ORL F ILE GENERATION METHODOLOGY

EPA v. 4.10 _PTox

March 2011

SECTION I: INTRODUCTION

This document provides the ORL file generation methodology for EPA Base Case v 4. 1 0 _PTox

. The methodology

takes Integrated Planning Model (IPM ® ) run results and generates ORL

- formatted files that the U.S.

Environmental Protection Agency (U.S. EPA) uses as inputs into air

- quality modeling framework.

Section II provides data descriptions and sources . Section III describes data processing steps in detail . S ection

I V describes the layout of the ORL

- formatted files.

SECTION II: DATA SOURCES AND DESCRIPTIONS

1. IPM run results:

This file contains IPM run results that have been disaggregated to the unit, emission control technology

and fuel type lev el . The file provides records of fossil

- fired existing and retrofit units, and committed and

new

- build aggregates 1 . The committed and new

- build aggregates are hereafter referred to as “generic”

aggregates. All records contain:

i. Population characteristics including state FIPS codes, county FIPS codes, recognized ORIS

codes (<80000) and unit ID s for existing and retrofit units. Generic aggregates have state

level information only

. ii. Sulfur dioxide ( SO 2 )

, nitrogen oxides ( NO

x ) , and p articulate matter (PM) control information

for existing and retrofit units as well as generic aggregates

. iii. Annual and seasonal heat input (TBtu).

iv. Heat content s (MMBtu/ton, k

- gallon, MMcf) and SO 2 and ash contents (lb/MMBtu).

v. Annual and summer NO

x emissions (MTon)

, annual SO 2 emission s (MTon)

, and m ercury

emission s (Ton).

2. Table 1 provides the rest of the input data ’s descriptions , sources and file locations.

Table 1. Input Data Descriptions , Sources and Locations

No. File Name Description Source Location

1 NEI This file contains National Emission Inventory (NEI)

unit

- specific data that include unit s IPM ORL flag,

data source, unique ID, ORIS plant ID, ORIS boiler

ID, tribal code, SIC, MACT source type, MACT,

NAICS, FIPS5, plant name, plant ID, point ID, stack

ID, segment ID, stack default flag, stack type, stack

height, stack diameter, stack temperat ure, stack

flow , stack velocity , location default flag, coordinate

system type, latitude, longitude, UTM zone, control

efficienc y , rule effectiveness, primary control

equipment code, secondary control equipment

code, year, horizontal area fugitive and rele ase height fugitive. EPA ORLSupport

Files.xls

1 Biomass (standalone or co

- firing) is considered fossil and therefore included in this process.2 No. File Name Description Source Location

2 GenericUnitSite This file contains all existing plants that serve as

sister plants in siting generic units. The data include

NEEDS 4. 1 0 Final plant ’ s state FIPS code, county

FIPS code, county’s most recent 8 hour ozone or

PM 2.5 attainment/non

- attainment status, ORIS code

and latitude

- longitude coordinate s

. EPA ORLSupport

Files.xls

3 L at L on Default This file contains updated latitude

- longitude

coordinates by ORIS code, state FIPS code and

county FIPS code. EPA ORLSupport

Files.xls

4 SCC This file contains Source Classification Codes

( SCCs ) by plant type, fuel type , c oal rank, firing and

bottom type (for boilers)

. EPA Table 6

5 PlantTypeStackPara

meters This file contains stack parameters (height,

diameter, temperature and velocity) by plant type. EPA Table 7

6 SCCDefault StackPar

ameters This file contains default stack parameters (height,

diameter, temperature and velocity) by SCC. EPA Table 8

7 HgBIN This file contains mercury speciation fractions

associated with each combination of plant type, coal

rank, fluidized bed combustion firing type, SO 2 control, fabric filter/bag house, ESP, NO

x post

combustion control, particulate matter scrubber and

burner type. The order is hierarchical for H g bin

assignment. EPA Table 9

8 SCCDefaultHeatCont

ent This file contains default heat contents by SCC. EPA Table 10

9 SCCEmsFac This file contains emission factors for carbon

monoxide (CO), volatile organic compounds (VOC),

ammonia (NH 3 ), filterable particulate matter less

than or equal to 10 microns ( filterable PM 10 ),

filterable particulate matter less than or equal to 2.5

microns ( filterable PM 2.5 ) , primary PM 10 and primary

PM 2.5 by SCC. EPA Table 1 1

10 PMSulfurAshContent

Default This file contains default filterable PM 10 and

filterable PM 2.5 control efficiencies and sulfur and

ash contents by plant type and fuel type and coal

rank. EPA Table 12

11 PMCDEmsFac This file contains PM condensable emission factors

by SCC. EPA Table 1 3

1 2 PMAdjustmentRatio This file contains primary PM 10 and primary PM 2.5 emission factors (EF) by SCC for gas

- fired units

(including IGCC)

. EPA Table 1 4

1 3 PMSulfurAshContent This file contains filterable PM 10 and filterable PM 2.5 control efficiencies and sulfur and ash contents by

ORIS code, unit ID, plant type and fuel type. The

filterable PM 10 and filterable PM 2.5 control

efficiencies are based on 2001 data. EPA ORLSupport

Files.xls3 SECTION III: DETAILED DATA PROCESSING

Flow Chart 1 describes general data processing steps. A more detailed description of each step is

provided in the subsections followed

.

Flow Chart 1

. D ata Processing Steps

I. D isaggregate generic aggregates into generic units, site the generic units’s states and count i es and assign them SCCs , ORIS codes

, plant ID s

, unit ID s

, point ID s and segment ID s

.

Generic unit data are prepared by transforming the generic aggregates into units similar to existing units

in terms of the available data. First, t he g eneric aggregates are disaggregated to create generic units.

Second, t he generic units are then sited a nd given state, count y and county

- centroid based latitude

longitude coordinates

. Third, the generic units are assigned SCCs , ORIS codes, plant ID s

, unit ID s , point

ID s and segment ID s

. This process is performed in three steps as described in Flow Chart 2

.

Flow Chart 2

. Generic Unit Processing II . Assign existing and retrofit units’ SCCs

, state FIPS codes, county FIPS codes, plant

IDs, point IDs, segment IDs and other NEI

unit

- specific data that are required for

construction of the ORL file s

. I . Disaggregate generic aggregates into

generic units, sit e the generic units’ states

and counties and assign them SCCs, ORIS

codes, plant IDs, unit IDs , point IDs and

segment IDs

.

III . Assign stack IDs and parameters and latitude

longitude / county centroid coordinates for all records.

1. Create generic units

2. Site generic units

3. Assign g eneric u nits SCCs , ORIS codes,

plant IDs, unit ID s, point IDs and segment

ID’s IV

. Calculate CO, NO

x , VOC, SO 2 , NH 3 , primary PM 10 , primary PM 2.5 and Hg

emissions for all records

. V

. Populate control efficiency percentage

(CEFF) and primary control equipment code

(CPRI) fields for SO 2 , NO

x and speciated Hg.

.4 1. Create g eneric u nits : Generic aggregates are first disaggregated to create generic units. The

process entails two steps:

i. T he generic aggregates are first aggregated by state

, plant type and , for coal steam and IGCC

, coal rank and mercury speciation fractions as shown in Table 9

.

ii. T hey are then s plit into smaller generic units by dividing the aggregated capacity by a reference

capacity . T he result is the number of generic units to be created in a given state for each plant

type and fuel type

.

The reference capacity is varied by plant type as shown in T able 2

.

Table 2

. Generic Unit Reference Capacity

Plant Type Reference Capacity (MW)

Biomass 600

Coal Steam 600

Combined Cycle 250

Combustion Turbine 160

Fossil Waste 0 30

IGCC 550

Oil/Gas Steam 100

Aggregated heat input and e missions are then divided evenly among all generic units created in a

given State for each plant type.

