FLAT FILE GENERATION METHODOLOGY
Version: January 2020 Reference Case using EPA Platform v6
SECTION I: INTRODUCTION
This document provides the flat file generation methodology for the January 2020 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 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:
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 and ash 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
1
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.
FlatFileJnput
s.xls
2
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.
FlatFileJnput
s.xls
3
LatLonDefault
This table contains latitude-longitude coordinates by ORIS code,
state FIPS code, and county FIPS code.
FlatFileJnput
s.xls
4
see
This table contains Source Classification Codes (SCCs) by plant
type, fuel type, coal rank, firing, and bottom type (for boilers).
Table 6
5
PlantTypeStackParamet
ers
This table contains stack parameters (height, diameter,
temperature, and velocity) by plant type.
Table 7
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 16
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No.
Table Name
Description
Location
6
SCCDefaultStackParame
ters
This table contains default stack parameters (height, diameter,
temperature, and velocity) by SCC.
Table 8
7
ControlDevices
This table contains post-combustion control devices and their
associated control IDs.
Table 9
8
CO, VOC, and NHs
Emission Factors
This table contains carbon monoxide (CO), volatile organic
compounds (VOC), and ammonia (NH3) emission factors for
existing units of plant types Landfill Gas, Non-fossil Waste, and
Municipal Solid Waste.
FlatFileJnput
s.xls
9
Generic CO, VOC, and
NH3 Emission Factors
This table contains CO, VOC, and NH3 emission factors for
generic units.
Table 10
10
SCCDefaultHeatContent
This table contains default heat contents by SCC.
Table 11
11
SCCEmsFac
This table contains emission factors for CO, VOC, and NH3.
Table 12
12
PM10 and PM2.5 Emission
Factors
This table contains PM10 and PM2.5 emission factors for existing
units.
FlatFileJnput
s.xls
13
Generic PM10 and PM2.5
Emission Factors
This table contains PM10 and PM2.5 emission factors for generic
units.
Table 13
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. Data Processing Steps
2
-------
Step 1. Disaggregate Generic Aggregates into Individual Generic Units, Site the Generic Units to
their States and Counties and Assign SCCs, ORIS Codes, Facility ID'S, 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.
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, and coal rank, li) 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 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
Table 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
030
IGCC
550
Oil/Gas Steam
100
Landfill Gas
030
Geothermal
030
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 that is 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 then 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.
3
-------
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 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
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
Landfill Gas
00000000
Geothermal
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
3
Coal Steam
9
Combined Cycle
7
Combustion Turbine
8
Fossil Waste
5
Geothermal
2
IGCC
6
Landfill Gas
1
Oil/Gas Steam
4
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".
4
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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.
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 it's a boiler, firing and bottom type. The SCC
is an eight-digit numeric code that describes 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 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
Tangential
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
5
-------
Plant Type
Boiler/
Generator
Fuel Type / Coal
Rank
Firing
Bottom
see
Coal Steam
Boiler/Generator
Subb
ituminous
Vertical
Wet
10100221
Coal Steam
Boiler/Generator
Subb
ituminous
10100222
Coal Steam
Boiler/Generator
Subb
ituminous
Dry
10100222
Coal Steam
Boiler/Generator
Subb
ituminous
Vertical
Dry
10100222
Coal Steam
Boiler/Generator
Subb
ituminous
Wall
Dry
10100222
Coal Steam
Boiler/Generator
Subb
ituminous
Wall
10100222
Coal Steam
Boiler/Generator
Subb
ituminous
Cyclone
Dry
10100223
Coal Steam
Boiler/Generator
Subb
ituminous
Cyclone
Wet
10100223
Coal Steam
Boiler/Generator
Subb
ituminous
Cyclone
10100223
Coal Steam
Boiler/Generator
Subb
ituminous
Stoker/SPR
10100224
Coal Steam
Boiler/Generator
Subb
ituminous
Stoker/SPR
Wet
10100224
Coal Steam
Boiler/Generator
Subb
ituminous
Stoker/SPR
Dry
10100224
Coal Steam
Boiler/Generator
Subb
ituminous
Tangential
Wet
10100226
Coal Steam
Boiler/Generator
Subb
ituminous
Tangential
Dry
10100226
Coal Steam
Boiler/Generator
Subb
ituminous
Cell
Wet
10100235
Coal Steam
Boiler/Generator
Subb
ituminous
Cell
Dry
10100235
Coal Steam
Boiler/Generator
Subb
ituminous
Cell
10100235
Coal Steam
Boiler/Generator
Subb
ituminous
FBC
Dry
10100238
Coal Steam
Boiler/Generator
Subb
ituminous
FBC
Wet
10100238
Coal Steam
Boiler/Generator
Subb
ituminous
FBC
10100238
Coal Steam
Boiler/Generator
Lignil
e
Wall
Dry
10100301
Coal Steam
Boiler/Generator
Lignil
e
Wet
10100301
Coal Steam
Boiler/Generator
Lignil
e
Tangential
Wet
10100302
Coal Steam
Boiler/Generator
Lignil
e
Tangential
Dry
10100302
Coal Steam
Boiler/Generator
Lignil
e
Cyclone
10100303
Coal Steam
Boiler/Generator
Lignil
e
Cyclone
Wet
10100303
Coal Steam
Boiler/Generator
Lignil
e
Stoker/SPR
Wet
10100306
Coal Steam
Boiler/Generator
Lignil
e
Stoker/SPR
10100306
Coal Steam
Boiler/Generator
Lignil
e
Stoker/SPR
Dry
10100306
Coal Steam
Boiler/Generator
Lignil
e
FBC
10100318
Coal Steam
Boiler/Generator
Lignil
e
FBC
Wet
10100318
Coal Steam
Boiler/Generator
Lignil
e
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
6
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Plant Type
Boiler/
Generator
Fuel Type / Coal
Rank
Firing
Bottom
SCC
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.
