Emissions Inventory for Air Quality Modeling 

Technical Support Document: 2017-2025 

Light-Duty Vehicle Greenhouse Gas Final Rule
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EPA-454/R-12-005

August 2012

Emissions Inventory for Air Quality Modeling Technical Support Document: 

2017-2025 Light-Duty Vehicle Greenhouse Gas Final Rule

U.S. Environmental Protection Agency

Office of Air and Radiation

Office of Air Quality Planning and Standards

Air Quality Assessment Division

Contact:

Alexis Zubrow
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TABLE OF CONTENTS

ACRONYMS...............................................................................................................................................v

LIST OF TABLES .....................................................................................................................................vi

LIST OF FIGURES ...................................................................................................................................vi

LIST OF APPENDICES ...........................................................................................................................vii

1 Introduction.........................................................................................................................................1

2 2005 Emission inventories and their preparation...............................................................................2

2.1 Custom configuration for emissions modeling for LDGHG............................................................3

2.2 2005 Emissions Inventories and Processing ...................................................................................5

2.3 2005 Onroad Mobile sources..........................................................................................................5

2.4 Nonroad mobile sources (nonroad, alm_no_c3, seca_c3) ...............................................................7

2.4.1 Locomotives and commercial marine vessels (alm_no_c3, seca_c3)...........................................7

2.5 2005 point sources (ptipm and ptnonipm sectors)...........................................................................7

2.5.1 Ethanol plants (ptnonipm) ..........................................................................................................8

2.6 2005 nonpoint sources (afdust, ag, avefire, nonpt)..........................................................................8

2.6.1 Portable fuel containers..............................................................................................................8

2.6.2 Onroad refueling ........................................................................................................................9

2.7 Other sources (biogenics, othpt, othar, and othon)..........................................................................9

3 VOC speciation changes that represent fuel changes.......................................................................10

4 2030 Reference Case ..........................................................................................................................12

4.1 Stationary source projections: EGU sector (ptipm)......................................................................18

4.2 Stationary source projections: non-EGU sectors (ptnonipm, nonpt, ag, afdust)............................18

4.2.1 Ethanol plants (ptnonipm) ........................................................................................................20

4.2.2 Biodiesel plants ptnonipm).......................................................................................................20

4.2.3 Portable fuel container growth and control (nonpt)...................................................................21

4.2.4 Cellulosic fuel production (nonpt)............................................................................................21

4.2.5 Ethanol transport and distribution (nonpt) ................................................................................22

4.2.6 Refinery adjustments (ptnonipm) .............................................................................................22

4.2.7 Ethanol transport gasoline and blends (ptnonipm, nonpt)..........................................................23

4.2.8 Upstream agricultural adjustments (afdust, ag, nonpt, ptnonipm)..............................................23

4.2.9 Livestock emissions growth (ag, afdust)...................................................................................23

4.2.10 Residential wood combustion growth (nonpt).......................................................................24

4.2.11 Gasoline Stage II growth and control (nonpt, ptnonipm).......................................................25

4.2.12 Aircraft growth (ptnonipm) ..................................................................................................26

4.2.13 Stationary source control programs, consent decrees & settlements, and plant closures 

(ptnonipm, nonpt)................................................................................................................................26

4.2.14 Oil and gas projections in TX, OK, and non-California WRAP states (nonpt).......................31

4.3 Mobile source projections............................................................................................................31

4.3.1 Onroad mobile (on_noadj, on_moves_runpm, on_moves_startpm)...........................................32

4.4 Nonroad mobile source projections (nonroad, alm_no_c3, seca_c3).............................................33

4.4.1 Emissions generated with the NONROAD model (nonroad) ....................................................33

4.4.2 Locomotives and Class 1 & 2 commercial marine vessels (alm_no_c3)....................................34

4.4.3 Class 3 commercial marine vessels (seca_c3)...........................................................................36

4.5 Canada, Mexico, and Offshore sources (othar, othon, and othpt)..................................................37

5 2030 Control Case..............................................................................................................................37

5.1 2030 Control Case Point and Nonpoint sources............................................................................37

5.2 2030 Control Case Mobile sources...............................................................................................40

6 References..........................................................................................................................................42
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ACRONYMS

AEO Annual Energy Outlook

BEIS Biogenic Emission Inventory System

btp Bulk plant terminal-to-pump

C3 Category 3 (commercial marine vessels)

CAP Criteria Air Pollutant

CARB California Air Resources Board

CMAQ Community Multiscale Air Quality

CSAPR Cross-State Air Pollution (formerly Transport) Rule

E0 0% Ethanol gasoline

E10 10% Ethanol gasoline

EISA Energy Independence and Security Act of 2007

EGU Electric Generating Utility

FAA Federal Aviation Administration

FIPS Federal Information Processing Standard

HAP Hazardous Air Pollutant

LDGHG Heavy Duty Greenhouse Gas

HONO HNO2, nitrous acid

IPM Integrated Planning Model

LDGHG Light Duty Greenhouse Gas

MOBILE6 Mobile Source Emission Factor Model, version 6

MOVES Motor Vehicle Emissions Simulator

MY Model Year

NEEDS National Electric Energy Database System

NEI National Emission Inventory

NMIM National Mobile Inventory Model

OAQPS EPA’s Office of Air Quality Planning and Standards

ORL One Record per Line (a SMOKE input format)

MP Multipollutant

NO Nitric oxide

NO2 Nitrogen dioxide

NOX Nitrogen oxides

PFC Portable Fuel Container

PEC Elemental carbon component of PM2.5

PMFINE Leftover “Other”, or “crustal” component of PM2.5

PNO3 Particulate nitrate component of PM2.5

PSO4 Particulate sulfate component of PM2.5

POC Organic carbon component of PM2.5

rbt Refinery-to-bulk terminal

RFS2 Revised annual renewable fuel standard

SMOKE Sparse Matrix Operator Kernel Emissions

SCC Source Category Code

TAF Terminal Area Forecast

TSD Technical Support Document

VOC Volatile Organic Compound

WRAP Western Regional Air Partnership
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LIST OF TABLES

Table 1-1. List of cases run in support of the LDGHG air quality modeling..................................................1

Table 2-1. Sectors Used in Emissions Modeling for the LDGHG Platform ...................................................2

Table 2-2. Model species produced by SMOKE for CB05 with SOA for LDGHG platform .........................4

Table 2-3. Description of differences in ancillary data between the LDGHG 2005 case and the 2005 v4.2 

platform.................................................................................................................................................5

Table 2-4. HONO, NO, and NO2 computations in LDGHG versus 2005v4.2 platform .................................6

Table 2-5. 2005 ethanol plant emissions (tons) .............................................................................................8

Table 3-1. Summary of VOC speciation profile approaches by sector across cases.....................................11

Table 4-1. Control strategies and growth assumptions for creating the LDGHG 2030 Reference case 

emissions inventories from the 2005 base case.....................................................................................15

Table 4-2. LDGHG FRM reference case stationary non-EGU source-related projection methods ...............19

Table 4-3. 2030 corn ethanol plant emissions [tons] ...................................................................................20

Table 4-4. 2030 biodiesel plant emissions [tons].........................................................................................20

Table 4-5. PFC emissions for 2030 [tons]...................................................................................................21

Table 4-6. 2030 cellulosic plant emissions [tons]........................................................................................22

Table 4-7. 2030 VOC losses (Emissions) due to ethanol transport and distribution [tons] ...........................22

Table 4-8. Impact of refinery adjustments on 2030 emissions [tons] ...........................................................23

Table 4-9. Upstream agricultural emission increases due to RFS2 fuels in 2030 [tons] ...............................23

Table 4-10. Growth factors from year 2005 to 2030 for animal operations..................................................23

Table 4-11. Projection factors for growing year 2005 residential wood combustion sources .......................25

Table 4-12. Factors used to project 2005 base-case aircraft emissions to year 2030 ....................................26

Table 4-13. Summary of Non-EGU Emission Reductions Applied to the 2005 Inventory due to Unit and 

Plant Closures......................................................................................................................................27

Table 4-14. Future-year ISIS-based cement industry annual reductions (tons/yr) for the non-EGU 

(ptnonipm) sector.................................................................................................................................29

Table 4-15. State-level non-MACT Boiler Reductions from ICR Data Gathering .......................................29