2. Site g eneric u nit s

The generic units are then given a state FIPS code, county FIPS code and latitude

- longitude /county

centroid based on an algorithm that sites generic units in counties within their respective states . The

generic unit siting data file

, GenericUnitSite

, is used in this algorithm to assign each generic unit a

sister plant that is in a county based on the county’s attainment/non

- attainment status. Within a

state the hierarchy for assignment of sister plant s in the order of county code then ORIS code is

shown in Flow Chart 3 :

Flow Chart 3

. Generic Unit Siting Hierarchy

All generic units are sited so that their ORIS codes are unique

, and the same ORIS code has the

same county, latitude

- longitude /county centroid across all runs of the same base case origin. S ister plants in attainment counties

S ister plants in PM non

- attainment

counties

S ister plants in 8

- hour ozone non

attainment counties5 3. Assign g eneric u nits SCCs , ORIS codes, plant IDs

, unit IDs

, point IDs and segment IDs :

i. SCC assignment is based on unit’s p lant type, fuel type and coal rank as shown in T able 3

.

Table 3

. Generic Unit SCC

Plant Type Fuel Type / Coal Rank SCC

Coal Steam Bituminous 10100202

Coal Steam Subbituminous 10100222

Coal Steam Lignite 10100301

Fossil Waste Process Gas 10100701

Biomass Biomass 10100902

Combined Cycle Natural Gas 20100201

Combined Cycle Oil 20100 1 01

Combustion Turbine Natural Gas 20100201

Combustion Turbine Oil 201001 01

IGCC Coal 20100301

IGCC Petroleum Coke 20100301

Oil/Gas Steam Natural Gas 10100601

ii. Generic unit’s ORIS code consist s of a six

- digit number. The units are first sorted by plant type

in the order of combined cycle, fossil waste, combustion turbine, IGCC

, and coal steam

.

Generic unit s’ ORIS code s are then assigned . The first digit of the ORIS code represents the

unit’s plant type as shown in Table 4

. The next three digits are a counter

, starting with “000”

and increment ing with each generic unit created within a given state for each plant type

. T he

last two digits are the state FIPS code.

Table 4

. Generic Unit 1 st Digit ORIS Code

Plant Type 1 st Digit of the ORIS Code

Biomass 3

Coal Steam 9

Combined Cycle 7

Combustion Turbine 8

Fossil Waste 5

IGCC 6

Oil/Gas Steam 4

For example, the first combined

- cycle generic unit sited in Arizona, which has a state FIPS

code of “04”, has an ORIS code of “700104”.

iii. Generic unit’s p lant ID consists of a concatenation of the word “ORIS” and the unit’s ORIS

code.

For example, the first combined

- cycle generic un it in Arizona used in the example above has

a plant ID of “ORIS700104”.

iv. Generic unit’s u nit ID consists of a concatenation of a three

- letter u nit ID code representing the

unit’s plant type as shown in T able 5 and the unit’s state FIPS code.6 Table 5

. Generic Unit ID Code

Plant Type Unit ID Code

Biomass GSC

Coal Steam GSC

Combined Cycle GCC

Combustion Turbine GGT

Fossil Waste GFW

IGCC IGC

Oil/Gas Steam GSC

For example, the first combined

- cycle generic unit in Arizona used in the example above has

a unit ID of “GCC04”.

v. Generic unit’s point ID is the same as the unit’s unit ID.

For example, the first combined

- cycle generic unit in Arizona in the example above has a

point ID of “GCC04”.

vi. Generic unit’s segment ID is equal to 1.

II

. A ssign existing and retrofit unit SCCs, state FIPS codes, county FIPS codes

, plant ID s

, point

ID s

, segment ID s and other NEI unit

- specific data that are required for construction of the ORL

files

.

1. Assign existing and retrofit units’ SCCs

SCC, or Source Classification Code, describ es a generating unit's characteristics. The

assignment of SCC for existing and retrofit units is based on a unit’s configuration that includes

plant type, fuel type, and, if it’s a boiler, firing and bottom type

. The SCC is an eight

- digit numeric

code with specific meaning (starting at the left) in the first, third, and fifth through eighth digits.

For the ORL files, t he first digit of the SCC represents the type of unit (boiler [=1] or turbine [=2]).

The third digit of the SCC represents the economic sector of the unit (electric power sector=1).

And the fifth through eight h digits of the SCC represent the unit's attributes including fuel type

and, if a boiler, bottom and firing type. The second and fourth digits are ze ro

. Table 6 displays

the SCCs.

Table 6. SCC Assignment for Existing and Retrofit Units

Plant Type Boiler / Generator Fuel Type / Coal Rank Firing Bottom SCC

Coal Steam Boiler/Generator Bituminous Wet 10100201

Coal Steam Boiler/Generator Bituminous Vertical Wet 10100201

Coal Steam Boiler/Generator Bituminous Wall Wet 10100201

Coal Steam Boiler/Generator Bituminous Vertical Dry 10100202

Coal Steam Boiler/Generator Bituminous Wall Dry 10100202

Coal Steam Boiler/Generator Bituminous Dry 10100202

Coal Steam Boiler/Generator Bituminous 10100202

Coal Steam Boiler/Generator Bituminous Wall 10100202

Coal Steam Boiler/Generator Bituminous Vertical 10100202

Coal Steam Bituminous Turbo 10100202

Coal Steam Boiler/Generator Bituminous Cyclone Wet 10100203

Coal Steam Boiler/Generator Bituminous Cyclone Dry 10100203

Coal Steam Boiler/Generator Bituminous Cyclone 101002037 Plant Type Boiler / Generator Fuel Type / Coal Rank Firing Bottom SCC

Coal Steam Boiler/Generator Bituminous Stoker/SPR Wet 10100204

Coal Steam Boiler/Generator Bituminous Stoker/SPR 10100204

Coal Steam Boiler/Generator Bituminous Stoker/SPR Dry 10100204

Coal Steam Boiler/Generator Bituminous Tangential Wet 10100211

Coal Steam Boiler/Generator Bituminous Tangential 10100212

Coal Steam Boiler/Generator Bituminous Tangential Dry 10100212

Coal Steam Boiler/Generator Bituminous Cell Wet 10100215

Coal Steam Boiler/Generator Bituminous Cell 10100215

Coal Steam Boiler/Generator Bituminous Cell Dry 10100215

Coal Steam Boiler/Generator Bituminous FBC 10100218

Coal Steam Boiler/Generator Bituminous FBC Wet 10100218

Coal Steam Boiler/Generator Bituminous FBC Dry 10100218

Coal Steam Boiler/Generator Subbituminous Wet 10100221

Coal Steam Boiler/Generator Subbituminous Wall Wet 10100221

Coal Steam Boiler/Generator Subbituminous Vertical Wet 10100221

Coal Steam Boiler/Generator Subbituminous 10100222

Coal Steam Boiler/Generator Subbituminous Dry 10100222

Coal Steam Boiler/Generator Subbituminous Vertical Dry 10100222

Coal Steam Boiler/Generator Subbituminous Wall Dry 10100222

Coal Steam Boiler/Generator Subbituminous Wall 10100222

Coal Steam Boiler/Generator Subbituminous Cyclone Dry 10100223

Coal Steam Boiler/Generator Subbituminous Cyclone Wet 10100223

Coal Steam Boiler/Generator Subbituminous Cyclone 10100223

Coal Steam Boiler/Generator Subbituminous Stoker/SPR 10100224

Coal Steam Boiler/Generator Subbituminous Stoker/SPR Wet 10100224

Coal Steam Boiler/Generator Subbituminous Stoker/SPR Dry 10100224

Coal Steam Boiler/Generator Subbituminous Tangential Wet 10100226

Coal Steam Boiler/Generator Subbituminous Tangential Dry 10100226

Coal Steam Boiler/Generator Subbituminous Cell Wet 10100235

Coal Steam Boiler/Generator Subbituminous Cell Dry 10100235

Coal Steam Boiler/Generator Subbituminous Cell 10100235

Coal Steam Boiler/Generator Subbituminous FBC Dry 10100238

Coal Steam Boiler/Generator Subbituminous FBC Wet 10100238

Coal Steam Boiler/Generator Subbituminous FBC 10100238

Coal Steam Boiler/Generator Lignite Wall Dry 10100301

Coal Steam Boiler/Generator Lignite Wet 10100301

Coal Steam Boiler/Generator Lignite Tangential Wet 10100302

Coal Steam Boiler/Generator Lignite Tangential Dry 10100302

Coal Steam Boiler/Generator Lignite Cyclone 10100303

Coal Steam Boiler/Generator Lignite Cyclone Wet 10100303

Coal Steam Boiler/Generator Lignite Stoker/SPR Wet 10100306

Coal Steam Boiler/Generator Lignite Stoker/SPR 10100306

Coal Steam Boiler/Generator Lignite Stoker/SPR Dry 101003068 Plant Type Boiler / Generator Fuel Type / Coal Rank Firing Bottom SCC

