Flat File Generation Methodology Version: EPA 2022 Reference Case Using EPA Platform V6

FLAT FILE GENERATION METHODOLOGY

Version: EPA 2022 Reference Case using EPA Platform v6

SECTION I: INTRODUCTION

This document provides the flat file generation methodology for the EPA 2022 Reference Case using
EPA Platform v6. The methodology takes Integrated Planning Model (IPM®) run results and generates
the formatted flat file that the U.S. Environmental Protection Agency (U.S. EPA) uses as inputs into the
air-quality modeling framework. Section II provides data descriptions. Section III (see page 2) describes
data processing steps in detail. Section IV (see page 12) describes the layout of the formatted flat file.

SECTION II: DATA DESCRIPTIONS

IPM run results: This file contains IPM run results that have been disaggregated to the unit, emission
control technology, and fuel type level. The file provides records of existing and retrofitted units and
committed and new-build aggregates1. The committed and new-build aggregates are hereafter referred
to as "generic" aggregates. All records contain the following:

i. Population characteristics, including state FIPS codes, county FIPS codes, recognized ORIS codes
(<80,000), and unit IDs for existing and retrofitted units. Generic aggregates have state-level information
only.

ii. Sulfur dioxide (SO2), nitrogen oxides (NOx), and particulate matter (PM) control information for existing
and retrofitted units, as well as generic aggregates.

iii. Annual and seasonal heat input (TBtu).

iv. Heat contents (MMBtu/ton, K gallon, MMcf) and SO2 contents (Ib/MMBtu).

v. Annual and summer NOx emissions (MTon), annual SO2 emissions (MTon), HCL emissions (MTon), and
mercury emissions (Ton).

Table 1 provides the rest of the input data descriptions and table locations.

Table 1 - Input Data Descriptions and Locations

No.

Table Name

Description

Location

EIS

This table contains Emission Inventory System (EIS) unit-
specific data that include unit facility name, facility code, boiler
ID, tribal code, reg code, NAICS, longitude, latitude, facility ID,
unit ID, release point ID, process ID, agency facility ID, agency
unit ID, agency release point ID, agency process ID, stack
height, stack diameter, stack temperature, stack flow, and stack
velocity.

Flat File
Inputs EPA
2022

Reference
Case.xlsx

GenericUnitSite

This table contains all existing plants that serve as sister plants
in siting generic units. The data include NEEDS v6 plant's state
FIPS code, county FIPS code, county's most recent 8-hour
ozone or PM2.5 attainment/non-attainment status, ORIS code,
latitude-longitude coordinates, and zip code.

Flat File
Inputs EPA
2022

Reference
Case.xlsx

LatLon Default

This table contains latitude-longitude coordinates by ORIS
code, state FIPS code, and county FIPS code.

Flat File
Inputs EPA
2022

Reference
Case.xlsx

1 All fossil, geothermal, landfill gas, non-fossil waste, municipal solid waste, tires, and biomass fired units are
included in this process. Nuclear, hydro, wind, solar, fuel cell, and energy storage units are not included.

Page 1 of 14

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No.

Table Name

Description

Location

see

This table contains Source Classification Codes (SCCs) by
plant type, fuel type, coal rank, firing, and bottom type (for
boilers).

Table 6

PlantTypeStackParameters

This table contains stack parameters (height, diameter,
temperature, and velocity) by plant type.

Table 7

SCCDefaultStackParamete
rs

This table contains default stack parameters (height, diameter,
temperature, and velocity) by SCC.

Table 8

ControlDevices

This table contains post-combustion control devices and their
associated control IDs.

Table 9

PM10, PM2.5,CO, VOC, and
NH3 Emission Factors

This table contains PM10, PM2.5, carbon monoxide (CO), volatile
organic compounds (VOC), and ammonia (NH3) emission
factors for existing units.