Table 4-16. National Impact of RICE Controls on 2030 Non-EGU Projections...........................................30

Table 4-17. Impact of Fuel Sulfur Controls on 2030 Non-EGU Projections................................................30

Table 4-18. Oil and Gas NOX and SO2 Emissions for 2005 and 2030 including additional reductions due to 

the RICE NESHAP..............................................................................................................................31

Table 4-19. Factors applied to year 2005 emissions to project locomotives and class 1 and class 2 

commercial marine vessel emissions to 2030 .......................................................................................35

Table 4-20. Additional class 1 railroad and C1/C2 CMV emissions from RFS2 fuel volume changes .........36

Table 4-21. NOX, SO2, PM2.5 and VOC factors to project class 3 CMV emissions for 2030 ........................37

Table 5-1. Adjustments to IPM Emissions to Account for Reduced Refinery Demand ................................38

Table 5-2. Total Air Quality Inventory Impacts on ptipm (Electric Power Plants from Electric and Electric 

Plug-in Vehicles, and Reductions in Production of Electricity for Refinery Use).................................38

LIST OF FIGURES

Figure 4-1. MOVES exhaust temperature adjustment functions for 2005 and 2030.....................................33
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LIST OF APPENDICES

APPENDIX A: Modified LDGHG Equations to adapt pre-speciated diesel emissions from MOVES to air 

quality modeling species needed for CMAQ.

APPENDIX B: Summary of LDGHG Rule 2030 Reference Case Non-EGU Control Programs, Closures and 

Projections

APPENDIX C: Fuel Distribution SCCs in Nonpt and Ptnonipm
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1 Introduction

This document provides the details of emissions data processing done in support of the Environmental 

Protection Agency (EPA) and National Highway Traffic Safety Administration (NHTSA) joint rulemaking 

effort under the Clean Air Act (CAA) and the Energy Independence and Security Act of 2007 (EISA) to 

establish fuel efficiency and greenhouse gas emissions standards for passenger cars, light-duty trucks, and 

medium-duty passenger vehicles, beginning with the 2017 model year (MY). This rulemaking effort is 

hereafter referred to in this technical support document (TSD) as the Light Duty Vehicle Greenhouse Gas 

(LDGHG) rule and consists of three emissions cases. Table 1-1 provides of list of the emissions cases 

created for this modeling effort.

Table 1-1. List of cases run in support of the LDGHG air quality modeling

Case Name

Internal EPA 

Abbreviation Description

2005 Base case 2005ct_ldghg2 2005 case created using average year fires data and an 

average year temporal allocation approach for Electrical 

Generating Units (EGUs), used to compute relative 

response factors with 2030 scenarios.

2030 Reference case 2030ct_ldghg_ref 2030 “reference” (baseline) scenario representing the 

best estimate for the future year without implementation 

of the new light duty GHG emissions standards.

2030 Control case 2030ct_ldghg_ctl2 2030 “control” case scenario representing 

implementation of national GHG emissions standards, 

phased in from 2017 to 2025, for passenger cars, lightduty trucks, and medium-duty passenger vehicles,

The data used in the 2005 emissions cases are often the same as those described in the Transport Rule Final 

CAP-BAFM 2005-based, Version 4.2 Platform TSD (http://www.epa.gov/ttn/chief/emch/index.html#2005), 

but some different emissions data are used for this rulemaking. Specifically, the LDGHG modeling used 

data intended only for the rule development and not for general use. All of the documentation provided here 

describes what was done differently and specifically for the LDGHG effort in contrast to what is used in the 

v4.2 platform.

In LDGHG, we used a 2005 base case approach for the year 2005 emissions scenario. This approach is very 

similar to that used in the Cross State Air Pollution Rule (CSAPR) Final Rule (formerly known as the 

“Transport Rule”). A base case approach uses average year fires and EGU temporal profiles from three

years of EGU data. We use a base case approach because we want to reduce year-specific variability in 

some components of the inventory. For example, large fires vary in location and day of the year each year, 

and EGU shutdowns and high use on high energy demand days also vary by year. By using a base case 

approach, these two aspects of the inventory are maintained in future year modeling and therefore do not 

introduce potentially spurious year-specific artifacts in air quality modeling estimates. For LDGHG, the 

same biogenic emissions data as the v4.2 platform was used for the 2005 case, and also for both future-year 

cases. The only significant data changes between the 2005 and the 2030 future-year LDGHG cases are the 

emission inventories and speciation approaches.

For this effort, we have created and provided county-level emission summaries for criteria pollutants and 

select hazardous air pollutants (e.g. benzene, acetaldehyde, formaldehyde, acrolein, 1,3-butadiene, ethanol, 

naphthalene) by emissions modeling sector for the cases listed above. Summaries were developed by month 
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using average day emissions and separately with annual totals. These data have been provided to the EPA 

docket for this rule. .

In the remainder of this document, we provide a description of the approaches taken for the emissions in 

support of air quality modeling for LDGHG. In Section 2, we describe the ancillary data and 2005 inventory 

differences from the v4.2 platform. In Section 3, we describe the speciation differences among each of the 

cases run for LDGHG. In Section 0, we describe the 2030 Reference case as compared to the 2005 base 

case, and in Section 5, we describe the 2030 Control Case in comparison to the 2030 Reference case.

2 2005 Emission inventories and their preparation

As mentioned previously, the 2005 emissions modeling approach for LDGHG used much of the same data 

and approaches as the 2005 v4.2 platform. In this section, we identify the differences between the data used 

for LDGHG and that used for the 2005 v4.2 platform. Section 2.1 provides ancillary data differences that

impact multiple sectors and Sections 2.2 through 2.3 provides differences for the point, area, and mobile 

sectors.

Table 2-1 below lists the platform sectors used for the LDGHG modeling platform. It also indicates which 

platform sectors include HAP emissions and the associated sectors from the National Emission Inventory 

(NEI). Subsequent sections refer to these platform sectors for identifying the emissions differences between 

the v4.2 platform and the LDGHG platform.

Table 2-1. Sectors Used in Emissions Modeling for the LDGHG Platform

Platform Sector

2005 NEI 

Sector Description

Contains HAP 

emissions?

IPM sector: ptipm Point NEI EGU units at facilities mapped to the IPM model using the 

National Electric Energy Database System (NEEDS) database.

Yes

Non-IPM sector: 

ptnonipm

Point+ All NEI point source units not matched to the ptipm sector, 

including aircraft.

Yes

Average-fire sector: 

avefire 

N/A Average-year wildfire and prescribed fire emissions, county and 

annual resolution. 

Yes

Agricultural sector: 

ag

Nonpoint NH3 emissions from NEI nonpoint livestock and fertilizer 

application.

No

Area fugitive dust 

sector: afdust

Nonpoint PM10 and PM2.5 emissions from fugitive dust sources in the NEI 

nonpoint inventory.

No

Remaining nonpoint 

sector: nonpt

Nonpoint+ All nonpoint sources not otherwise included in other emissions 

modeling sectors.

Yes

Nonroad sector: 

nonroad

Mobile: 

Nonroad

Monthly nonroad emissions from the National Mobile Inventory 

Model (NMIM) using NONROAD2005 version nr05c-BondBase, 

which is equivalent to NONROAD2008a, since it incorporated 

Bond rule revisions to some of the base-case inputs and the Bond 

rule controls did not take effect until later. NMIM was used for all 

states except California. Monthly emissions for California created 

from annual emissions submitted by the California Air Resources 

Board (CARB) for the 2005v2 NEI.

Yes

Aircraft, 

locomotive, marine: 

alm_no_c3

Mobile: 

Nonroad

Primarily 2002 NEI non-rail maintenance locomotives, and 

category 1 and category 2 commercial marine vessel (CMV) 

emissions sources, county and annual resolution. Aircraft 

emissions are no longer in this sector and are now included in the 

Non-EGU sector (as point sources); also, category 3 CMV 

emissions are no longer in this sector and are now contained in the 

seca_c3 sector.

Yes
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Platform Sector

2005 NEI 

Sector Description

Contains HAP 

emissions?

C3 commercial 

marine: seca_c3

Mobile: 

nonroad

Annual point source-formatted, year 2005 category 3 (C3) CMV 

emissions, developed for the rule called “Control of Emissions 

from New Marine Compression-Ignition Engines at or Above 30 

Liters per Cylinder”, usually described as the Emissions Control 

Area (ECA) study (http://www.epa.gov/otaq/oceanvessels.htm). 