Coal Steam Boiler/Generator Lignite FBC 10100318

Coal Steam Boiler/Generator Lignite FBC Wet 10100318

Coal Steam Boiler/Generator Lignite FBC Dry 10100318

O/G Steam Boiler/Generator Oil 10100401

O/G Steam Boiler/Generator Oil Wall Dry 10100401

O/G Steam Boiler/Generator Oil Tangential 10100404

O/G Steam Orimulsion Wall 10100409

O/G Steam Orimulsion Other 10100409

O/G Steam Boiler/Generator Natural Gas 10100601

O/G Steam Boiler/Generator Natural Gas Wall 10100601

O/G Steam Boiler/Generator Natural Gas Wall Dry 10100601

O/G Steam Natural Gas Wall Wet 10100601

O/G Steam Natural Gas Vertical Dry 10100601

O/G Steam Natural Gas Vertical 10100601

O/G Steam

_ Natural Gas Cell

_ 10100601

O/G Steam Natural Gas Cyclone Dry 10100601

O/G Steam Natural Gas Cyclone Wet 10100601

O/G Steam Natural Gas Cyclone 10100601

O/G Steam Natural Gas Other Dry 10100601

O/G Steam Natural Gas Tangential Dry 10100604

O/G Steam Natural Gas Tangential Wet 10100604

O/G Steam Boiler/Generator Natural Gas Tangential 10100604

Fossil Waste Boiler Process Gas 10100701

Coal Steam Boiler/Generator Petroleum Coke Vertical Dry 10100801

Coal Steam Petroleum Coke Wall 10100801

Coal Steam Boiler/Generator Petroleum Coke 10100801

Coal Steam Boiler/Generator Petroleum Coke FBC Dry 10100818

Coal Steam Boiler/Generator Biomass 10100902

Coal Steam Boiler/Generator Waste Coal 10102001

Coal Steam Boiler/Generator Waste Coal Wall 10102001

Coal Steam Boiler/Generator Waste Coal FBC 10102018

Combined

Cycle Generator Oil 20100101

Combustion

Turbine Boiler/Generator Oil 20100101

Combined

Cycle Boiler/Generator Natural Gas 20100201

Combined

Cycle Natural Gas 20100201

Combustion

Turbine Boiler/Generator Natural Gas 20100201

Fossil Waste Generator Process Gas 20100201

IGCC Boiler/Generator 201003019 2. Assign existing and retrofit units’ state FIPS codes, county FIPS code s , plant ID s , point ID s and

segment ID s

The units’ s tate FIPS codes, co unty FIPS code s , p lant IDs, point IDs, and s egment IDs are
assigned from the NEI unit

- specific data file

, NEI

. Where the NEI provides no data, default

values are used

. Appendix A describes the default value s in detail.

III

. A ssign stack ID s and parameters and latitude

- longitude/county centroid coordinates for all

units

1. Assign s tack ID and p arameters for all u nits

i. Existing and retrofit units’ stack ID s are assigned from the NEI data file. If the NEI data file

provides no stack ID data, default stack ID s are assigned as follows:

a. The u nits are first sorted by ORIS c ode and u nit ID in alphanumeric order.

b. D efault stack ID s are then assigned, starting with “41” and incrementing for the rest

of the units that do not have NEI stack ID s within the same ORIS Code

.

c. All generic units are assigned default stack IDs.

ii. Existing and retrofit unit’s stack parameters are assigned based on the hierarchy described in

Flow Chart 4

.

Flow Chart 4. Stack Parameters Assignment Hierarchy

Existing and retrofit units’ s tack parameters are first assigned based on a unit’s plant type as

shown in Table 7

.

Table 7

. Plant Type

- Based Stack Parameters

Plant Type Stack Height

(ft) Stack Diameter

(ft) Stack Temperature

(degree F) Stack Velocity

(ft/sec) Stack Flow

(cft/sec)

IGCC 150 19 340 75.8 21491.48

If Table 7 provides no plant type

- based stack parameters, the units are assigned NEI stack

parameters from the NEI

.

W here the NEI data file provides no stack parameter s

, the units are assigned default stack

parameters based on a unit’s SCC as shown in Table 8

. Plant Type

- Based Stack Parameters

NEI Stack Parameters

SCC

- Based Default Stack Parameters10 Table 8. SCC

- Based Default Stack Parameters

SCC Stack

Height

(ft) Stack

Diameter

(ft) Stack

Temperature

(oF) Stack

Velocity

(ft/sec)

10100201 603.2 19.8 281.2 076.5

10100202 509.7 14.6 226.0 062.0

10100203 491.6 16.6 278.4 080.5

10100204 225.0 00.6 067.2 002.4

10100211 490.0 17.4 280.0 076.4

10100212 445.6 17.4 275.2 077.6

10100215 509.7 14.6 226.0 062.0

10100218 399.3 10.8 245.6 040.1

10100221 983.0 22.8 350.0 110.0

10100222 468.5 16.0 254.7 065.6

10100223 446.8 15.9 308.0 093.6

10100224 255.5 10.0 251.3 015.3

10100226 495.8 18.9 259.2 091.2

10100235 468.5 16.0 254.7 065.6

10100238 600.0 22.5 315.0 078.0

10100301 427.5 22.3 232.8 074.2

10100302 483.5 21.0 229.4 092.4

10100303 462.0 21.7 271.3 072.5

10100306 300.0 07.2 441.0 067.0

10100318 326.7 12.3 326.7 074.7

10100401 252.9 10.1 258.1 042.6

10100404 322.1 14.0 301.8 062.8

10100409 252.9 10.1 258.1 042.6

10100601 263.9 10.3 236.0 046.9

10100604 308.0 15.2 275.2 066.0

10100701 239.2 09.4 238.0 042.3

10100801 371.3 05.5 122.4 020.4

10100818 399.3 10.8 245.6 040.1

10100902 303.4 03.3 137.7 016.1

10102001 509.7 14.6 226.0 062.0

10102018 399.3 10.8 245.6 040.1

20100101 057.7 09.6 655.8 064.9

20100201 062.0 10.0 585.3 061.3

20100301 150.0 19.0 340.0 075.8

iii. G eneric units are assigned SCC

- based default stack parameters.

iv. All units’ stack flows are assigned from the NEI data file , except f or IGCC units which receive

default stack flow by plant type as shown in Table 7. Where the NEI data file provides no stack

flow data, stack flows are calculated as follows:11 

### ) (ft/sec Velocity Stack *

2 (ft) Diameter Stack

* 3.141592 (cft/sec) Flow Stack 2 

###  ** **  ** **  ****

**=**

2. Assign latitude

- l ongitude c oordinates

L atitude

- longitude coordinates are assigned from the NEI data file. If the NEI data file provides

no data

, latitude

- longitude /county centroid coordinates are assigned based on a unit’s sister

ORIS code from the file LatLonDefault.

I V

. C alculate CO, NO

x , VOC, SO 2 , NH 3 , primary PM 10 , primary PM 2.5 and mercury (Hg) emissions for all

units

Emissions are calculated at three levels: annual, season al and average day emissions.