Flat File
Inputs EPA
2022

Reference
Case.xlsx

Generic PM10 and PM2.5,
CO, VOC, and NHs
Emission Factors

This table contains PM10, PM2.5, CO, VOC, and NH3 emission
factors for generic units.

Table 10

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 that follow.

Flow Chart 1 - Data Processing Steps

Step 1. Disaggregate Generic Aggregates into Individual Generic Units, Site the Generic Units to
their States and Counties and Assign SCCs, ORIS Codes, Facility IDs, Release Point IDs, and
Process IDs: Generic unit data are prepared by transforming the generic aggregates into units similar to
existing units in terms of the available data. First, the generic aggregates are disaggregated to create
generic units. Second, the generic units are sited and given the state, county, and county-centroid-based
latitude-longitude coordinates. Third, the generic units are assigned SCCs, ORIS codes, facility IDs, unit
IDs, release point IDs, and process IDs. This process is performed in three steps as described in Flow
Chart 2.

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Flow Chart 2 - Generic Unit Processing

1. Creating generic units: Generic aggregates are first disaggregated to create generic units. The
process entails two steps: i) The generic aggregates are first aggregated by state, plant type and, for coal
steam and IGCC, coal rank, ii) They are then split into smaller generic units by dividing the aggregated
capacity by a reference capacity. The result is the number of generic units created in each state for each
plant type and fuel type. The reference capacity is varied by plant type as shown in Table 2.

Table 2 - Generic Unit Reference Capacity

Plant Type

Reference Capacity (MW)

Biomass

Coal Steam

650

Combined Cycle

1,083

Combined Cycle with CCS

377

Combustion Turbine

237

Fossil Waste

Oil/Gas Steam

100

Landfill Gas

Geothermal

Aggregated heat input and emissions are then divided evenly among all generic units created in a given
state for each plant type.

2. Siting generic units: The generic units are given a state FIPS code, county FIPS code, and latitude-
longitude based on an algorithm that sites generic units in counties within their respective states. The
generic unit siting data table, GenericUnitSite, is used in this algorithm to assign each generic unit a sister
plant in a county based on the county's attainment/non-attainment status. Within a state, the hierarchy
for assignment of sister plants in the order of county code and ORIS code is shown in Flow Chart 3. All
generic units are sited so that their ORIS codes are unique, and the same ORIS code has the same
county and latitude-longitude across all runs of the same base case origin.

Flow Chart 3 - Generic Unit Siting Hierarchy

3. Assigning generic unit SCCs, ORIS codes, facility IDs, unit IDs, release point IDs, and process IDs:
SCC assignment is based on the unit's plant type, fuel type, and coal rank as shown in Table 3. Generic
unit ORIS code consists 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.

-------
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

10100902

Combined Cycle

Natural Gas

20100201

Combined Cycle

Oil

20100101

Combustion Turbine

Natural Gas

20100201

Combustion Turbine

Oil

20100101

IGCC

Coal

20100301

IGCC

Petroleum Coke

20100301

Oil/Gas Steam

Natural Gas

10100601

Landfill Gas

00000000

Geothermal

00000000

Then generic unit ORIS codes are 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 incrementing with
each generic unit created within a given state for each plant type. The last two digits are the state FIPS
code. For example, the first combined-cycle generic unit in Arizona used in the example above has a
plant ID of "ORIS700104".

Table 4 - Generic Unit 1st Digit ORIS Code

Plant Type

1st Digit of the ORIS Code

Biomass

Coal Steam

Combined Cycle

Combustion Turbine

Fossil Waste

Geothermal

IGCC

Landfill Gas

Oil/Gas Steam

Generic unit's facility ID consists of a concatenation of the word "ORIS" and the unit's ORIS code.
Generic unit's unit ID consists of a concatenation of a three-letter unit ID code representing the unit's
plant type as shown in Table 5 and the unit's state FIPS code. For example, the first combined-cycle
generic unit in Arizona used in the example above has a unit ID of "ORISGCC04".

