*A)+(1.50E0)

10100504 PM25-FIL 1000 Gallons Burned Particulate emission factors for residual oil combustion without emission controls are, on average, a function of fuel oil grade and sulfur content where S is the weight % of sulfur in the oil. For example, if the fuel is 1.00% sulfur, then S=1. For Number 6 Oil: A=1.12(S)+0.37. For Number 5 Oil: A=1.2. For Number 4 Oil: A=0.84.; (Factor is derived: 52% of the PM,

4.3E0*A

4

filterable factor) 10100504 PM25-PRI 1000 Gallons Burned Sum of PM25-FIL and PM-CON emission

factors (4.3E0*A)+(1.50E0)

10200401 PM10-FIL 1000 Gallons Burned Particulate emission factors for residual oil combustion without emission controls are, on average, a function of fuel oil grade and sulfur content where S is the weight % of sulfur in the oil. For example, if the fuel is 1.00% sulfur, then S=1. For Number 6 Oil: A=1.12(S)+0.37. For Number 5 Oil: A=1.2. For Number 4 Oil: A=0.84.

7.17E0*A


(7.17E0*A)+(1.500E0)


4.67E0*A


(4.67E0*A)+(1.500E0)


7.17E0*A

5


(7.17E0*A)+(1.50E0)


4.67E0*A


(4.67E0*A)+(1.50E0)


7.17E0*A


(7.17E0*A)+(1.50E0)


4.67E0*A

10200403 PM25-PRI 1000 Gallons Burned Sum of PM25-FIL and PM-CON emission (4.67E0*A)+(1.50E0)

6

factors 10200405 PM10-FIL 1000 Gallons Burned Multiply the emission factor provided by the

weight percent sulfur content of the fuel to obtain emission factor in lb/activity units; where S is the wt. % of the sulfur in the oil.

7.90E0*S+2.77E0


(7.90E0*S+2.77E0) + 1.50E0

10200405 PM25-FIL 1000 Gallons Burned Multiply the emission factor provided by the weight percent sulfur content of the fuel to obtain emission factor in lb/activity units. Where S is the wt. % of the sulfur in the oil. Derived factor: 56% of uncontrolled PM-FIL factor based on AP-42, Tables 1.3-1 and 1.3-5.

1.226(S)+1.803E0


(1.226(S)+1.803E0) + 1.50E0

10201404 PM10-FIL 1000 Gallons Burned Multiply the emission factor provided by the weight percent sulfur content of the fuel to obtain emission factor in lb/activity units; where S is the wt. % of the sulfur in the oil. Emission factor was transferred from other oil-burning boilers assuming process similarity.

7.90E0*S+2.77E0

10201404 PM25-FIL 1000 Gallons Burned Multiply the emission factor provided by the weight percent sulfur content of the fuel to obtain emission factor in lb/activity units. Where S is the wt. % of the sulfur in the oil. Derived factor: 56% of uncontrolled PM-FIL factor based on AP-42, Tables 1.3-1 and 1.3-5.

1.226(S)+1.803E0

10300401 PM10-FIL 1000 Gallons Burned Particulate emission factors for residual oil combustion without emission controls are, on average, a function of fuel oil grade and sulfur

5.17E0*A

7

content where S is the weight % of sulfur in the oil. For example, if the fuel is 1.00% sulfur, then S=1. For Number 6 Oil: A=1.12(S)+0.37. For Number 5 Oil: A=1.2. For Number 4 Oil: A=0.84. For Number 2 Oil: A=0.24.


(5.17E0*A)+(1.500E0)

10300401 PM25-FIL 1000 Gallons Burned Particulate emission factors for residual oil combustion without emission controls are, on average, a function of fuel oil grade and sulfur content where S is the weight % of sulfur in the oil. For example, if the fuel is 1.00% sulfur, then S=1. For Number 6 Oil: A=1.12(S)+0.37. For Number 5 Oil: A=1.2. For Number 4 Oil: A=0.84. For Number 2 Oil: A=0.24.