1. A nnual emission calculations

i. Annual NO

x , SO 2 and m ercury ( H g) emissions (tons) are taken directly from IPM run results . Coal units’

ann ual m ercury emissions are separated into elemental, ionic and particulate species as follows:



### = ) ( tons Emissions Annual

Species Mercuy

Species Mercury Mercury 

### Fraction Emission Annual *

Where Species Mercury 

### Fraction are mercury speciation fraction s for elemental, ionic and particulate

.
The hierarchy for the assignment of mercury speciation fractions is shown in Flow Chart 5

. This

hierarchy

, in conjunction with the mapping from Table 9

, determines the assignment of

associated speciation fractions.12 Flow Chart 5

. Mercury Speciation Fraction Assignment Hierarchy

1. Plant Type (Coal Steam, Coal

Gasification (IGCC))

2. Coal Rank (Bituminous, Subbituminous,

Lignite, Waste Coal, Petroleum Coke)

3. Fluidized Bed Combustion (FBC) Firing

Type

4. SO 2 Control (Wet Scrubber (FGD), Dry

Scrubber (FGD))

5. Spray Dry Absorber (SDA)/Fabric Filter

(FF) Baghouse Particulate Control

6. ESP (Cold

- Side (CS), Hot Side (CS))

Particulate Control

7. NO

x Control (SCR, SNCR, Other Post

Combustion Control such as Cyclone,

Mechanical Collector)

8. Particulate Matter (PM) Scrubber

9. Boiler/Burner Type (Cyclone, Pulverized

Coal (PC), Stoker)13 Table 9 : Mercury Speciation Fractions

Category Particulate Ionic Elemental

Bituminous Coal and Pet. Coke, PC Boiler with ESP

- CS 0.0117 0.4656 0.5227

Bituminous Coal, Coal Gasification 0.0051 0.0847 0.9102

Bituminous Coal, PC Boiler with Dry Sorbent Injection and ESP

- CS 0.0016 0.6710 0.3274

Bituminous Coal, PC Boiler with ESP

- CS 0.0611 0.6820 0.2570

Bituminous Coal, PC Boiler with ESP

- CS and Wet FGD 0.0022 0.0778 0.9200

Bituminous Coal, PC Boiler with ESP

- HS 0.0490 0.5784 0.3726

Bituminous Coal, PC Boiler with ESP

- HS and Wet FGD 0.0063 0.2068 0.7870

Bituminous Coal, PC Boiler with FF Baghouse 0.0398 0.6258 0.3344

Bituminous Coal, PC Boiler with FF Baghouse and Wet FGD 0.0648 0.3300 0.6052

Bituminous Coal, PC Boiler with PM Scrubber 0.0180 0.1951 0.7869

Bituminous Coal, PC Boiler with SCR and SDA/FF Baghouse 0.0506 0.4604 0.4890

Bituminous Coal, PC Boiler with SDA/FF Baghouse 0.0917 0.2886 0.6197

Bituminous Coal, PC Boiler with SNCR and ESP

- CS 0.2032 0.2712 0.5256

Bituminous Coal, Stoker Boiler with SDA/FF Baghouse 0.1996 0.1794 0.6211

Bituminous Coal/Pet. Coke, Cyclone with ESP

- CS and Wet FGD 0.0007 0.1130 0.8863

Bituminous Coal/Pet. Coke, PC Boiler with FF Baghouse 0.0220 0.7841 0.1939

Bituminous Coal/Pet.Coke , Fluidized Bed Combustor with SNCR and FF

Baghouse 0.4244 0.2787 0.2970

Bituminous Waste, Fluidized Bed Combustor with FF Baghouse 0.0212 0.3881 0.5907

Lignite Coal, Cyclone Boiler with ESP

- CS 0.0004 0.1699 0.8297

Lignite Coal, Cyclone Boiler with SDA/FF Baghouse 0.0995 0.1707 0.7298

Lignite Coal, Fluidized Bed Combustor with ESP

- CS 0.0137 0.1164 0.8700

Lignite Coal, Fluidized Bed Combustor with FF Baghouse 0.0042 0.7118 0.2840

Lignite Coal, PC Boiler with ESP

- CS 0.0009 0.0362 0.9629

Lignite Coal, PC Boiler with ESP

- CS and FF Baghouse 0.0019 0.6449 0.3532

Lignite Coal, PC Boiler with ESP

- CS and Wet FGD 0.0082 0.1345 0.8574

Lignite Coal, PC Boiler with PM Scrubber 0.0016 0.0298 0.9686

Lignite Coal, PC Boiler with SDA/FF Baghouse 0.0036 0.1262 0.8702

Subbituminous Coal, Fluidized Bed Combustor with SNCR and FF

Baghouse 0.0027 0.0342 0.9632

Subbituminous Coal, Fluidized Bed Combustor 0.061 1 0.68 20 0.25 70

Subbituminous Coal, PC Boiler with ESP

- CS 0.0016 0.3083 0.6901

Subbituminous Coal, PC Boiler with ESP

- CS and Wet FGD 0.0043 0.0294 0.9663

Subbituminous Coal, PC Boiler with ESP

- HS 0.0006 0.1252 0.8741

Subbituminous Coal, PC Boiler with ESP

- HS and Wet FGD 0.0117 0.0446 0.9437

Subbituminous Coal, PC Boiler with FF Baghouse 0.0149 0.8283 0.1568

Subbituminous Coal, PC Boiler with PM Scrubber 0.0145 0.0511 0.9344

Subbituminous Coal, PC Boiler with SDA/ESP 0.0032 0.0382 0.9586

Subbituminous Coal, PC Boiler with SDA/FF Baghouse 0.0099 0.0435 0.9467

Subbituminous Coal/Pet. Coke, Cyclone Boiler with ESP

- HS 0.0093 0.0752 0.915514 ii. Annual CO, VOC and NH 3 emissions (tons) are calculated by multiplying the unit’s fuel use and

uncontrolled emission factor s for CO, VOC and NH 3 as follows:



### = (tons) Emissions Annual

Pollutant



### ton) (lb 2000 f) gallon,MMc (lb/ton,k Factor Emission * f) gallon,MMc (ton,k Use Fuel Annual

Pollutant



### / **− −** 

W here :



### 2000 converts lb to short ton and the pollutants are CO, VOC, and NH 3

.



### )

, , ( MMcf gallon k ton Use Fuel Annual

**−** is calculated from IPM run results

, which are in

MMBtu of annual heat input and converted into physical units of annual fuel use as follows:



### =

**−** )

, , ( MMcf gallon k ton Use Fuel



### )

, , / ( ) (

MMcf gallon k ton MMBtu Content Heat MMBtu Input Heat

**−**

Where 

### )

, , / ( MMcf gallon k ton MMBtu Content Heat

**−** is assigned using EPA Base

Case 4.10 Final assumptions for coal and petroleum coke units. All other units are

assigned default heat contents based on the unit’s SCC as shown in Table 10

.

Table 10 : SCC

- Based Default Heat Content

(MMBtu/ton, K

- gallon, MMcft)

SCC Heat Content

10100401 0152

10100404 0152

10100409 0152

10100601 1024

10100604 1024

10100701 0671

10100902 0012

20100101 0138

20100201 1024



### f) gallon,MMc (lb/ton,k Factor edEmission Uncontroll

Pollutant 

### − is assigned for CO, VOC, NH 3

based on a unit’s SCC as shown in Table 1 1

.15 Table 1 1 : SCC

- Based Emission Factors

(lbs/ton, k

- gal, MMcft)