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

Geothermal

GGE

IGCC

IGC

Landfill Gas

GLF

Oil/Gas Steam

GSC

Generic unit's release point ID is the same as the unit's unit ID. Generic unit's process ID is the same as
the unit's facility ID.

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Step 2. Assigning Existing and Retrofitted Unit's SCCs, State FIPS Codes, County FIPS Codes,
Facility IDs, Release Point IDs, Process IDs, and Other EIS Unit-Specific Data That Are Required
for Construction of the Flat File.

First, existing, and retrofitted units' SCCs are assigned. SCC, or Source Classification Code, describes a
generating unit's characteristics. The assignment of SCC for existing and retrofitted units is based on a
unit's configuration that includes plant type, fuel type, and, if the unit is a boiler, firing and bottom type.
The SCC is an eight-digit numeric code that describes the characteristics of the units. Beginning from the
left the 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 eighth
digits of the SCC represent the unit's attributes including fuel type and, if the unit is a boiler, bottom and
firing type. The second and fourth digits are zero. Table 6 displays the SCCs.

Table 6 - SCC Assignment for Existing and Retrofitted Units

Plant Type

Boiler/
Generator

Fuel Type / Coal
Rank

Firing

Bottom

SCC

Coal Steam

Boiler/Generator

B

tuminous



Wet

10100201

Coal Steam

Boiler/Generator

B

tuminous

Vertical

Wet

10100201

Coal Steam

Boiler/Generator

B

tuminous

Wall

Wet

10100201

Coal Steam

Boiler/Generator

B

tuminous

Vertical

Dry

10100202

Coal Steam

Boiler/Generator

B

tuminous

Wall

Dry

10100202

Coal Steam

Boiler/Generator

B

tuminous



Dry

10100202

Coal Steam

Boiler/Generator

B

tuminous





10100202

Coal Steam

Boiler/Generator

B

tuminous

Wall



10100202

Coal Steam

Boiler/Generator

B

tuminous

Vertical



10100202

Coal Steam



B

tuminous

Turbo



10100202

Coal Steam

Boiler/Generator

B

tuminous

Cyclone

Wet

10100203

Coal Steam

Boiler/Generator

B

tuminous

Cyclone

Dry

10100203

Coal Steam

Boiler/Generator

B

tuminous

Cyclone



10100203

Coal Steam

Boiler/Generator

B

tuminous

Stoker/SPR

Wet

10100204

Coal Steam

Boiler/Generator

B

tuminous

Stoker/SPR



10100204

Coal Steam

Boiler/Generator

B

tuminous

Stoker/SPR

Dry

10100204

Coal Steam

Boiler/Generator

B

tuminous

Tanqential

Wet

10100211

Coal Steam

Boiler/Generator

B

tuminous

Tangential



10100212

Coal Steam

Boiler/Generator

B

tuminous

Tangential

Dry

10100212

Coal Steam

Boiler/Generator

B

tuminous

Cell

Wet

10100215

Coal Steam

Boiler/Generator

B

tuminous

Cell



10100215

Coal Steam

Boiler/Generator

B

tuminous

Cell

Dry

10100215

Coal Steam

Boiler/Generator

B

tuminous

FBC



10100218

Coal Steam

Boiler/Generator

B

tuminous

FBC

Wet

10100218

Coal Steam

Boiler/Generator

B

tuminous

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

Tanqential

Wet

10100226

Coal Steam

Boiler/Generator

Subbituminous

Tanqential

Dry

10100226

Coal Steam

Boiler/Generator

Subbituminous

Cell

Wet

10100235

5

-------
Plant Type

Boiler/
Generator

Fuel Type / Coal
Rank

Firing

Bottom

see

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

Liqn

te

Wall

Dry

10100301

Coal Steam

Boiler/Generator

Liqn

te



Wet

10100301

Coal Steam

Boiler/Generator

Liqn

te

Tanqential

Wet

10100302

Coal Steam

Boiler/Generator

Liqn

te

Tanqential

Dry

10100302

Coal Steam

Boiler/Generator

Liqn