Utilized final projections from 2002, developed for the C3 ECA

Proposal to the International Maritime Organization (EPA-420-F10-041, August 2010).

Yes

Onroad, except 

gasoline PM: 

on_noadj

Mobile: 

onroad+

Three, monthly, county-level components:

1) California onroad, created using annual emissions for all 

pollutants, submitted by CARB for the 2005v2 NEI. NH3 (not 

submitted by CARB) from MOVES2010a.

2) Onroad gasoline and diesel vehicle emissions from 

MOVES2010a not subject to temperature adjustments: exhaust 

CO, NOX, VOC, NH3, benzene, formaldehyde, acetaldehyde, 

1,3-butadiene, acrolein, naphthalene, brake and tire wear PM, and 

evaporative VOC, benzene, and naphthalene.

Yes

Onroad starting 

exhaust PM: 

on_moves_startpm

Mobile: 

onroad+

Monthly, county-level MOVES2010a-based onroad gasoline 

emissions subject to temperature adjustments. Limited to exhaust 

mode only for PM species and naphthalene. California emissions 

not included. This sector is limited to cold start mode emissions 

that contain different temperature adjustment curves from running 

exhaust (see on_moves_runpm sector).

No

Onroad running 

exhaust PM 

on_moves_runpm

Mobile: 

onroad+

Monthly, county-level draft MOVES2010a-based onroad gasoline 

emissions subject to temperature adjustments. Limited to exhaust 

mode only for PM species and naphthalene. California emissions 

not included. This sector is limited to running mode emissions 

that contain different temperature adjustment curves from cold 

start exhaust (see on_moves_startpm sector).

No

Biogenic: biog N/A Hour-specific, grid cell-specific emissions generated from the 

BEIS3.14 model, including emissions in Canada and Mexico. 

Unchanged from the 2005v4 platform.

No

Other point sources 

not from the NEI: 

othpt

N/A Point sources from Canada’s 2006 inventory and Mexico’s Phase 

III 1999 inventory, annual resolution. Also includes annual U.S. 

offshore oil 2005v2 NEI point source emissions. Unchanged from 

the 2005v4 platform.

No

Other nonpoint and 

nonroad not from 

the NEI: othar

N/A Annual year 2006 Canada (province resolution) and year 1999 

Mexico Phase III (municipio resolution) nonpoint and nonroad 

mobile inventories. Unchanged from the 2005v4 platform.

No

Other onroad 

sources not from the 

NEI: othon

N/A Year 2006 Canada (province resolution) and year 1999 Mexico 

Phase III (municipio resolution) onroad mobile inventories, 

annual resolution. Unchanged from the 2005v4 platform.

No

+ Some data included in modeling sector has been revised beyond what is included in the 2005 NEI v1 or v2. 

As with the 2005 v4.2 platform, the primary emissions modeling tool used to create the air quality modelready emissions was the Sparse Matrix Operator Kernel Emissions (SMOKE) modeling system 

(http://www.smoke-model.org/index.cfm). We used SMOKE version 2.7 to create emissions files for a 36-

km national grid, and 12-km Eastern and 12-km Western grids for the 2005 base case (also known as the 

“2005ct_ldghg 2_05b” case). 

2.1 Custom configuration for emissions modeling for LDGHG

Unlike the 2005 v4.2 platform, the configuration for LDGHG modeling included additional hazardous air 

pollutants (HAPs) and used slightly revised ancillary speciation data. Both of these differences are described 

in this section.
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Table 2-2 lists the additional HAP pollutants processed for the LDGHG platform, which were not included in 

the 2005 v4.2 platform. However, since using the full multipollutant HAP version of the Community 

Multiscale Air Quality (CMAQ) model would have taken longer than the time available for our project, we 

used a “lite” version of the multipollutant CMAQ (Version 4.7) that required emissions only for the species 

listed in the footnote of Table 2-2.

Table 2-2. Model species produced by SMOKE for CB05 with SOA for LDGHG platform

Inventory Pollutant Model Species Model species description

CL2 CL2 Atomic gas-phase chlorine

HCl HCL Hydrogen Chloride (hydrochloric acid) gas

CO CO Carbon monoxide

NOX NO Nitrogen oxide

NO2 Nitrogen dioxide

HONO Nitrous acid

SO2 SO2 Sulfur dioxide

SULF Sulfuric acid vapor

NH3 NH3 Ammonia

VOC ACROLEIN* Acrolein from the HAP inventory

ALD2 Acetaldehyde from VOC speciation

ALD_PRIMARY* Acetaldehyde from the HAP inventory

ALDX Propionaldehyde and higher aldehydes

BENZENE Benzene (not part of CB05)

BUTADIENE13*1,3-butadiene from the HAP inventory

ETH Ethene

ETHA Ethane

ETOH Ethanol

FORM Formaldehyde

FORM_PRIMARY*Formaldehyde from the HAP inventory

IOLE Internal olefin carbon bond (R-C=C-R)

ISOP Isoprene

MEOH Methanol

OLE Terminal olefin carbon bond (R-C=C)

PAR Paraffin carbon bond

TOL Toluene and other monoalkyl aromatics

XYL Xylene and other polyalkyl aromatics

Various additional 

VOC species from the 

biogenics model which 

do not map to the 

above model species

SESQ Sesquiterpenes

TERP Terpenes

PM10 PMC Coarse PM > 2.5 microns and 10 microns

PM2.5 PEC Particulate elemental carbon 2.5 microns

PNO3 Particulate nitrate 2.5 microns

POC Particulate organic carbon (carbon only) 2.5 microns

PSO4 Particulate Sulfate 2.5 microns

PMFINE Other particulate matter 2.5 microns

Sea-salt species (non –

anthropogenic 

emissions)

PCL Particulate chloride

PNA Particulate sodium

- ACROLEIN, ALD2_PRIMARY, BUTADIENE13, and FORM_PRIMARY are the extra “CMAQ-lite” HAPs 

that are not in the v4.2 platform.
5

In addition to the model species differences, the LDGHG platform had a few additional custom aspects in the 

2005 cases. Table 2-3 lists the datasets used by the LDGHG platform that are different from the v4.2

platform. 

Another consideration is the speciation across the LDGHG future-year cases as compared to 2005. Section 3 

provides a detailed account of these differences. Otherwise, the future-year ancillary data were largely the 

same as those in 2005, with no substantial differences. All ancillary data files can be found at the 2005-

based platform website (http://www.epa.gov/ttn/chief/emch/index.html#2005).

Table 2-3. Description of differences in ancillary data between the LDGHG 2005 case and the 2005 v4.2

platform

Ancillary Data Type Difference between 2005 v4.2 platform and LDGHG platform

Speciation crossreferences and 

Speciation profiles

The LDGHG data files are configured to support the multi-pollutant (MP) 

version of CMAQ, whereas the 2005 v4.2 platform data file is configured to 

support only the non-MP version. Therefore, the LDGHG data files include 

profiles for additional VOC HAP species.

Inventory tables The LDGHG data file is configured to support the MP “lite” version of CMAQ, 

whereas the 2005 v4.2 platform data file is configured to support only the nonMP version.

2.2 2005 Emissions Inventories and Processing

The LDGHG emissions for 2005 for many sectors except for U.S. onroad mobile sectors (on_noadj, 

on_moves_runpm, and on_moves_startpm) are similar to those provided in the 2005 Version 4.2-based 

Transport Rule Final TSD. Only minor adjustments were made to the point source sectors (ptnonipm, point), 

nonpoint source sectors (nonpt, afdust, ag, avefire), and nonroad sectors (alm_no_c3, nonroad, seca_c3). 

The Canada and Mexico sector (othar, othon, othpt) inventories are unchanged from the 2005v4.2 emissions 

modeling platform except for updated gridding surrogates used in the area based emissions. The 2005v4.2

TSD provides detailed documentation on the 2005v4.2 inventories and can be found at: 

ftp://ftp.epa.gov/EmisInventory/2005v4_2/transportrulefinal_eitsd_28jun2011.pdf.