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
7
-------
see
Stack Height
Stack Diameter
Stack Temperature (°F)
Stack Velocity
(ft)
(ft)
(ft/sec)
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
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 Flow (cft/sec) = 3.141592 * f ^lac^ DiameteT- (ft) ^ * 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
8
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Step 5. Calculating CO, NOx, VOC, SO2, NH3, Primary PM10, Primary PM2.5, Mercury (Hg), and HCI
Emissions
Emissions are calculated at three levels: annual, seasonal, and monthly emissions.
Annual emission calculations:
i. Annual NOx, SO2, mercury (Hg), and HCI emissions (tons) are taken directly from IPM run results.
ii. Annual CO, VOC, and NH3 emissions (tons) for units of plant types Landfill Gas, Non-fossil Waste, and
Municipal Solid Waste are calculated by multiplying the unit's generation and unit specific emission
factors as follows:
Annual EmissionPoUutant (tons) = Annual Generation (MWh) * Unit Specific Emission FactorPollutant (ton/MWh)
For existing units, unit specific emission factors for CO, VOC, and NH3 are provided in the
COVOCNH3EmissionFactors table. For generic units, emission factors for CO, VOC, and NH3 are
assigned by plant type as shown in Table 10.
Table 10: Generic CO, VOC, and NH3 Emission Factors (Ton/MWh)
Plant Type
CO EF
VOC EF
NHsEF
Landfill Gas
0.00336001
0.00038188
0.00000432
Municipal Solid Waste
0.00035865
0.00002872
0.00001893
Note: CO, VOC, and NH3 emissions are not calculated for Geothermal and Tires.
iii. Annual CO, VOC, and NH3 emissions (tons) for units of the remaining plant types are calculated by
multiplying the unit's fuel use and emission factors as follows:
Annual EmissionsPollutant (tons) =
Annual Fuel Use (ton, K gallon, MMcf) * Emission FactorPoUutant (lb per ton, K gallon, MMcf)
2000 (lb/ton)
Where 2000 converts lb to short ton and the pollutants are CO, VOC, and NH3. Annual Fuel Use (ton, K
gallon, MMcf) 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:
/ Heat Input (MMBtu) \
(ton.K gallon,MMcf) = I - — I
\Heat Content (MMBtu per ton, K gallon, MMcf)J
Fuel Use
Where Heat Content (MMBtu per ton, K gallon, MMcf) is assigned using January 2020 Reference Case
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 11.
Table 11: SCC-Based Default Heat Content (MMBtu/ton, K gallon, MMcf)
SCC
Heat Content
10100401
0152
10100404
0152
10100409
0152
10100601
1024
10100604
1024
10100701
0671
10100902
0012
20100101
0138
20100201
1024
Emission factor is assigned for CO, VOC, and NH3 based on a unit's SCC as shown in Table 12.