SCC CO

EF VOC

EF NH 3 EF Filterable PM 10 EF Filterable PM 2.5 EF PM Flag 1

10100201 00.50 00.04 00.03 02.60 01.48 A

10100202 00.50 00.06 00.03 02.30 00.60 A

10100203 00.50 00.11 00.03 00.26 00.11 A

10100204 05.00 00.05 00.03 13.20 04.60

10100211 00.50 00.04 00.03 02.60 01.48 A

10100212 00.50 00.06 00.03 02.30 00.60 A

10100215 00.50 00.06 00.03 02.30 00.60 A

10100218 18.00 00.05 00.03 12.40 01.36

10100221 00.50 00.04 00.03 02.60 01.48 A

10100222 00.50 00.06 00.03 02.30 00.60 A

10100223 00.50 00.11 00.03 00.26 00.11 A

10100224 05.00 00.05 00.03 13.20 04.60

10100226 00.50 00.06 00.03 02.30 00.60 A

10100235 00.50 00.06 00.03 02.30 00.60 A

10100238 18.00 00.05 00.03 16.10 04.20

10100301 00.25 00.07 00.03 01.80 00.52 A

10100302 00.60 00.07 00.03 02.30 00.66 A

10100303 00.60 00.07 00.03 00.87 00.37 A

10100306 05.00 00.07 00.03 01.60 00.56 A

10100318 00.15 00.03 00.03 12.00 01.40

10100401 05.00 00.76 00.80 2 3

10100404 05.00 00.76 00.80 2 3

10100409 05.00 00.76 00.80 2 3

10100601 84.00 05.50 03.20 4 4

10100604 24.00 05.50 03.20 4 4

10100701 06.57 00.43 01.20 4 4

10100801 00.60 00.07 00.40 07.90 04.50 A

10100818 18.00 00.05 00.40 12.40 01.36

10100902 06.80 00.19 00.09 05.70 04.90

10102001 00.25 00.07 00.03 01.82 00.52 A

10102018 00.15 00.03 00.03 12.00 01.40

20100101 00.46 00.06 06.62 00.60 00.60

20100201 84.00 02.10 06.56 4 4

20100301 35.00 02.20 06.56 4 4

1 Multiply ash content % (A) by the PM EF numeric value to obtain the EF.

2 Filterable PM 10 EF = 5.9 * (1.12 * S + 0.37), where S=sulfur content %.

3 Filterable PM 2.5 EF = 4.3 * (1.12 * S + 0.37), where S=sulfur content %.

4 There are no EF for these SCC because of uncertainty due to an artifact of the test method used in the past.16 SCC CO

EF VOC

EF NH 3 EF Filterable PM 10 EF Filterable PM 2.5
EF PM Flag 1

PM 10 and PM 2.5 primary are calculated directly from their EF (see Table 16).

i i i. Annual primary PM 10 and PM 2.5 emissions (tons) are calculated for all but gas

- fired and IGCC units by adding

the filterable PM 10 and filterable PM 2.5 emissions to condensable PM emissions

. Filterable PM 10 and PM 2.5 emissions for each unit are based on historical information regarding existing emissions controls and types of fuel

burned and ash content of the fuel burned, as well as the projected emission controls (e.g., scrubbers and fabric

filters). Condensable PM emissions are based on plant type, sulfur content of the fuel, and 

### SO 2 /HCl and PM

control configurations. Although EPA’s analysis is based on the best available emission factors, these emission

factors do not account for the potential changes in condensable PM emissions due to the installation and

operation of SCRs. The formation o f additional condensable PM (in the form of 

### SO 3 and H 2 SO 4 ) in units with

SCRs depends on a number of factors, including coal sulfur content, combustion conditions and characteristics of

the catalyst used in the SCR, and is likely to vary widely from unit t o unit. SCRs are generally designed and

operated to minimize increases in condensable PM. This limitation means that condensable PM emissions are
potentially underestimated for units with SCRs. In contrast, it is possible condensable PM emissions are

o verestimated in a case where the unit is combusting a low

- sulfur coal in the presence of a scrubber.



### = ) ( tons Emission Annual

10 PM Primary 

# ( **)** ) ( ) (

10 

### tons Emission Annual tons Emission Annual

e Condensabl PM PM Filterable 

### +

**=** ) ( tons Emission Annual

2.5 PM Primary 

# ( **)** ) ( ) (

5

. 2 

### tons Emission Annual tons Emission Annual

e Condensabl PM PM Filterable 

### +

Where :



### = ) (

10 

### tons Emission Annual

PM Filterable



###  ****

** ** 

** ** 

** ** 

**− −** 

) / ( 2000 )

, , / ( * )

, , (

10



### ton lb MMcf gallon k ton lb Factor Emission MMcf gallon k ton Use Fuel

PM Filterable



###  ****

** ** 

** ** 

** ** 

**−** 100

1 * 10 PM 

### Efficiency Control Filterable 

# ( **)** (%) * Content Ash



### = ) (

5

. 2 

### tons Emission Annual

PM Filterable



###  ** **  ** **  ** **  ****

**− −** 

) / ( 2000 )

, , / ( * )

, , (

5

. 2



### ton lb MMcf gallon k ton lb Factor Emission MMcf gallon k ton Use Fuel

PM Filterable17 

###  ****

** ** 

** ** 

** ** 

**−** 100

1 * 5

. 2 PM 

### Efficiency Control Filterable 

# ( **)** (%) * Content Ash

If 

### ) (

5

. 2 

### tons Emission Annual

PM Filterable 

### is greater than 

### ) (

10 

### tons Emission Annual

PM Filterable 

### ,



### ) (

5

. 2 

### tons Emission Annual

PM Filterable 

### is set equal to 

### ) (

10 

### tons Emission Annual

PM Filterable 

### .



### ) / ( 2000 ) / ( * ) (

ton lb MMBtu lb Factor Emission MMBtu Input Heat Annual

e Condensabl PM

W here :



### 2000 converts lb to short ton and the pollutants are CO, VOC, and NH 3

.

10 PM 

### Efficiency Control Filterable and

5

. 2 PM 

### Efficiency Control Filterable are assigned based

on a unit’s ORIS code, unit ID, plant type and fuel type from the data file PMSulfurAshContent.

Where PMSulfurAshContent provides no data, default values based on a unit’s plant type and

fuel type and coal rank as shown in Table 12 are used.

Table 12: Default PM Control Efficiencies and Sulfur and Ash Contents

Plant Type Fuel Type /

Coal Rank Filterable

PM 10 Control

Efficiency (%) Filterable

PM 2.5 Control

Efficiency (%) Sulfur

Content

(%) Ash

Content

(%)

Biomass Biomass 99.2 99.2

Coal Steam Bituminous 99.2 99.2 1.67 10.8

Coal Steam Subbituminous 99.2 99.2 0.32 05.6

Coal Steam Lignite 99.2 99.2 0.87 13.9

Coal Steam Petroleum Coke 99.2 99.2 5.30 00.1

Coal Steam Waste Coal 99.2 99.2 2.38 43.7

Coal Steam Biomass 99.2 99.2 1.67 10.8

IGCC Bituminous 1.67 10.8

IGCC Subbituminous 0.32 05.6

IGCC Lignite 0.87 13.9

IGCC Petroleum Coke 5.30 00.1

O/G Steam Oil 99.2 99.2 0.89 00.0

O/G Steam Orimulsion 99.2 99.2 0.89 00.0

Combustion

Turbine Oil 0.11 00.0

Combined Cycle Oil 0.11 00.0 

### = ) ( tons Emission Annual

e Condensabl PM18 

### ) / ( ) / (

2 

### MMBtu lb Content Ash and MMBtu lb Content SO are assigned using EPA Base

Case v4.10 assumptions. The EPA Base Case v4. 1 0 SO 2 and ash contents are in lb/ MMBtu and

converted into percentage

- of

- fuel sulfur and ash contents as follows:

i

. Sulfur content conversion

If fuel type is coal, waste coal or petroleum coke :



### = (%) Content Sulfur



### 100 * ) / ( 2000 * 2 ) / ( * ) / (

2



### ton lb ton MMBtu Content Heat MMBtu lb Content SO

where 2000 converts lb to short ton.

If fuel type is oil:



### = (%) Content Sulfur



### 100 * ) / ( 7882 * 2 ) / ( * ) / (

2 

### gallon k lb gallon k MMBtu Content Heat MMBtu lb Content SO

**− −** 

where 7882 converts lb to k

- gallon of oil.