2.3 2005 Onroad Mobile sources

Onroad mobile sources include three sectors for US onroad emissions (on_noadj, on_moves_startpm, 

on_moves_runpm). As discussed in the previous section, the three US nonroad sectors (nonroad,

alm_no_c3, and seca_c3) and the Canada/Mexico onroad emissions (othon) are unchanged from the 

2005v4.2 platform.

For onroad mobile, the MOVES-based emissions in the on_noadj sector and the on_moves_startpm and 

on_moves_runpm sectors (completely MOVES-based) emissions inventory data are from the Motor Vehicle 

Emission Simulator (MOVES2010, specifically, version MOVES2010a) model. In addition, for the 

MOVES PM sectors, the temperature adjustment calculations applied to PM2.5 species were the same as in 

the v4.2 platform. The NH3 onroad emissions in California (on_noadj sector) use MOVES2010(a)-based 

emissions. All other pollutants in California were supplied by CARB for the 2005 NEI v2. The LDGHG

onroad emissions keep additional HAPs as described in Section 2.1. 

For LDGHG, MOVES2010a was used in conjunction with an internal default databases

(MOVESDB20100913_45_corr, MOVESDB20100913_ldt, and 

MOVESDB20100913_MHDHHD2b3_corr) which contained performance updates from 

MOVESDB20100826, the database originally released with MOVES2010a and used in the 2005v4.2 

platform. The MOVES2010a default database used to model LDGHG also included improved heavy duty 
6

PM exhaust estimates (particularly for future year estimates) and was further customized to allow separate 

calculation of heavy duty emissions of different weight categories as described in the “Final Rulemaking to 

Establish Greenhouse Gas Emissions Standards and Fuel Efficiency Standards for Medium- and Heavy-Duty 

Engines and Vehicles Regulatory Impact Analysis” 

(http://www.epa.gov/oms/climate/documents/420r11901.pdf).

In addition, we used NO and NO2 directly from MOVES2010a for LDGHG, rather than the default NO/NO2

speciation from NOX used in 2005v4.2 processing. Table 2-4 shows the default NO, NO2, and HONO 

fractions used in 2005v4.2 versus the equations for LDGHG, where NO_MOVES and NO2_MOVES are the 

MOVES2010-provided NO and NO2 emissions. The HONO, computed from total MOVES NOX (sum of 

NO and NO2 from MOVES) is subtracted out of MOVES NO2 to conserve mass. The speciation of 

MOVES HONO, NO and NO2 is based on the molecular weight of NO2 (46); that is, these NOX components 

were speciated assuming they were inventoried as NO2-equivalent. All prior speciation of MOVES NOX

was also based on NO2 molecular weight equivalency.

Table 2-4. HONO, NO, and NO2 computations in LDGHG versus 2005v4.2 platform

CMAQ Specie LDGHG 2005v4.2

NO NO_MOVES NOX * 0.9

NO2 0.992 * NO2_MOVES – 0.008 * NO_MOVES NOX * 0.092

HONO 0.008 * (NO2_MOVES + NO_MOVES) NOX * 0.008

With one notable exception discussed here, for onroad gasoline exhaust PM emissions, the allocation of 

MOVES PM2.5 emissions to SMOKE-ready format PM species is the same as the 2005v4.2 platform and is 

documented in Appendix D of the 2005v4.1 TSD: 

http://www.epa.gov/ttn/chief/emch/toxics/2005v4.1_appendices.pdf. The exception to these equations is that 

for LDGHG processing, NH4 (ammonium) is removed from the computation of POC (PM2.5-based organic 

carbon) in equation 9, which in turn, affects the PMFINE (“other”, or “crustal” PM2.5) computation in 

equation 10. In short, MOVES2010a for LDGHG included improved PM exhaust estimates, and for diesel 

exhaust, the larger sulfate (PSO4) component was creating more NH4 in equation 7 than available 

“PM25OM” from MOVES2010a, where MOVES-provided species are related as follows:

PM25_TOTAL = PM25EC + PM25OM + PSO4

CMAQ requires these five CMAQ species to sum to total PM2.5, i.e.:

PM2.5 = POC+PEC+PNO3+PSO4+PMFINE

Appendix A in this document contains the revised text and equations, specifically, equation 7b for diesel 

exhaust. A recent study (SRI, 2009) also showed that, despite being sampled for NH4 and other ionic species 

in the particle phase, no particle phase NH4 was found in downstream filter tests. OTAQ experts agreed that 

NH4 for diesel exhaust must therefore removed, but we did not have time to reprocess gasoline exhaust PM 

(on_moves_runpm and on_moves_startpm sector) emissions with NH4 removed so the gasoline exhaust PM 

emissions do include some ammonium. However, PSO4 for gasoline exhaust is considerably smaller than 

diesel exhaust so the impact is likely negligible for air quality modeling. It is important to note that total 

PM2.5 was conserved for both gasoline and diesel exhaust (e.g., PM2_5_TOTAL from MOVES and PM2.5 

for CMAQ are identical). Note that PM emissions from these diesel sources are not subject to temperature 

adjustments like the on_moves_startpm and on_moves_runpm sectors.
7

2.4 Nonroad mobile sources (nonroad, alm_no_c3, seca_c3)

The nonroad sectors include a wide-range of mobile emission sources ranging from locomotives, marine 

vessels, construction and farming equipment to hand-held lawn tools. Emissions for this sector are the same 

as those in the 2005v4.2 emissions modeling platform. The 2005v4.2 TSD can be found at: 

ftp://ftp.epa.gov/EmisInventory/2005v4_2/transportrulefinal_eitsd_28jun2011.

2.4.1 Locomotives and commercial marine vessels (alm_no_c3, seca_c3)

The year 2005 emissions for locomotive and commercial marine vessel sources used for this rule are the 

same as they were for the Final Rulemaking: Greenhouse Gas Emissions Standards and Fuel Efficiency 

Standards for Medium- and Heavy-Duty Engines and Vehicles signed on August 9, 2011 and available at 

http://www.epa.gov/oms/climate/regulations.htm#1-2, and are also the same as those used for the Final 

Cross-State Air Pollution (CSAPR) Rule documented in:

ftp://ftp.epa.gov/EmisInventory/2005v4_2/transportrulefinal_eitsd_28jun2011.pdf. The procedures for 

calculating emissions from locomotives and C1/C2 commercial marine were developed for the Locomotive 

Marine Rule (2008) and are detailed in the RIA “Final Rule: Control of Emissions of Air Pollution from 

Locomotives and Marine Compression-Ignition Engines Less Than 30 Liters per Cylinder”, published May 

6, 2008 and republished June 30, 2008, and can be found at: 

http://www.epa.gov/oms/locomotives.htm#2008final. The procedures used for calculating C3 commercial 

marine emissions are those developed in the recent C3 “Final Rule: Control of Emissions from New Marine 

Compression-Ignition Engines at or Above 30 Liters per Cylinder”, published April 30, 2010 and can be 

found at: http://www.epa.gov/oms/oceanvessels.htm#car-ems.

2.5 2005 point sources (ptipm and ptnonipm sectors)

Point sources are sources of emissions for which geographic coordinates (e.g., latitude/longitude) are 

specified, as in the case of an individual facility. A facility may have multiple emission points that may be 

characterized as units such as boilers, reactors, spray booths, kilns, etc. A unit may have multiple processes 

(e.g., a boiler that sometimes burns residual oil and sometimes burns natural gas). Note that this section 

describes only NEI point sources within the contiguous United States. The offshore oil platform (othpt 

sector) and category 3 CMV emissions (seca_c3 sector) are also point source formatted inventories but are 

unchanged for the LDGHG modeling from the modeling of other recent rules. Discussion of the seca_c3 and 

othpt sector emissions can be found in the Final CSAPR TSD referenced in Section 2.3.2.

After removing offshore oil platforms (othpt sector), two platform sectors were created from the remaining 

2005v2 NEI point sources to provide inputs into SMOKE: the EGU sector – also called the Integrated 

Planning Model (IPM) sector (i.e., ptipm) and the non-EGU sector – also called the non-IPM sector (i.e., 

ptnonipm). This split facilitates the use of different SMOKE temporal processing and future-year projection 

techniques for each of these sectors, along with the replacement of ptipm emissions with outputs from IPM 

in emissions cases for future years. The inventory pollutants processed through SMOKE for both ptipm and 

ptnonipm sectors were: CO, NOX, VOC, SO2, NH3, PM10, and PM2.5 and the following HAPs: HCl 

(pollutant code = 7647010), and Cl2 (code = 7782505). We did not utilize BAFM from these sectors as we 

chose to speciate VOC without any use (i.e., integration) of VOC HAP pollutants from the inventory. 