9
-------
Table 12: SCC-Based Emission Factors (lb/ton, K gallon, MMcf)
see
CO EF
VOC EF
NH3 EF
10100201
0.5
0.04
0.03
10100202
0.5
0.06
0.03
10100203
0.5
0.11
0.03
10100204
5
0.05
0.03
10100211
0.5
0.04
0.03
10100212
0.5
0.06
0.03
10100215
0.5
0.06
0.03
10100218
18
0.05
0.03
10100221
0.5
0.04
0.03
10100222
0.5
0.06
0.03
10100223
0.5
0.11
0.03
10100224
5
0.05
0.03
10100226
0.5
0.06
0.03
10100235
0.5
0.06
0.03
10100238
18
0.05
0.03
10100301
0.25
0.07
0.03
10100302
0.6
0.07
0.03
10100303
0.6
0.07
0.03
10100306
5
0.07
0.03
10100318
0.15
0.03
0.03
10100401
5
0.76
0.8
10100404
5
0.76
0.8
10100409
5
0.76
0.8
10100601
84
5.5
3.2
10100604
24
5.5
3.2
10100701
6.57
0.43
1.2
10100801
0.6
0.07
0.4
10100818
18
0.05
0.4
10100902
6.8
0.19
0.09
10102001
0.25
0.07
0.03
10102018
0.15
0.03
0.03
20100101
0.46
0.06
6.62
20100201
84
2.1
6.56
20100301
35
2.2
6.56
iv. Annual primary PM10 and PM2 5 emissions (tons) are calculated by multiplying the unit's generation and
unit specific emission factors for PM10 and PM2 5 as follows:
Annual EmissionPouutant (tons) =
Annual Generation (MWh) * Unit level Emission FactorPouutant (Ib/MWh)
2000 (lb/ton)
Where 2000 converts lb to short ton and the pollutants are PM10 and PM2 5. For existing units, unit specific
emission factor is assigned for PM10 and PM2 5 as described in Appendix B. For generic units, unit specific
emission factor is assigned for PM10 and PM2 5 based on plant type as shown in Table 13.
Table 13: Generic PM10 and PM2.5 Emission Factors (Lb/MWh)
Plant Type
Primary PM10 EF
Primary PM2.5 EF
Ultrasupercritical Coal with 30% CCS
0.10594280
0.08338125
Ultrasupercritical Coal with 90% CCS
0.10594280
0.08338125
Ultrasupercritical Coal without CCS
0.10594280
0.08338125
Combined Cycle
0.06222523
0.06183582
Combined Cycle with Carbon Capture
0.06222523
0.06183582
Combustion Turbine
0.22368918
0.06557471
Biomass
0.14128140
0.07452200
Landfill Gas
0.35752155
0.35752155
10
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Seasonal emission calculations:
Summer Season is the 153 days between May 1 and September 30. Summer NOx 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.
Winter Season is the 90 days between December 1 and February 28. Winter emissions are calculated by
multiplying the annual emissions by the ratio of the winter to annual heat input.
Winter Shoulder Season is the 122 days between October 1 and November 30 and March 1 and April 30.
Winter Shoulder emissions are calculated by multiplying the annual emissions by the ratio of the Winter
Shoulder to annual heat input.
/Seasonal Heat Input (MMBtu)\
Seasonal Emission (tons) = Annual Emissions (tons) * - - —
V Annual Heat Input (MMBtu) J
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.
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SECTION IV: FLAT FILE LAYOUT:
A flat file is generated with the processed data (as explained in 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 PM25, 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.
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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/N] 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
County-centroid based longitude by ORIS code, state FIPS code and country FIPS code
LONGITUDE
from LatLonDefault table.
LATITUDE
County-centroid based longitude by ORIS code, state FIPS code and country FIPS 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
ANNUAL AVG HOURS PER YE
N/A
13
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Field Name
Default Value
AR
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
14
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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 (2016 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 2016, and NEEDS v6 and 2016 EIA Form 923. We
identified units that have no PM emissions in NEI 2016 and for those units we reviewed additional
sources. These sources included NEI 2014, California Air Resources Board 2016, California Air
Resources Board 2014, New York Emission Inventory 2016, Oklahoma Annual Point Source Emissions
2016, Pennsylvania Air Emissions Report 2016, and Texas Emission Inventory 2016.
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 historic
emissions and generation).
3. Estimated default primary PM10 and PM2 5 emission factors by plant type and FGD control status at
national level based on NEEDS units with PM emission factors available from step 2 in order to use for
those NEEDS units with no matching historic 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 historic characteristics 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 2016, 2016 EIA Form 923 are compared with the future year IPM
projections.
5. If no FGD controls or no 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 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.
10. For new units, 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.
15
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11. New York and Michigan have emission rules for filterable PM. We ensured that projected PM emissions
are within the bounds of these state emission limits. For most units, PM filterable emission limits for NY
and Ml were higher than the primary PM emission factors estimated. For a few small combustion turbine
units where the estimated emission factors were higher than the specified emission limits, the calculated
emission factors were used as the primary PM emission factors are higher than the PM filterable emission
factors.
16
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