If fuel type is fossil waste and the unit uses process gas SCC “101007”:



### = (%) Content Sulfur



### 100 * ) / ( 52794 * 2 ) / ( * ) / (

2 

### MMcf lb MMcf MMBtu Content Heat MMBtu lb Content SO

where 52794 converts lb to MMcf of fossil waste 2

.

If fuel type is fossil waste and the unit uses natural gas SCC "201002":



### = (%) Content Sulfur



### 100 * ) / ( 44000 * 2 ) / ( * ) / (

2 

### MMcf lb MMcf MMBtu Content Heat MMBtu lb Content SO

where 44000 converts lb to MMcf of natural gas.

No sulfur content conversion is performed for natural gas as the sulfur content for natural

gas is assumed to be zero.

ii. Ash content conversion for coal

2 Fossil waste using process gas SCC is assumed to be a combination of coke

- oven gas and blast

- furnace gas.19 

### = (%) Content Ash



### 100 *

2000 ) / ( * ) / ( ton MMBtu Content Heat MMBtu lb Content Ash

where 2 000 is the number of lb per short ton.

I f no sulfur and ash content assumptions from EPA Base Case 4.10 are available, default values based

on a unit’s ORIS code, unit ID, plant type and fuel type from the data file PMSulfurAshContent are used

first ; default values based on plant type and coal rank in Table 12 are used second. This hierarchy is

s ummarized in Flow Chart 6

.

Flow Chart 6

. Sulfur and Ash Contents Assignment Hierarchy



### ) / ( MMBtu lb Factor Emission

e Condensabl PM is assigned for all units based on units’

SCCs and whether they have either a n SO 2 control or PM scrubber installed as shown in

Table 1 3

.

Table 1 3 : SCC

- Based PM Condensable Emission Factors

(lbs/MMBtu)

SCC SO 2 Control 1 PM Control 1 PM Condensable EF 2

10100201 Wet Scrubber PM Scrubber 0.0200

10100201 Dry Scrubber PM Scrubber 0.0200

10100202 Wet Scrubber PM Scrubber 0.0200

10100202 Dry Scrubber PM Scrubber 0.0200

10100203 Wet Scrubber PM Scrubber 0.0200

10100203 Dry Scrubber PM Scrubber 0.0200

10100204 0.0400 1. EPA Base Case v4.10 Final SO 2 and

ash content (lb/MMBtu) assumptions,

converted into percentage

- of

- fuel sulfur

and ash contents

2. Default percentage

- of

- fuel sulfur and

ash contents by ORIS code, unit ID, plant

type and fuel type

3. Default percentage

- of

- fuel sulfur and

ash contents by plant type and fuel rank20 SCC SO 2 Control 1 PM Control 1 PM Condensable EF 2

10100211 Wet Scrubber PM Scrubber 0.0200

10100211 Dry Scrubber PM Scrubber 0.0200

10100212 Wet Scrubber PM Scrubber 0.0200

10100212 Dry Scrubber PM Scrubber 0.0200

10100215 Wet Scrubber PM Scrubber 0.0200

10100215 Dry Scrubber PM Scrubber 0.0200

10100218 0.0100

10100221 Wet Scrubber PM Scrubber 0.0200

10100221 Dry Scrubber PM Scrubber 0.0200

10100222 Wet Scrubber PM Scrubber 0.0200

10100222 Dry Scrubber PM Scrubber 0.0200

10100223 Wet Scrubber PM Scrubber 0.0200

10100223 Dry Scrubber PM Scrubber 0.0200

10100224 0.0400

10100226 Wet Scrubber PM Scrubber 0.0200

10100226 Dry Scrubber PM Scrubber 0.0200

10100235 Wet Scrubber PM Scrubber 0.0200

10100235 Dry Scrubber PM Scrubber 0.0200

10100238 0.0100

10100301 Wet Scrubber PM Scrubber 0.0200

10100301 Dry Scrubber PM Scrubber 0.0200

10100302 Wet Scrubber PM Scrubber 0.0200

10100302 Dry Scrubber PM Scrubber 0.0200

10100303 Wet Scrubber PM Scrubber 0.0200

10100303 Dry Scrubber PM Scrubber 0.0200

10100306 0.0400

10100318 0.0100

10100401 0.0100

10100404 0.0100

10100409 0.0100

10100801 0.0100

10100818 0.0100

10100902 0.0170

10102001 Wet Scrubber PM Scrubber 0.0200

10102001 Dry Scrubber PM Scrubber 0.0200

10102018 0.0100

20100101 0.0072

1 For the given SCC, only one of the controls need be present for the EF to be assigned.

In addition, DSI is considered a scrubber for estimating PM emissions.

2 For SCCs that have non

- blank controls for both SO 2 and PM, then EF = (0.1 * S)

- 0.03,

( where S=sulfur content %), but if the EF is less than 0.01, set it equal to 0.01.21 For the SCCs in Table 13 that have non

- blank controls for both SO2 and PM, their PM condensable emission

factor can be calculated. using the equation below:



# ( **)** 03

. 0 (%) * 1

. 0

**− =**  Content Sulfur Factor Emission e Condensabl PM

If the calculated value is less than the floor of 0.01 lb/ MMBtu, then .01 is assigned as the PM condensable

E mission F actor in place of the calculated value.

Also, u nits hav ing a n SO 2 control are assigned the lower of the PM condensable emission factor from Table 13

and the calculated PM condensable emission factor using the above equation.

Primary PM 10 and p rimary PM 2.5 cannot be estimated for gas

- fired units (including IGCCs) using the sa me
methodology as the other fuels sin c e there are no accurate filter able emission factors for them. Thus, their

emission s are estimated di rectly. Primary PM 10 and p rimary PM 2.5 emission factors in lb/MMBtu are assigned

based on each unit’s SCC as shown i n Table 1 4

. .

Table 1 4 : Primary PM 10 and Primary PM 2.5 Emission Factors for Gas

- Fired and IGCC Units

(lb/MMBtu)

SCC Primary PM 10 EF Primary PM 2.5 EF

10100601 0.532 0.440

10100604 0.532 0.440

10100701 0.043 0.035

20100201 0.317 0.195

20100301 11.263 11.263

2

. Season al emission calculations:

Summer is considered to be the 153 days between May 1 and Septem b er 30 inclusive. Summer NO

x emissions

are taken directly from IPM run results. For all other pollutants, summer emissions are calculated by multiplying

the annual emissions by the ratio of the summer to annual heat input.



### * ) ( ) ( tons Emissions Annual tons Emissions Summer

**=** 

###  ****
** ** 
** ** 
** ** 

MMBtu Input Heat Annual MMBtu Input Heat Summer

( ) (

Winter is considered to be the 212 days between October 1 and April 30 inclusive that are not considered to be

summer days. Winter emissions are calculated by subtracting the summer emissions from the annual emissions.



### ) ( ) ( tons Emissions Summer tons Emissions Annual (tons) Emissions Winter

**− =** 

3

. Season al average

- day emission calculations:

Summer average

- day emissions are calculated by dividing the summer emissions by the 153 days in the summer

.



### = ) ( tons Emissions Day Average Summer



### 153 ) ( tons Emissions Summer22 Winter average

- day emissions are calculated by dividing the winter emissions by the 212 days in the winter

.