te

Cyclone



10100303

Coal Steam

Boiler/Generator

Liqn

te

Cyclone

Wet

10100303

Coal Steam

Boiler/Generator

Liqn

te

Stoker/SPR

Wet

10100306

Coal Steam

Boiler/Generator

Liqn

te

Stoker/SPR



10100306

Coal Steam

Boiler/Generator

Liqn

te

Stoker/SPR

Dry

10100306

Coal Steam

Boiler/Generator

Liqn

te

FBC



10100318

Coal Steam

Boiler/Generator

Liqn

te

FBC

Wet

10100318

Coal Steam

Boiler/Generator

Liqn

te

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

Tanqential



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

Tanqential

Dry

10100604

O/G Steam



Natural Gas

Tanqential

Wet

10100604

O/G Steam

Boiler/Generator

Natural Gas

Tanqential



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







20100301

We then assign existing and retrofitted units' state FIPS codes, county FIPS codes, facility IDs, release
point IDs, and process IDs. State FIPS codes, county FIPS codes, facility IDs, release point IDs, and
process IDs are obtained from the EIS unit-specific data table. Where the EIS provides no data, default
values are used. Appendix A describes the default values in detail.

6

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Step 3. Assigning Stack Parameters and Latitude-Longitude/County Centroid Coordinates for All
Units

Stack Parameters: Existing and retrofitted unit's stack parameters are assigned based on the hierarchy
described in Flow Chart 4.

Flow Chart 4 - Stack Parameters Assignment Hierarchy

Stack parameters are first assigned based on 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 EIS stack parameters
from the EIS unit-specific data table. If the EIS data table provides no stack parameters, the units are
assigned default stack parameters based on a unit's SCC as shown in Table 8.

Table 8 - SCC-Based Default Stack Parameters

SCC

Stack Height

Stack Diameter

Stack Temperature (°F)

Stack Velocity



(ft)

(ft)



(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

7

-------
see

Stack Height

(ft)

Stack Diameter

(ft)

Stack Temperature (°F)

Stack Velocity
(ft/sec)

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

Generic units are assigned SCC-based default stack parameters.

Stack flow data are assigned from the EIS data table for all existing and retrofitted units, except for IGCC
units which receive default stack flow by plant type as shown in Table 7. If the EIS data table does not
provide stack flow data or if the SCC-based default stack parameters are assigned, stack flows are
calculated as follows:

- ^ , . (Stack Diameter (ft)\2 , ,

Stack Flow (cft/sec) = 3.141592 * I I * Stack Velocity (ft/sec)

Coordinates: Latitude-longitude coordinates are assigned from the EIS data table. If the EIS data table
provides no data, latitude-longitude coordinates are assigned based on a unit's sister ORIS code from the
table LatLonDefault or based on the county centroid.

Step 4. Assigning Post-Combustion Control Device IDs for All Units

Control IDs are assigned reflecting all post-combustion control devices at a unit in a particular projection
year. The control devices reflect both existing and retrofit controls. Table 9 lists the control devices and
their associated control IDs.

Table 9 - Post-Combustion Control Devices

Control ID

Description

119

Dry FGD

139

SCR

140

SNCR or other NOx

141

Wet FGD

206

DSI

207

AC I

Step 5. Calculating CO, NOx, VOC, SO2, NH3, Primary PM10, Primary PM2.5, Mercury (Hg), and HCI
Emissions

Emissions are calculated at two levels: seasonal and monthly.