1.92E0*A


(1.92E0*A)+(1.500E0)


5.17E0*A


(5.17E0*A)+(1.50E0)

10300402 PM25-FIL 1000 Gallons Burned Particulate emission factors for residual oil combustion without emission controls are, on average, a function of fuel oil grade and sulfur content where S is the weight % of sulfur in the

1.92E0*A

8

oil. For example, if the fuel is 1.00% sulfur, then S=1. For Number 6 Oil: A=1.12(S)+0.37. For Number 5 Oil: A=1.2. For Number 4 Oil: A=0.84. For Number 2 Oil: A=0.24.


(1.92E0*A)+(1.50E0)


5.17E0*A


(5.17E0*A)+(1.50E0)


1.92E0*A


(1.92E0*A)+(1.50E0)

10

Sample Calculations Calculation for PM10 Filterable (PM10-FIL) for Residual Oil for SCC 10200401: PM10-FIL = Annual Throughput x (7.17 x ((1.12 x S) +0.37)) EPA FIRE formula (7.17E0*A) For number 6 Oil: A=1.12(S)+0.37 Where: S = % Sulfur in fuel Annual Throughput = The amount of residual oil per (1000 gallons) burned in a specified

year. 7.17 =lbs/1000 Gallons Burned = EPA emission factor 1.12 = constant value 0.37 = constant value Example: If SCC = 10200401 If Annual Throughput = 587.159 (1000 gallons) Then: S = 1.0% PM10-FIL = (587.159) x (7.17 x ((1.12 x (1)) + 0.37)) PM10-FIL = 6272.80 lbs /2000 PM10-FIL = 3.13 Tons Calculation for PM10 Primary (PM10-PRI) for Residual Oil for SCC 10200401: PM10-PRI = PM10-FIL + PM-CON Where: PM10-FIL = PM10-FIL (Filterable PM10) PM-CON = Condensable Particulate Matter calculated in i-STEPS PM10-PRI = PM10-PRI (Primary PM10) Example: If PM10-FIL = 3.14 Tons If PM-CON = 0.44 Tons Then: PM10-PRI =3.14 +0.44 PM10-PRI =3.58 Tons Calculation for PM25-FIL for Residual Oil for SCC 10200401: PM25-FIL = Annual Throughput x (4.67x ((1.12 x S) +0.37)) Where: S = % Sulfur Annual Throughput = The amount of residual oil per (1000 gallons) burned in a

specified year. 4.67 = Numerical value dependent on SCC 1.12 = constant value 0.37 = constant value

11

Example: If SCC = 10200401 If Annual Throughput = 587.159(1000 gallons) Then: S = 1 PM25-FIL = (587.159) x (4.67 x ((1.12 x (1)) + 0.37)) PM25-FIL = 4085.63lbs/2000 PM25-FIL = 2.04 Tons Calculation for PM25-PRI Residual Oil for SCC 10200401: PM25-PRI = PM10-FIL + PM-CON Where: PM25-FIL = PM-FIL2.5 (Filterable PM2.5 ) PM-CON = Condensable Particulate Matter PM25-PRI = PM2.5-PRI (Primary PM2.5) Example: IF PM25-FIL = 2.0 Tons IF PM-CON = 0.44 Tons Then: PM25-PRI = 2.04 +0.4404 PM25-PRI = 2.48

ATTACHMENT D – COMBUSTION HAPS TABLE

Acids CAS Number

Hydrochloric Acid 7647010

Hydrofluoric Acid 7664393

Sulfuric Acid 7664939

Dioxins/Furans CAS Number

2,3,7,8-TCDD 1746016

1,2,3,7,8-PeCDD 40321764

1,2,3,4,7,8-HxCDD 39227286

1,2,3,6,7,8-HxCDD 57653857

1,2,3,7,8,9-HxCDD 19408743

1,2,3,4,6,7,8-HpCDD 35822469

OCDD 3268879

2,3,7,8-TCDF 51207319

1,2,3,7,8-PeCDF 57117416

2,3,4,7,8-PeCDF 57117314

1,2,3,4,7,8-HxCDF 70648269

1,2,3,6,7,8-HxCDF 57117449

1,2,3,7,8,9-HxCDF 72918219

2,3,4,6,7,8-HxCDF 60851345

1,2,3,4,6,7,8-HpCDF 67562394

1,2,3,4,7,8,9-HpCDF 55673897

OCDF 39001020

2,3,7,8-TCDD TEQ 600

Metals (weight of parent metal

only; combine metal from all

compounds + any elemental forms)