### = ) ( tons Emissions Day Average Winter



### 212 ) ( tons Emissions Winter

V. P opulate control efficiency percentage (CEFF) and primary control equipment code (CPRI) fields :

1. Control Efficiency Percentage (CEFF) Field :

T he CEFF field for SO 2 , NO

x and elemental, ionic and particulate mercury species is calculated using the

following methodology:

For all existing units:

i ) SO 2 :

a ) 

### =

2 SO 

### CEFF ** ** 

** ** 

** ** 

** ** 

**−** ) / ( ) / ( 1

2 2



### MMBtu lb Rate Emission SO Inlet MMBtu lb Rate Emission SO Outlet



### ∗ 

### 100

Where:



### = ) / (

2 

### MMBtu lb Rate Emission SO Outlet ) ( ) (

2



### MMBtu

Input Heat Annual lbs Emission SO Annual



### theUnit at Consumed Fuel the of MMBtu lb Content SO MMBtu lb Rate Emission SO Inlet

) / ( ) / (

2 2 

### =

b ) W eighted average

2 SO 

### CEFF value , weighting on capacity (MW), is reported when aggregating

ORL records to SCC level.

ii ) E lemental, ionic and particulate mercury species :

a ) 

### = Species Mercury 

### CEFF ** **  ** **  ** **  ** ** 

**−** ) / ( ) / ( 1

TBtu lb Rate Emission Mercury Inlet TBtu lb Rate Emission Mercury Outlet



### ∗ 

### 100

Where:



### = ) / ( TBtu lb Rate Emission Mercury Outlet 

### ) ( ) (

TBtu Input Heat Annual lbs Emission Mercury Annual



### Consumed Fuel the of TBtu lb Content Mercury TBtu lb Rate Emission Mercury Inlet

) / ( ) / (

**=**

b ) W eighted average Species Mercury 

### CEFF value , weighting on c apacity (MW), is reported when

aggregating ORL records to SCC level.

iii ) NO

x :23 1 ) 

### =

x NO Winter 

### CEFF ** ** 

** ** 

** ** 

** ** 

**−** (lb/MMBtu) Rate Emission NO Winter Inlet (lb/MMBtu) Rate Emission NO Winter Outlet

x x 

### 1 

### ∗ 

### 100

Where:



### (MMBtu) Input Heat Winter (lbs) Emission NO Winter (lb/MMBtu) Rate Emission NO Winter Outlet

x x 

### =



### (lb/MMBtu) Rate NO NEEDS Winter (lb/MMBtu) Rate Emission NO Winter Inlet

x x 

### = 3

2 ) 

### =

x NO Summer 

### CEFF ** ** 

** ** 

** ** 

** ** 

**−** ) / ( ) / ( 1

MMBtu lb Rate Emission NO Summer Inlet MMBtu lb Rate Emission NO Summer Outlet

x x 

### ∗ 

### 100

Where:



### ) ( ) ( ) / (

MMBtu Input Heat Summer lbs Emission NO Summer MMBtu lb Rate Emission NO Summer Outlet

x x 

### =



### ) / ( ) / (

MMBtu lb Rate NO NEEDS Summer MMBtu lb Rate Emission NO Summer Inlet

x x 

### =

4

3 ) 

### =

x NO 

### CEFF 

# ( **)**

x x SummerNO WinterNO 

### CEFF

, CEFF Max

The

x NO 

### CEFF is used in both w inter and s ummer ORL files.

4 ) W eighted average

x NO 

### CEFF value , weighting on c apacity (MW), is reported when

aggregating ORL records to SCC level. If the SCC aggregate has no primary control

equipment code (CPRI), no

x NO 

### CEFF value is repor ted , unless any portion of the SCC

aggregate has a NO

x control equipment.

If the calculated SO 2 , NO

x or m ercury species CEFF value is less than one percent, no CEFF value is

reported . Also, no CEFF value is reported for repowering units.

For all generic units:

All generic units have default 

### CEFF value by plant type as described in T able 1 5 :

3 The 

### ) / ( MMBtu lb Rate NO NEEDS Winter

x is without post

- comb ustion control removal.

4 The 

### ) / ( MMBtu lb Rate NO NEEDS Summer

x is without post

- combustion control removal.24 Table 1 5

. Default 

### CEFF by Plant Type

Plant Type Default

2 SO 

### CEFF Value Default

Species Mercury 

### CEFF Value Default

x NO 

### CEFF Value

Conventional

Pulverized Coal 90% 90% 90%

Integrated

Gasification

Combined Cycle 99% 90% 90%

2. Primary Control Equipment Code (CPRI) Field:

For all e xisting u nits:

The CPRI field for existing units is populated in two steps:

i. CPRI value is assigned based on the final post

- combustion control information, i.e. accounting for both

existing and retrofit investment post

- combustion c ontrol(s) installed at the unit as shown in Table 1 6

.

Table 1 6

. CPRI by Pollutant and P ost

- Combustion Control

Pollutant Post

- Combustion Control CPRI (1)

NO

x SCR 0001

NO

x SNCR or other Post Combustion NO

x control 0002

SO 2 Wet Scrubber 0003

SO 2 Dry Scrubber 0004

SO 2 Wet or Dry Scrubber (2 ) 0005

Hg Activated Carbon Injection 0006

NO

x , SO 2 , Hg Repowering 0007

(1) If no emission control information is available, no CPRI value is reported

. (2) Used for g eneric units only.

ii. Simp le

- majority rule

, based on capacity (MW)

, is applied to select dominant CPRI value when

aggregating ORL records to SCC level.

For all g eneric u nits:

All generic units have default CPRI value by plant type as described in T able 1 7 :

Table 1 7

. Default CPRI by Plant Type for Generic Units

Plant Type NO

x CPRI SO 2 CPRI Mercury CPRI

Conventional

Pulverized Coal 0001 0005

Integrated Gasification

Combined Cycle 0001

Combined Cycle 000125 SECTION I V : ORL

- F ORMATTED FILES LAYOUT :

The processed data are then converted into two ORL

- formatted files, one for summer and one for winter, for U.S.

EPA to use in air quality modeling framework

. Both winter and summer ORL

- formatted file s contain annual

emissions and they each contain their r espective seasonal average day emission s

.

Both c riteria and HAP emissions are provided in the same file. The pollutants are provided in the following order:

CO, NO

x , VOC, SO 2 , NH 3 , primary PM 10 , primary PM 2.5 , 200 ( e lem ental mercury ), 201 (ionic mercury ) and 202

(particulate mercury ).

The f ile s’ naming convention is as follows:

PTINV_<ipm run and winter/summer alpha

- numeric only>_<year4>_<date created using

ddmmmyyyy>_ORL.txt

where:

year4 = 4

- digit year of the emissions (e.g., 20 30 )

dd = 2

- digit date number (e.g., 01 through 31)

mmm = 3

- char lowercase month (jan, feb, mar, apr, may, jun, jul, aug, sep, oct, nov, dec)

yyyy = 4

- digit year

F or example : 'PTINV_ EPA 410

_ Final _BC_42l_summer_ 20 3 0 _12DEC 20 1 0_ORL.txt ’

.

All data fields are comma

- delimited and c haracter data, i ncluding comma, semi

- colon and space, are enclosed in

double

- quotes.

Each file contains the following h eader line s :

#ORL

#TYPE Point Source Inventory for CAPS and Mercury

#COUNTRY US

#YEAR <year of emissions>

#DESC Annu al and Summer Average Day

#DESC US excluding AK and HI, not including PR nor VI

#DESC For some sources, these data have multiple entries that

#DESC appear to be "duplicates", but are not. These entries have

#DESC the same source IDs across all entries, but different emissions.

#DESC To use this data properly in SMOKE, the run script should use

#DESC the setting RAW_DUP_CHECK = N. This setting will cause SMOKE

#DESC to provide a warning about "duplicate records" and sum the

#DESC emissions to create a sin gle SMOKE source.