Seasonal emission calculations:

i. Seasonal NOx, SO2, mercury (Hg), and HCI emissions (tons) are taken directly from IPM run results.

ii. Seasonal primary PM10, primary PM2 5, CO, VOC, and NH3 emissions (tons) are calculated by
multiplying the unit's generation and unit specific emission factors for each pollutant as follows:

Seasonal Generation (MWh) * Unit level Emission FactorPollutant (Ib/MWh)
Seasonal EmissionPollutant (tons) = —

-------
Where 2000 converts lb to short ton; seasons are summer, winter, and winter shoulder; and the pollutants
are PM10, PM2 5, CO, VOC, and NH3. For existing units, unit-specific emission factor by pollutant is
assigned. Appendix B describes the methodology for estimation of PMioand PM2 5 emission factors. For
generic units, unit specific emission factor is assigned for each pollutant based on plant type as shown in
Table 10.

Table 10 - Generic Emission Factors (Ib/MWh)

Plant Type

Primary PM10

Primary PM2.5

VOC

NHs

Ultrasupercritical Coal with 30% CCS

0.146

0.112

0.284

0.013

0.006

Ultrasupercritical Coal with 90% CCS

0.146

0.112

0.284

0.013

0.006

Ultrasupercritical Coal without CCS

0.146

0.112

0.284

0.013

0.006

Combined Cycle

0.029

0.028

0.032

0.01

0.02

Combined Cycle with Carbon Capture

0.029

0.028

0.032

0.01

0.02

Combustion Turbine

0.069

0.065

0.298

0.023

0.046

Biomass

0.089

0.08

1.918

0.155

0.337

Landfill Gas

0.576

0.586

6.98

1.159

0.036

Monthly emission calculations:

Summer, Winter, and Winter Shoulder monthly emissions are calculated by multiplying the seasonal
emissions by the number of days in a specific month and dividing by the total number of days in that
season. Summer is the 153 days between May 1 and September 30. Winter is the 90 days between
December 1 and February 28. And Winter Shoulder is the 122 days between October 1 and November
30 and March 1 and April 30.

SECTION IV: FLAT FILE LAYOUT:

A flat file is generated with the processed data (as explained in the sections above) for use in air quality modeling
work. Both criteria and HAP emissions are provided in the same file. The pollutants are provided in the following
order: CO, NOx, VOC, SO2, NH3, primary PM10, primary PM2 5, Mercury (Hg), and HCI.

The file's naming convention is as follows:

FlatFile___.txt

where:

year4 = 4-digit year of the emissions (e.g., 2030)
yyyy = 4-digit year

mm = 2-digit month number (e.g. 01 through 12)
dd = 2-digit date number (e.g., 01 through 31)

For example: 'FlatFile_EPA513_BC_7c_2018_20131108.txt'.

All data fields are comma-delimited and character data, including comma, semi-colon, and space, are enclosed in
double-quotes.

The file contains the following header lines:

#FORMAT=ff10_POINT
#COUNTRY=US
#YEAR=

#VALUE_UNITS=TON
#CREATION DATE=

-------
#CREATOR_NAME=US EPA-CAMD
#DATA_SET_ID=1 ,US EPA IPM

#COUNTRY_CD,REGION_CD,TRIBAL_CODE,EIS_FACILITY_ID,EIS_UNIT_ID,EIS_REL_POINT_ID,EIS_PRO
CESS_ID,AGY_FACILITY_ID,AGY_UNIT_ID,AGY_REL_POINT_ID,AGY_PROCESS_ID,SCC,POLL,ANN_VALU
E,ANN_PCT_RED,FACILITY_NAME,ERPTYPE,STKHGT,STKDIAM,STKTEMP,STKFLOW,STKVEL,NAICS,LON
GITUDE,LATITUDE,LL_DATUM,HORIZ_COLL_MTHD,DESIGN_CAPACITY,DESIGN_CAPACITY_UNITS,REG_
CODES,FAC_SOURCE_TYPE,UNIT_TYPE_CODE,CONTROL_IDS,CONTROL_MEASURES,CURRENT_COST
,CUMULATIVE_COST,PROJECTION_FACTOR,SUBMITTER_FAC_ID,CALC_METHOD,DATA_SET_ID,FACIL_
CATEGORY_CODE,ORIS_FACILITY_CODE,ORIS_BOILER_ID,IPM_YN,CALC_YEAR,DATE_UPDATED,FUG_
HEIGHT, FUG_WIDTH_YDIM,FUG_LENGTH_XDIM,FUG_ANGLE,ZIPCODE,ANNUAL_AVG_HOURS_PER_YE
AR,JAN_VALUE,FEB_ VALUE,MAR_VALUE,APR_VALUE,MAY_VALUE,JUN_VALUE,JUL_VALUE,AUG_VALU
E,SEP_ VALUE,OCT_VALUE,NOV_VALUE,DEC_VALUE,JAN_PCTRED,FEB_PCTRED,MAR_PCTRED,APR_P
CTRED,MAY_PCTRED,JUN_PCTRED,JUL_PCTRED,AUG_PCTRED,SEP_PCTRED,OCT_PCTRED,NOV_PCT
RED,DEC_PCTRED,COMMENT