Integration is discussed in detail in Section 3.

The ptnonipm emissions were provided to SMOKE as annual emissions. The ptipm emissions for the base 

case were input to SMOKE as daily emissions. The ptipm emissions are unchanged from those in the 

2005v4.2 –the basis for the Final CSAPR and Heavy Duty Greenhouse Gas (HDGHG) FRM- emission 

modeling platform. However, for the ptnonipm sector for all LDGHG FRM scenarios, including year 2005 

emissions, additional known ethanol plants were included that were not in 2005v4.2. We also removed all 
8

onroad refueling emissions as these were replaced with MOVES-based onroad refueling emissions 

(discussed in Section 2.5.2).

2.5.1 Ethanol plants (ptnonipm)

We replaced all ethanol plants that OTAQ had supplied from the RFS2 rule –see Section 2.1.2 in the CSAPR 

Final TSD- with those recently compiled for the 2005 case for the LDGHG FRM. These plants all produce 

corn ethanol and reflect a volume of approximately 4.1 billion gallons. All ethanol plants were assigned 

coordinates based on analysis using searches of company web sites and Google Earth verification for many 

sites. Emissions were calculated based on plant design capacity and emission factors based on production 

process and energy source (e.g. dry mill natural gas, wet mill coal, etc.). Finally, because benzene, 

acetaldehyde and formaldehyde (BAF) emissions were directly computed for these sources, we treated these 

ethanol plants as VOC integrate sources, unlike the rest of the ptnonipm sector. A summary of the ethanol 

plant emissions used in the 2005 scenario is provided in Table 2-5.

Table 2-5. 2005 ethanol plant emissions (tons)

Pollutant Emissions

1,3-Butadiene 0.0003

Acrolein 10.5

Formaldehyde 13.3

Benzene 5.7

Acetaldehyde 314.4

CO 7,023

NOX 8,204

PM10 10,107

PM2.5 3,691

SO2 9,001

VOC 10,754

2.6 2005 nonpoint sources (afdust, ag, avefire, nonpt)

The year 2005 area-source fugitive dust (afdust), agricultural animal and fertilizer NH3 (ag), and average 

(typical)-year fires (avefire) emissions are the same as those used in the CSAPR Final (2005v4.2) emission 

modeling platform. Nonpoint sources that were not subdivided into the afdust, ag, or avefire sectors were 

assigned to the “nonpt” sector, and most of these sources are also unchanged for LDGHG FRM modeling. 

The 2005 nonpoint sources that change in this study are limited to portable fuel containers (PFCs) and 

onroad refueling.

2.6.1 Portable fuel containers

Year 2005 PFC emissions are unchanged from the CSAPR Final inventory except for the addition of ethanol. 

Ethanol emissions were not provided for 2005, but were supplied for future year scenarios. Therefore, we 

scaled year 2017 pre-RFS2 ethanol emissions by the ratio of 2005 to 2017 pre-RFS2 VOC emissions to 

compute year 2005 ethanol emissions as follows: 

Ethanol_2005 = Ethanol_2017(pre-RFS2) * [VOC_2005 / VOC_2017(pre-RFS2)]
9

2.6.2 Onroad refueling

Refueling emissions were modeled using a modified draft version of EPA’s Motor Vehicle Emissions 

Simulator (draft MOVES2010b) at the county level for all twelve months. The refueling inventory includes 

emissions from spillage loss and displacement vapor loss. 

In an effort to reduce MOVES runtime, the “representing counties” approach was used instead of running 

every single county in the lower 48 states. We selected representing counties by grouping counties based on 

Petroleum Administration for Defense Districts (PADD), fuel parameters, usage of California emission 

standards, I/M programs, altitude, and temperature.

Temperature bins with increments of ten degrees Fahrenheit were created for the minimum and maximum 

temperatures for each month using the temperatures from the 2005 calendar year values in the 

CountyYearMonthHour table of the NMIM County Database (NCD) NCD20100602 NMIM database. All 

counties in each group had min and max temperatures for all twelve months in the same temperature bins.

Once counties were grouped, the representing county was chosen as the one with the highest VMT, resulting 

in total of 238 counties. The same set of county groups and representing counties was used for all years and 

scenarios. 

MOVES was run in inventory mode for only the representing counties using the county-specific on-road 

data, such as vehicle miles travelled, fleet age distribution, speed distribution, and meteorology, available 

from the NCD. The customized fuel inputs, discussed in Section 2.2.2.1, were used for each of the 

representing counties.

The resulting refueling emission inventories for 238 representing counties in U.S. short tons were converted 

to emission factors by dividing the inventory by the corresponding activity in each representing county. 

Then, the calculated emission factors from the representing counties were applied to the represented counties 

and multiplied by the county-specific activity to generate the inventories for all counties.

2.7 Other sources (biogenics, othpt, othar, and othon)

All emissions from Canada, Mexico, and Offshore Drilling platforms (othpt, othar, and othon), and all nonanthropogenic inventories (biogenics and ocean chlorine) are unchanged from the 2005v4.2 (used for the 

Final CSAPR and HDGHG FRM) emissions modeling platform. The one difference between LDGHG and 

these previous modeling is the use of updated gridding surrogates for othar and othon. The same emissions 

are used for all LDGHG FRM scenarios and years.

The biogenic emissions were computed based on 2005 meteorology data using the BEIS3.14 model within 

SMOKE. The 2002 platform used the BEIS3.13 model; otherwise, all underlying land use data and 

parameters are unchanged for the 2005 platform.

The BEIS3.14 model creates gridded, hourly, model-species emissions from vegetation and soils. It estimates 

CO, VOC, and NOX emissions for the U.S., Mexico, and Canada. The BEIS3.14 model is described further 

in: http://www.cmascenter.org/conference/2008/slides/pouliot_tale_two_cmas08.ppt

The inputs to BEIS include:

Temperature data at 2 meters which were obtained from the meteorological input files to the air 

quality model,
10

Land-use data from the Biogenic Emissions Landuse Database, version 3 (BELD3). BELD3 data 

provides data on the 230 vegetation classes at 1-km resolution over most of North America, which is 

the same land-use data were used for the 2002 platform.

The emissions from Canada, Mexico, and Offshore Drilling platforms are included as part of five sectors: 

othpt, othar, and othon. 

The “oth” refers to the fact that these emissions are “other” than those in the 2005 NEI, and the third and 

fourth characters provide the SMOKE source types: “pt” for point, “ar” for “area and nonroad mobile”, and 

“on” for onroad mobile. 

For Canada, year 2006 inventories are used for the 2005 platform, although corresponding future-year 

emissions were not available. For Mexico we continued to use emissions for 1999 (Eastern Research Group 

Inc., 2006) developed as part of a partnership between Mexico's Secretariat of the Environment and Natural 

Resources (Secretaría de Medio Ambiente y Recursos Naturales-SEMARNAT) and National Institute of 

Ecology (Instituto Nacional de Ecología-INE), the U.S. EPA, the Western Governors' Association (WGA), 

and the North American Commission for Environmental Cooperation (CEC). This inventory includes 

emissions from all states in Mexico.

The offshore emissions include point source offshore oil and gas drilling platforms. We used updated 

emissions from the 2005v2 NEI point source inventory. The offshore sources were provided by the Mineral 

Management Services (MMS).

3 VOC speciation changes that represent fuel changes

A significant detail that is different in each of the LDGHG modeling cases than in the 2005v4.2 emissions 

modeling is the VOC speciation profiles used to split total VOC emissions into the VOC model species 

needed for CMAQ. In this section, we summarize the various speciation profile information used in 

configuring the various cases.

The VOC speciation approach used for the 2005 base-year case has some notable differences from the 2005 

v4.2 platform for many emissions modes (e.g., evaporative, exhaust) and processes (e.g., diesel, gasoline, 

refueling). Two significant updates in the 2005 LDGHG are: 1) headspace vapor speciation utilizes a 

combination of the E10 headspace vapor profile (8763) and E0 headspace vapor profile (8762) as opposed to 

using solely E0 for 20051, and 2) a new Heavy Duty Diesel vehicle exhaust mode profile (8774) for pre-2007 

model year (MY) vehicles that replaces an older 2004-vintage medium-duty diesel profile (4674). See Table 

3-1 for more details.