#DESC <IPM run name>

#DESC FIPS,PLANTID,POINTID,STACKID,SEGMENT,PLANT,SCC,ERPTYPE,SRCTYPE,

STKHGT,STKDIAM,STKTEMP,STKFLOW,STKVEL,SIC,MACT,NAICS,CTYPE,XLOC,YLOC,

UTMZ,POLCODE,ANN_EMIS,AVD_EMIS,CEFF,REFF,CPRI,CSEC,NEI_UNIQUE_ID,

ORIS_FACILITY_CODE,ORIS_BOILER_ID,IPM_YN,DATA_SOURCE,STACK_DEFAULT_FLAG,LOCATION_DE

FAULT_FLAG,YEAR,TRIBAL_CODE,HORIZONTAL_AREA_F UGITIVE,

RELEASE_HEIGHT_FUGITIVE

The last header line contains comma

- delimited field names identifying the data contained in ea ch data field

. The

f ield name, description, type and length of each data field are described in Appen dix B

.26 Appendix A

Default Values

Field Name Description Default Value

FIPS FIPS code for state and county N/A

PLANTID State Plant Identification Code Concatenation of "ORIS" and

NEEDS ORIS Code

POINTID Point Identification Code NEEDS Unit ID

STACKID Stack Identification Code Start with “41” and increment for

the rest of the units that do not

have NEI stack ID s within the

same ORIS Code

SEGMENT SEGMENT ID "1"

PLANT Plant Name N/A

SCC Source Classification Code N/A

ERPTYPE Emissions release point type; indicates type of

stack: 01 = fugitive, 02 = vertical stack, 03 =

horizontal stack, 04 = goose neck, 05 =

vertical with rain cap, 06 = downward

- facing

vent "02"

SRCTYPE Source type; 01 = major, 02 = Section 112

area source, 03 = non

- road source "01"

STKHGT Stack Height (ft) SCC

- based default stack

parameters from

SCCDefaultStackParameters file.

STKDIAM Stack Diameter (ft) SCC

- based default stack

parameters from

SCCDefaultStackParameters file.

STKTEMP Stack Gas Exit Temperature (°F) SCC

- based default stack

parameters from

SCCDefaultStackParameters file.

STKFLOW Stack Gas Flow Rate (cft/sec) SCC

- based default stack

parameters from

SCCDefaultStackParameters file.

STKVEL Stack Gas Exit Velocity (ft/sec) SCC

- based default stack

parameters from

SCCDefaultStackParameters file.

SIC Standard Industrial Classification Code "4911"

MACT Maximum Achievable Control Technology

Code which identifies a source categories

defined by Maximum Achievable Control

Technology rules or rules that are done under

other programs such as Section 129 standards Blank

NAICS North American Industrial Classification

System Code "22"27 Field Name Description Default Value

CTYPE Coordinate system type; U = Universal

Transverse Mercator ; L = Latitude/longitude "L"

XLOC X location, If CTYPE = U, Easting value

(meters); If CTYPE = L, Longitude (decimal

degrees) County

- centroid based longitude

by ORIS code, state FIPS code

and country FIPS code from

LatLonDefault file.

YLOC Y location, If CTYPE = U, Northing value

(meters), If CTYPE = L, Latitude (decimal

degrees) County

- centroid based latitude

by ORIS code, state FIPS code

and country FIPS code from

LatLonDefault file.

UTMZ UTM zone (required if CTYPE = U) Blank

POLCODE Code representing the pollutant contained in

the inventory N/A

ANN_EMIS Annual Emissions (ton/year) N/A

AVD_EMIS Average

- day Emissions (ton/average day) N/A

CEFF Control Efficiency percentage (give value of 0

- 100) Blank

REFF Rule Effectiveness percentage (give value of

0

- 100) 100

CPRI Primary Control Equipment Code Blank

CSEC Secondary Control Equipment Code Blank

NEI_UNIQUE_ID Unique ID that ties together HAP and CAP

emissions within a common facility ID, and ties

together emissions obtained from multiple data

sources (e.g., TRI, State, ESD) which may

have different state facility identifiers but really

belong to a single facility Blank

ORIS_FACILITY_CODE ORIS code matching with the 200 5 NEI ORL

CAP corresponding ID NEEDS ORIS Code

ORIS_BOILER_ID Boiler ID matching with the 200 5 NEI ORL

CAP corresponding ID in relation to above ID NEEDS Boiler ID

IPM_YN Y or N single character flag indicating whether

the point source belongs in the IPM sector "Y"

DATA_SOURCE Flag indicating the source of the data (e.g.,

state

- submitted, toxics release inventory,

Clean Air Markets Division, etc.) "IPM"

STACK_DEFAULT_FLAG Flag indicating how NEI defaulted stack

parameters Blank

LOCATION_DEFAULT_FLAG Flag indicating how NEI defaulted locations Blank

YEAR Year of emissions 4

- digit year of the emissions

TRIBAL_CODE Indicates the particular tribe that submitted the

data Blank

HORIZONTAL_AREA_FUGITIVE Related to AXLEN, AYLEN which are optional

parameters for ISCST3/AERMOD Blank

RELEASE_HEIGHT_FUGITIVE Related to optional parameters for

ISCST3/AERMOD Blank28 Appendix B

ORL

- F ormatted Files Layout

F ield Name D escription T ype and Length

FIPS FIPS code for state and county Character (5)

PLANTID State Plant Identification Code Character (15)

POINTID Point Identification Code Character (6)

STACKID Stack Identification Code Character (6)

SEGMENT SEGMENT ID Character (6)

PLANT Plant Name Character (80)

SCC Source Classification Code Character (10)

ERPTYPE Emissions release point type; indicates type of stack:

01 = fugitive, 02 = vertical stack, 03 = horizontal stack,

04 = goose neck, 05 = vertical with rain cap, 06 =

downward

- facing vent Character (2)

SRCTYPE Source type; 01 = major, 02 = s ection 112 area source,

03

= non

- road source Character (2)

STKHGT Stack Height (ft) Number (10)

STKDIAM Stack Diameter (ft) Number (10,2)

STKTEMP Stack Gas Exit Temperature (°F) Number (10)

STKFLOW Stack Gas Flow Rate ( cft /sec) Number (10,2)

STKVEL Stack Gas Exit Velocity (ft/sec) Number (10,2)

SIC Standard Industrial Classification Code Number (4)

MACT Maximum Achievable Control Technology Code which

identifies a source categories defined by Maximum

Achievable Control Technology rules or rules that are

done under other programs such as Section 129

standards Character (6)

NAICS North American Industrial Classification System Code Character (6)

CTYPE Coordinate system type; U = Universal Transverse

Mercator ; L = Latitude/longitude Character (8)

XLOC X location, If CTYPE = U, Easting value (meters); If

CTYPE = L, Longitude (decimal degrees) Number (11,6)

YLOC Y location, If CTYPE = U, Northing value (meters), If

CTYPE = L, Latitude (decimal degrees) Number (11,6)

UTMZ UTM zone (required if CTYPE = U) Number (2)

POLCODE Code representing the pollutant contained in the

inventory Character (9)

ANN_EMIS Annual Emissions (tons/year) Number (20,8)

AVD_EMIS Average

- day Emissions (tons/average day) Number (20,8)

CEFF Control Efficiency percentage (give value of 0

- 100) Number (5,2)

REFF Rule Effectiveness percentage (give value of 0

- 100) Number (5,2)

CPRI Primary Control Equipment Code Number (4)

CSEC Secondary Control Equipment Code Number (4)

NEI_UNIQUE_ID Unique ID that ties together HAP and CAP emissions

within a common facility ID, and ties together emissions

obtained from multiple data sources (e.g., TRI, State,

ESD) which may have different s tate f acility i dentifiers

but really belong to a single facility Character (20)

ORIS_FACILITY_CODE ORIS code matching with the 200 5 NEI ORL CAP

corresponding ID Character (6)

ORIS_BOILER_ID B oiler ID ID matching with the 200 5 NEI ORL CAP

corresponding ID in relation to above ID Character (5)29 F ield Name D escription T ype and Length

IPM_YN Y or N single character flag indicating whether the point

source belongs in the IPM sector Character (1)

DATA_SOURCE Flag indicating the source of the data (e.g., state

submitted, toxics release inventory, Clean Air Markets

Division, etc.) Character (10)

STACK_DEFAULT_FLAG Flag indicating how NEI defaulted stack parameters Character (10)

LOCATION_DEFAULT_F

LAG Flag indicating how NEI defaulted locations Character (10)

YEAR Year of emission s Character (4)

TRIBAL_CODE Indicates the particular tribe that submitted the data Character (3)

HORIZONTAL_AREA_FU

GITIVE Related to AXLEN, AYLEN which are optional

param eters for ISCST3/AERMOD Number (8)

RELEASE_HEIGHT_FUGI

TIVE Related to optional param eter s for ISCST3/AERMOD Number (8)