The last header line contains comma-delimited field names identifying the data contained in each data field.

10

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Appendix A

Default Values

Field Name

Default Value

COUNTRY CD

N/A

REGION CD

N/A

TRIBAL CODE

N/A

EIS FACILITY ID

"ORIS" followed by the ORIS FACILITY CODE. For example, ORIS55177.

EIS UNIT ID

"ORIS" followed by the ORIS BOILER ID. For example, ORISST1.



"ORIS" followed by the ORIS BOILER ID. That is, the same as the unit ID default

EIS REL POINT ID

value.

EIS PROCESS ID

Use the same value as in the [IPM Y/Nl field. That is, the NEEDS UniquelD.

AGY FACILITY ID

Blank

AGY UNIT ID

Blank

AGY REL POINT ID

Blank

AGY PROCESS ID

Blank

see

N/A

POLL

N/A

ANN VALUE

N/A

ANN PCT RED

Blank

FACILITY NAME

NEEDS Plant Name

ERPTYPE

Blank

STKHGT

SCC-based default stack parameters from SCCDefaultStackParameters table.

STKDIAM

SCC-based default stack parameters from SCCDefaultStackParameters table.

STKTEMP

SCC-based default stack parameters from SCCDefaultStackParameters table.

STKFLOW

SCC-based default stack parameters from SCCDefaultStackParameters table.

STKVEL

SCC-based default stack parameters from SCCDefaultStackParameters table.

NAICS

Blank

LONGITUDE

County-centroid based longitude by ORIS code, state FIPS code and country FIPS
code from LatLonDefault table.



County-centroid based longitude by ORIS code, state FIPS code and country FIPS

LATITUDE

code from LatLonDefault table.

LL DATUM

Blank

HORIZ COLL MTHD

Blank

DESIGN CAPACITY

N/A

DESIGN CAPACITY UNITS

N/A

REG CODES

Blank

FAC SOURCE TYPE

"125"

UNIT TYPE CODE

"100" for Boiler, "120" for Turbine, "140" for combined cycle (boiler/gas turbine).