The VOC speciation approach used for each of the future-year cases is customized to account for the impact 

of fuel changes. These changes affect the on_noadj sector, the nonroad sector, and parts of the nonpt and 

ptnonipm sectors. The speciation changes from fuels in the nonpt sector are for portable fuel containers 

(PFCs), onroad refueling, and fuel distribution operations associated with the bulk-plant-to-pump (btp) 

distribution. The speciation changes from fuels in the ptnonipm sector include btp distribution operations 

inventoried as point sources. Refinery to bulk terminal (rbt) fuel distribution and bulk plant storage (bps) 

speciation does not change across the modeling cases because this is considered upstream from the 

introduction of ethanol into the fuel. Mapping of fuel distribution SCCs to btp, bps, and rbt emissions 

categories can be found in Appendix C.

 

1 This was an oversight in the 2005v4.2 platform corrected for this modeling effort. 
11

To differentiate when a source was integrating BAFM versus EBAFM (ethanol in addition to BAFM), the 

speciation profiles which do not include ethanol are referred to as an “E-profile”, for example E10 headspace 

gasoline evaporative speciation profile 8763 where ethanol is speciated from VOC, versus 8763E where 

ethanol is obtained directly from the inventory. For fuel distribution operations associated with the bulkplant-to-pump (btp) distribution, ethanol is speciated from VOC –thus a “BAFM” profile- because the fuel 

distribution operations in the nonpoint inventories are NEI-based and therefore do not include ethanol 

specifically because the NEI does not provide ethanol as a pollutant. For PFC and refueling, ethanol was 

present in the inventories and therefore EBAFM profiles were used to integrate ethanol in the speciation. 

Table 3-1 summarizes the different profiles utilized for the fuel-related sources in each of the sectors for 

2005 and the future year cases. A comparison of the 2005v4.2 platform with the LDGHG 2005 case is also 

included. This table does not indicate when “E-profiles” were used.

Table 3-1. Summary of VOC speciation profile approaches by sector across cases

Inventory 

Type and 

Mode

VOC speciation approach by fuels VOC 

Profile 

Codes

2005

V4.2

2005

LDGHG

2030

Reference

& Control

Mobile 

Exhaust 

Diesel

medium-duty diesel exhaust, 2004-vintage 4674 onroad

nonroad

pre-2007 Heavy Duty profile 8774 onroad

nonroad

pre-2007 Medium Duty 8775 onroad 

except Class 

6,7 & 8 start

weighted year 2030 heavy-duty start 

(parking area) emissions with HD controls

877CH onroad 

class 8 start 

only

weighted year 2030 medium-duty start 

(parking area) emissions with HD controls

877CM onroad class 

6 & 7 start 

only

Mobile 

Exhaust 

Gasoline

Tier 1 E0 and E10 combinations 8750

8751

onroad

nonroad

onroad

nonroad

Tier 1 E10 

8751

nonroad

Tier 2 E10 8757 onroad

Mobile 

Evaporative 

Diesel

diesel evap headspace profile, Circle K 

Diesel single-sample

4547 onroad

nonroad

onroad

nonroad

onroad

nonroad

Mobile 

Evaporative 

Gasoline

E0 and E10 combinations 8753

8754

onroad

nonroad

onroad

nonroad

E10 

8754

onroad

nonroad

Mobile 

Refueling, 

PFCs, gas 

distribution

E0 headspace 8762 All listed

E0 headspace and E10 headspace 

combinations

8762

8763

All listed

E0 headspace or E15

2

8869

8871

All listed

 

2

PFC and BTP are post addition of ethanol and hence use E15 profile (8871) and BTP and RPT are before the addition of ethanal 

and hence use E0 profile (8869).
12

4 2030 Reference Case

The 2030 reference case represents emissions in the future. The reference and control cases assume fuel and 

emission changes from the Energy Independence and Security Act of 2007 (EISA) and RFS2 for upstream 

sources. For highway vehicles, we assume all gasoline use is E10. The 2030 reference case uses many of the 

same growth and control assumptions as those for the Final Cross-State Air Pollution Rule (CSAPR). There 

are some differences between the shared projection inputs from the 2012 and 2014 base case projections in 

CSAPR and the 2030 reference case for LDGHG:

1) The 2030 reference case includes the HDGHG controls. That is, we use the onroad HDGHG control 

case emission inventory as the reference case emissions for the LDGHG rule.

2) Some additional controls that were promulgated after 2014, (e.g., post-2014 consent decrees and fuel 

sulfur rules in a couple of states) are included.

3) Growth factors for several sources are year-specific; so while the methodology is the same as 

CSAPR, the future year emissions estimates differ (e.g., oil and gas in a couple states, residential 

wood combustion).

4) Onroad refueling uses year and scenario-specific (i.e., reference versus control) MOVES emissions, 

rather than NEI emissions.

5) There is a new dataset of ethanol plants that replaces a limited set of NEI ethanol plants in 2005v4.2-

based CSAPR 2012 and 2014 projections. 

6) Minor errors identified after CSAPR modeling was complete were fixed (e.g, we include agricultural 

dust projections for the couple of states that provided point source farms).

There are other new inputs unique to the LDGHG reference case that were not part of the CSAPR 

projections. Examples of these are RFS2 upstream inputs such as biodiesel and cellulosic ethanol plants, and 

adjustments to refinery emissions and fuel transport and distribution emissions to account for impacts of 

EISA. These new inputs and projections for the reference case are discussed later in this section. The 

remainder of Section 4 is very similar to Section 4 in the CSAPR emissions modeling TSD, available from 

ftp://ftp.epa.gov/EmisInventory/2005v4_2/transportrulefinal_eitsd_28jun2011.pdf, but with the updates just 

discussed.

The future base-case projection methodologies vary by sector. The 2030 reference case represents predicted 

emissions in the absence of any further controls beyond those Federal and State measures already 

promulgated before emissions processing on the Transport Rule began in December, 2010. For EGU 

emissions (ptipm sector), the emissions reflect state rules and federal consent decrees through December 1, 

2010. For mobile sources (on_noadj, on_moves_runpm, and on_moves_startpm sectors), all national 

measures for which data were available at the time of modeling have been included. The future base-case 

scenarios do reflect projected economic changes and fuel usage for EGU and mobile sectors. For nonEGU

point (ptnonipm sector) and nonpoint stationary sources (nonpt, ag, and afdust sectors), local control 

programs that might have been necessary for areas to attain the 1997 PM2.5 NAAQS annual standard, 2006 

PM NAAQS (24-hour) standard, and the 1997 ozone NAAQS are generally not included in the future basecase projections for most states. One exception are some NOx and VOC reductions associated with the New 

York, Virginia, and Connecticut State Implementation Plans (SIP), which were added as part of the 

comments received from the CSAPR and a larger effort to start including more local control information on 

stationary non-EGU sources; this is described further in Section 4.2. The following bullets summarize the 

projection methods used for sources in the various sectors, while additional details and data sources are given 

in Table 4-1.
13

IPM sector (ptipm): Unit-specific estimates from IPM, version 4.10, including CSAPR and the 

Mercury and Air Toxics Standards (MATS).

Non-IPM sector (ptnonipm): Projection factors and percent reductions reflect CSAPR (Transport 

Rule) comments and emission reductions due to control programs, plant closures, consent decrees 

and settlements, and 1997 and 2001 ozone State Implementation Plans in NY, CT, and VA. We also

used projection approaches for point-source livestock, and aircraft and gasoline stage II emissions

that are consistent with projections used for the sectors that contain the bulk of these emissions. 

Terminal area forecast (TAF) data aggregated to the national level were used for aircraft to account

for projected changes in landing/takeoff activity. Year-specific speciation was applied to some 

portions of this sector and was discussed in Section 3.

Average fires sector (avefire): No growth or control.

Agricultural sector (ag): Projection factors for livestock estimates based on expected changes in 

animal population from 2005 Department of Agriculture data; no growth or control for NH3

emissions from fertilizer application.

Area fugitive dust sector (afdust): Projection factors for dust categories related to livestock estimates 

based on expected changes in animal population; no growth or control for other categories in this 

sector.