CAS Number

Arsenic 7440382

Beryllium 7440417

Cadmium 7440439

Chromium (total) 7440473

Chromium VI 18540299

Lead 7439921

Manganese 7439965

Mercury 7439976

Nickel 7440020

Polycyclic Aromatic Hydrocarbons

(PAHs)CAS Number

Acenaphthene 83329

Acenapthylene 208968

Anthracene 120127

Benzo(a)anthracene 56553

Benzo(a)pyrene 50328

Benzo(b)fluoranthene 205992

Benzo(g,h,i)perylene 191242

Benzo(k)fluoranthene 207089

Chrysene 218019

Dibenz(a,h)anthracene 53703

Fluoranthene 206440

Fluorene 86737

Indeno(1,2,3-cd)pyrene 193395

Naphthalene 91203

Phenanthrene 85018

Pyrene 129000

ATTACHMENT E – GREENHOUSE GAS TABLE

GREENHOUSE GASES

Chemical Names

Chemical Formula

Synonyms

CAS #

Carbon Dioxide CO2 carbonic anhydride 124-38-9 Methane CH4 natural gas; methyl hydride; R 50 (refrigerant) 74-82-8 Nitrous Oxide N2O dinitrogen monoxide; dinitrogen oxide; hyponitrous acid

anhydride; laughing gas 10024-972

Sulfur Hexafluoride SF6 sulfur fluoride 2551-62-4 Hydrofluorocarbons (HFCs)

1. Trifluoromethane (HFC-23) CHF3 fluoroform; methyl trifluoride; carbon trifluoride; R 23; Arcton 1; Freon 23; Genetron 23; Halocarbon 23

75-46-7

2. Diflouromethane (HFC-32) CH2F2 methylene fluoride; carbon fluoride hydride; Freon 32; Genetron 32; R 32

75-10-5

3. Pentafluoroethane (HFC-125) CHF2CF3 1,1,1,2,2-Pentafluoroethane; Genetron 125; R 125 354-33-6 4. 1,1,1,2-Tetraflouroethane

(HFC-134a) CH2FCF3 1,2,2,2-Tetrafluoroethane; Norflurane; R 134a 811-97-2

5. 1,1,1-Trifluoroethane (HFC-143a) CH3CF3 methyl fluoroform; Freon 143; R 143a 420-46-2 6. 1,1-Diflouroethane (HFC-152a) CH3CHF2 ethylidene fluoride; Freon 152a; Genetron 152a; R 152a;

Genetron 100; Halocarbon 152A; Dymel 152a 75-37-6

7. 1,1,1,2,3,3,3-Heptafluoropropane (HFC-227ea)

(F3C)2CHF 2H- Heptafluoropropane; Apaflurane; Freon 227ea; R 227; R 227ea

431-89-0

8. 1,1,1,3,3,3-Hexafluropropane (HFC-236fa)

(F3C)2CH2 Bistrifluoromethylmethane; R 236fa 690-39-1

9. 1,1,1,2,3,4,4,5,5,5-Decafluoropentane (HFC-4130mee)

C5H2F10 Expanded formula – CF3CFHCFHCF2CF3 2H,3H-Perfluoropentane

138495-42-8

Perfluorohydrocarbons (PFCs) 1. Tetrafluoromethane CF4 Carbon tetrafluoride; perfluoromethane; Arcton 0; Freon

14; Halon 14; Halocarbon 14; R 14 75-73-0

2. Hexafluoroethane C2F6 Perfluoroethane; Freon 116; Fluorocarbon 116; R 116 76-16-4 3. Decafluorobutane C4F10 Perfluorobutane; Perfluoro-n-butane 355-25-9 4. Tetradecafluorohexane C6F14 Perfluoro-n-hexane; Perfluorohexane; Fluorinert FC72;

Flutec PP1 355-42-0

Prepared by Delaware Air Quality Management Section, DNREC from numerous sources – 3/3/06

state and local emission inventory system and local emission inventory system user’s guide march...

Documents