CONTROL IDS

N/A

CONTROL MEASURES

Blank

CURRENT COST

Blank

CUMULATIVE COST

Blank

PROJECTION FACTOR

Blank

SUBMITTER ID

N/A

CALC METHOD

N/A

DATA SET ID

N/A

FACIL CATEGORY CODE

N/A

ORIS FACILITY CODE

NEEDS ORIS Code

ORIS BOILER ID

NEEDS Unit ID

IPM YN

N/A

INV YEAR

N/A

DATE UPDATED

N/A

FUG HEIGHT

Blank

FUG WIDTH YDIM

Blank

FUG LENGTH XDIM

Blank

FUG ANGLE

Blank

ZIPCODE

N/A

11

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Field Name

Default Value

ANNUAL AVG HOURS PER YEA
R

N/A

JAN VALUE

N/A

FEB VALUE

N/A

MAR VALUE

N/A

APR VALUE

N/A

MAY VALUE

N/A

JUN VALUE

N/A

JUL VALUE

N/A

AUG VALUE

N/A

SEP VALUE

N/A

OCT VALUE

N/A

NOV VALUE

N/A

DEC VALUE

N/A

JAN PCTRED

Blank

FEB PCTRED

Blank

MAR PCTRED

Blank

APR PCTRED

Blank

MAY PCTRED

Blank

JUN PCTRED

Blank

JUL PCTRED

Blank

AUG PCTRED

Blank

SEP PCTRED

Blank

OCT PCTRED

Blank

NOV PCTRED

Blank

DEC PCTRED

Blank

COMMENT

Blank

12

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Appendix B: PM Emissions

This appendix documents the updated PM Emissions Factor Methodology. This updated approach accomplishes
the following:

• Improves consistency of PM emissions rates between the reported base year (2019 NEI inventory) and
future year projections (IPM post-processing outputs)

• Enhances transparency by relying on reported emissions rates where possible and calculating estimates
only when necessary.

• Expedites creation and review of future year PM projections.

The steps taken to develop the unit specific primary PM10 and PM2 5 emission factors are explained below. The
resulting emission factors are included in the file FlatFile_lnputs.xls.

1. Developed crosswalks between NEEDS v6 and NEI 2019, and NEEDS v6 and 2018 and 2019 EIA Form
923. Additional data sources were reviewed for units that had no PM emissions in NEI 2019. These
sources included California Air Resources Board 2018, Florida State Emissions Inventory 2018, Michigan
Point Source Emission 2018, New York Emission Inventory 2018, North Carolina State Emissions
Inventory 2018, Oklahoma Annual Point Source Emissions 2018, Texas Emission Inventory 2018, and
Virginia State Emissions 2018.

2. Calculated NEEDS unit-specific primary PM10 and primary PM2 5 emission factors in Ib/MWh as the ratio
between reported PM emissions and reported generation (for those NEEDS units with reported historical
emissions and generation).

3. Estimated default primary PM10 and PM2 5 emission factors by plant type and FGD control status at the
national level based on NEEDS units with PM emission factors available from step 2 to use for those
NEEDS units with no matching historical emissions or generation or are considered as outliers. NEEDS
units with PM emission factors considered outliers are removed while calculating the default emission
factors.

4. Identified those units where historical and projected characteristics are different so that correct emissions
factors can be applied. For this purpose, FGD controls and fuel types (coal or natural gas) reported in
NEEDS, NEI 2019, 2018/2019 EIA Form 923 are compared with the future year IPM projections.

5. If no FGD controls or coal-to-gas fuel changes were projected in IPM, we used primary PM10 and primary
PM2 5 emissions factors calculated in step 2 to projected generation (MWh). In instances of biomass co-
firing, NEI-based unit-level primary PM10 and primary PM2 5 emission factors are used.

6. For units that have changed or are projected to change fuel from coal to gas, we used default primary
PM10 and PM2 5 emission factors for natural gas-fired units from step 3.

7. For units that switch coal rank, we applied unit-specific primary PM10 and PM2 5 emission factors from
step 2. Note that the expected impact of coal rank switching on emissions is minimal and developing a
methodology to capture the projected coal rank switch is complex.

8. For coal units projected to add new FGD controls, we applied default primary PM10 and primary PM2 5
emission factors for coal units with FGD control from step 3 when the default emission factors from step 3
are lower than the emission factors for the coal units without FGD controls.

9. For oil/gas steam, combined cycle, combustion turbine, and all other plant types, we applied steps 1
through 8.

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10. For new combined cycle and combustion turbine units, we used primary PM10 and primary PM2 5 emission
factors derived from the NEI for similar units with an online year of 2015 or later. For new units with
remaining plant types, we used primary PM10 and primary PM2 5 emission factors derived from the NEI for
similar units with an online year of 2010 or later.

Unit level emissions factors used in calculating PM emissions are presented in the spreadsheet titled "Post
Processing Emissions Factors PM CO VOC NH3."

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