Remaining Nonpoint sector (nonpt): Projection factors that implement Transport Rule Proposal 

comments and reflect emission reductions due to control programs. Residential wood combustion

projections based on growth in lower-emitting stoves and a reduction in higher emitting stoves. PFC 

projection factors reflecting impact of the final Mobile Source Air Toxics (MSAT2) rule. Gasoline 

stage II projection factors based on National Mobile Inventory Model (NMIM)-estimated VOC 

refueling estimates for future years. Oil and gas projection estimates are provided for the nonCalifornia Western Regional Air Partnership (WRAP) states as well as Oklahoma and Texas. Yearspecific speciation was applied to some portions of this sector and was discussed in Section 3.

Nonroad mobile sector (nonroad): Other than for California, this sector uses data from a run of 

NMIM that utilized the NR05d-Bond-final version of NONROAD (which is equivalent to 

NONROAD2008a), using future-year equipment population estimates and control programs to the 

year 2030 and using national level inputs. Final controls from the final locomotive-marine and small 

spark ignition OTAQ rules are included. California-specific data provided by the state of California, 

except NH3 used 2030 NMIM. Year-specific speciation was applied to some portions of this sector 

and is discussed in Section 4.3.5.

Locomotive, and non-Class 3 commercial marine sector (alm_no_c3): Projection factors for Class 1 

and Class 2 commercial marine and locomotives which reflect Transport Rule comments and activity 

growth and final locomotive-marine controls.

Class 3 commercial marine vessel sector (seca_c3): Base-year 2005 emissions grown and controlled 

to 2030, incorporating Transport Rule comments and controls based on Emissions Control Area 

(ECA) and International Marine Organization (IMO) global NOX and SO2 controls.

Onroad mobile sector with no adjustment for daily temperature (on_noadj): MOVES2010a run 

(state-month) for 2030 with results disaggregated to the county level in proportion to NMIM 2030

emissions estimates. The reference case does not include LDGHG or RFS2 impacts, but does include 

HDGHG impacts. Temperature impacts at the monthly average resolution. California-specific data 

provided by the state of California, except NH3 which was obtained from MOVES2010a. Other than 

California, this sector includes all non-refueling onroad mobile emissions (exhaust, evaporative, 

brake wear and tire wear modes) except exhaust mode gasoline PM and naphthalene emissions that 

are provided in the on_moves_startpm and on_moves_runpm sectors.
14

Onroad PM gasoline running mode sector (on_moves_startpm): Running mode MOVES2010a year 

2030 future-year state-month estimates for PM and naphthalene, apportioned to the county level 

using NMIM 2030 state-county ratios matched to vehicle and road types. The reference case does 

not include 2017-LDGHG or RFS2 impacts, but does include HDGHG impacts. Use future-year

temperature adjustment file for adjusting the 72°F emissions to ambient temperatures (for elemental 

and organic carbon) based on grid cell hourly temperature (note that lower temperatures result in 

increased emissions).

Onroad PM gasoline start mode sector (on_moves_startpm): Cold start MOVES2010a future-year 

2012 and 2014 state-month estimates for PM and naphthalene, apportioned to the county level using 

NMIM 2030 state-county ratios of local urban and rural roads by vehicle type. The reference case 

does not include 2017LDGHG or RFS2 impacts, but does include HDGHG impacts. Use future-year 

temperature adjustment file for adjusting the 72°F emissions (for elemental and organic carbon) to 

ambient temperatures based on grid cell hourly temperatures (lower temperatures result in increased 

emissions).

Other nonroad/nonpoint (othar): No growth or control. 

Other onroad sector (othon): No growth or control.

Other point (othpt): No growth or control.

Biogenic: 2005 emissions used for all future-year scenarios.
15

Table 4-1 summarizes the control strategies and growth assumptions by source type that were used to create 

the 2030 base-case emissions from the 2005v4.2 base-case inventories. All Mexico, Canada, and offshore 

oil emissions are unchanged in all future cases from those in the 2005 base case. Note that mercury (Hg) is 

listed in the pollutants column; however, we did not include Hg in our v4.2-based LDGHG modeling.

Lists of the control, closures, projection packets (datasets) used to create the LDGHG 2030 future reference 

case scenario inventories from the 2005 LDGHG base case are provided in Appendix B.

The remainder of this section is organized either by source sector or by specific emissions category within a 

source sector for which a distinct set of data were used or developed for the purpose of projections for the 

LDGHG Rule. This organization allows consolidation of the discussion of the emissions categories that are 

contained in multiple sectors, because the data and approaches used across the sectors are consistent and do 

not need to be repeated. Sector names associated with the emissions categories are provided in parentheses.
16

Table 4-1. Control strategies and growth assumptions for creating the LDGHG 2030 Reference case 

emissions inventories from the 2005 base case

Control Strategies and/or growth assumptions

(grouped by affected pollutants or standard and approach used to 

apply to the inventory)

Pollutants 

affected

Approach/ 

Reference

Non-EGU Point (ptnonipm sector) projection approaches

MACT rules, national, VOC: national applied by SCC, MACT

Boat Manufacturing 

Wood Building Products Surface Coating

Generic MACT II: Spandex Production, Ethylene manufacture

Large Appliances

Miscellaneous Organic NESHAP (MON): Alkyd Resins, Chelating Agents, Explosives, 

 Phthalate Plasticizers, Polyester Resins, Polymerized Vinylidene Chloride

Reinforced Plastics

Asphalt Processing & Roofing

Iron & Steel Foundries

Metal: Can, Coil

Metal Furniture

Miscellaneous Metal Parts & Products

Municipal Solid Waste Landfills

Paper and Other Web

Plastic Parts

Plywood and Composite Wood Products

Carbon Black Production

Cyanide Chemical Manufacturing

Friction Products Manufacturing

Leather Finishing Operations

Miscellaneous Coating Manufacturing

Organic Liquids Distribution (Non-Gasoline)

Refractory Products Manufacturing

Sites Remediation

VOC EPA, 2007a

Consent decrees on companies (based on information from the Office of Enforcement 

and Compliance Assurance – OECA) apportioned to plants owned/operated by the 

companies

VOC, CO, NOx, 

PM, SO2

1

DOJ Settlements: plant SCC controls for:

Alcoa, TX 

Premcor (formerly Motiva), DE

All 2

Refinery Consent Decrees: plant/SCC controls NOx, PM, SO2 3

Hazardous Waste Combustion PM 4

Municipal Waste Combustor Reductions –plant level PM 5

Hospital/Medical/Infectious Waste Incinerator Regulations NOX, PM, SO2 EPA, 2005

Large Municipal Waste Combustors – growth applied to specific plants All (including Hg) 5

MACT rules, plant-level, VOC: Auto Plants VOC 6

MACT rules, plant-level, PM & SO2: Lime Manufacturing PM, SO2 7

MACT rules, plant-level, PM: Taconite Ore PM 8

Livestock Emissions Growth from year 2002 to year 2030 (some farms in the point 

inventory)

NH3, PM 9

NESHAP: Portland Cement (09/09/10) – plant level based on Industrial Sector 

Integrated Solutions (ISIS) policy emissions in 2013. The ISIS results are from the 

ISIS-Cement model runs for the NESHAP and NSPS analysis of July 28, 2010 and 

include closures.

Hg, NOX, SO2, 

PM, HCl 10; EPA, 

2010

New York ozone SIP controls VOC, NOX,

HAP VOC 11

Additional plant and unit closures provided by state, regional, and the EPA agencies and 

additional consent decrees. Includes updates from CSAPR comments.

All 12

Emission reductions resulting from controls put on specific boiler units (not due to 

MACT) after 2005, identified through analysis of the control data gathered from the 

NOX, SO2, HCl Section 

4.2.13.2
17

Information Collection Request (ICR) from the Industrial/Commercial/Institutional 

Boiler NESHAP.

Reciprocating Internal Combustion Engines (RICE) NESHAP NOX, CO, PM, 

SO2

13

Ethanol plants that account for increased ethanol production due to RFS2 mandate All 14

State fuel sulfur content rules for fuel oil –effective only in Maine, New Jersey, and New 

York

SO2

15

Nonpoint (nonpt sector) projection approaches

Municipal Waste Landfills: projection factor of 0.25 applied All EPA, 2007a

Livestock Emissions Growth from year 2002 to year 2030 NH3, PM 9

New York, Connecticut, and Virginia ozone SIP controls VOC 11, 16

RICE NESHAP NOX, CO, VOC, 

PM, SO2

13

State fuel sulfur content rules for fuel oil –effective only in Maine, New Jersey, and New 

York

SO2

15

Residential Wood Combustion Growth and Change-outs from year 2005 to year 2030 All 17

Gasoline and diesel fuel Stage II refueling via MOVES2010 LDGHG month-specific 

inventories for 2030 with assumed RFS2 and LDGHG fuels

VOC, Benzene, 

Ethanol 18

Portable Fuel Container Mobile Source Air Toxics Rule 2 (MSAT2) inventory growth 

and control from year 2005 to year 2030 

VOC 19

Use Phase II WRAP 2018 Oil and Gas for year 2030 VOC, SO2, NOX, 

CO

Section 

4.2.14

Use 2008 Oklahoma and Texas Oil and Gas, and apply year 2021 projections for TX 

(last year available used as surrogate for 2030), and RICE NESHAP controls to 

Oklahoma emissions.

VOC, SO2, NOX, 

CO, PM

Section 

4.2.14

APPROACHES/REFERENCES- Non-EGU Stationary Sources:

1. Appendix B in the MATS Proposal TSD: 

http://www.epa.gov/ttn/chief/emch/toxics/proposed_toxics_rule_appendices.pdf

2. For Alcoa consent decree, used http:// cfpub.epa.gov/compliance/cases/index.cfm; for Motiva: used information sent by 

State of Delaware

3. Used data provided by the EPA, OAQPS, Sector Policies and Programs Division (SPPD).

4. Obtained from Anne Pope, the US EPA - Hazardous Waste Incinerators criteria and hazardous air pollutant controls 

carried over from 2002 Platform, v3.1. 

5. Used data provided by the EPA, OAQPS SPPD expert.

6. Percent reductions and plants to receive reductions based on recommendations by rule lead engineer, and are consistent 

with the reference: EPA, 2007a

7. Percent reductions recommended are determined from the existing plant estimated baselines and estimated reductions as 

shown in the Federal Register Notice for the rule. SO2 percent reduction are computed by 6,147/30,783 = 20% and 

PM10 and PM2.5 reductions are computed by 3,786/13,588 = 28%

8. Same approach as used in the 2006 Clean Air Interstate Rule (CAIR), which estimated reductions of “PM emissions by 

10,538 tpy, a reduction of about 62%.” Used same list of plants as were identified based on tonnage and SCC from 

CAIR: http://www.envinfo.com/caain/June04updates/tiop_fr2.pdf

9. Except for dairy cows and turkeys (no growth), based on animal population growth estimates from the US Department 

of Agriculture (USDA) and the Food and Agriculture Policy and Research Institute. See Section 4.2.10.

10. Data files for the cement sector provided by Elineth Torres, the EPA-SPPD, from the analysis done for the Cement 

NESHAP: The ISIS documentation and analysis for the cement NESHAP/NSPS is in the docket of that rulemakingdocket # EPA-HQ-OAR-2002-005. The Cement NESHAP is in the Federal Register: September 9, 2010 (Volume 75, 

Number 174, Page 54969-55066

11. New York NOX and VOC reductions obtained from Appendix J in NY Department of Environmental Conservation 

Implementation Plan for Ozone (February 2008): http://www.dec.ny.gov/docs/air_pdf/NYMASIP7final.pdf.

12. Appendix D of Cross-State Air Pollution Rule: 

ftp://ftp.epa.gov/EmisInventory/2005v4_2/transportrulefinal_eitsd_appendices_28jun2011.pdf

13. Appendix F in the Proposed (Mercury and Air) Toxics Rule TSD: 
18

http://www.epa.gov/ttn/chief/emch/toxics/proposed_toxics_rule_appendices.pdf

14. The 2008 data used came from Illinois’ submittal of 2008 emissions to the NEI.

15. Based on available, enforceable state sulfur rules as of November, 2010: 

http://www.ilta.org/LegislativeandRegulatory/MVNRLM/NEUSASulfur%20Rules_09.2010.pdf ,

http://www.mainelegislature.org/legis/bills/bills_124th/billpdfs/SP062701.pdf , 

http://switchboard.nrdc.org/blogs/rkassel/governor_paterson_signs_new_la.html , 

http://green.blogs.nytimes.com/2010/07/20/new-york-mandates-cleaner-heating-oil/

16. VOC reductions in Connecticut and Virginia obtained from CSAPR comments.

17. Growth and Decline in woodstove types based on industry trade group data, See Section 4.2.11.

18. MOVES (2010a) results for onroad refueling including activity growth from VMT, Stage II control programs at gasoline 

stations, and phase in of newer vehicles with onboard Stage II vehicle controls. 

http://www.epa.gov/otaq/models/moves/index.htm

19. VOC, benzene, and ethanol emissions for 2030 based on MSAT2 rule and ethanol fuel assumptions (EPA, 2007b)

Onroad mobile and nonroad mobile controls 

(list includes all key mobile control strategies but is not exhaustive)

National Onroad Rules:

Tier 2 Rule: Signature date February, 2000

2007 Onroad Heavy-Duty Rule: February, 2009

Final Mobile Source Air Toxics Rule (MSAT2): February, 2007

Renewable Fuel Standard: March, 2010

Light Duty Greenhouse Gas Rule: May, 2010

Corporate Average Fuel Economy standards for 2008-2011

Heavy-Duty Vehicle Greenhouse Gas Rule: August 2011

all 1

Local Onroad Programs:

National Low Emission Vehicle Program (NLEV): March, 1998

Ozone Transport Commission (OTC) LEV Program: January,1995

VOC 2

National Nonroad Controls:

Clean Air Nonroad Diesel Final Rule – Tier 4: June, 2004

Control of Emissions from Nonroad Large-Spark Ignition Engines and Recreational 

Engines (Marine and Land Based): “Pentathalon Rule”: November, 2002

Clean Bus USA Program: October, 2007

Control of Emissions of Air Pollution from Locomotives and Marine Compression-Ignition 

Engines Less than 30 Liters per Cylinder: October, 2008

Locomotive and marine rule (May 6, 2008)

Marine SI rule (October 4, 1996)

Nonroad large SI and recreational engine rule (November 8, 2002)

Nonroad SI rule (October 8, 2008)

Phase 1 nonroad SI rule (July 3, 1995)

Tier 1 nonroad diesel rule (June 17, 2004)

all 3,4,5

Aircraft (emissions are in the nonEGU point inventory):

Itinerant (ITN) operations at airports to year 2030 all 6

Locomotives:

Energy Information Administration (EIA) fuel consumption projections for freight rail

Clean Air Nonroad Diesel Final Rule – Tier 4: June 2004

Locomotive Emissions Final Rulemaking, December 17, 1997

Locomotive rule: April 16, 2008

Control of Emissions of Air Pollution from Locomotives and Marine: May 2008

all EPA, 2009; 

3; 4; 5

Commercial Marine:

Category 3 marine diesel engines Clean Air Act and International Maritime Organization

standards (April, 30, 2010) –also includes CSAPR comments.

EIA fuel consumption projections for diesel-fueled vessels

Clean Air Nonroad Diesel Final Rule – Tier 4

Emissions Standards for Commercial Marine Diesel Engines, December 29, 1999

Locomotive and marine rule (May 6, 2008)

Tier 1 Marine Diesel Engines, February 28, 2003

all 7, 3; EPA, 

2009
19

APPROACHES/REFERENCES – Mobile Sources

1. http://epa.gov/otaq/hwy.htm

2. Only for states submitting these inputs: http://www.epa.gov/otaq/lev-nlev.htm

3. http://www.epa.gov/nonroad-diesel/2004fr.htm

4. http://www.epa.gov/cleanschoolbus/

5. http://www.epa.gov/otaq/marinesi.htm

6. Federal Aviation Administration (FAA) Terminal Area Forecast (TAF) System, January 2010: 

http://www.apo.data.faa.gov/main/taf.asp

7. http://www.epa.gov/otaq/oceanvessels.htm

4.1 Stationary source projections: EGU sector (ptipm)

The future-year data for the ptipm sector used in the air quality modeling were created using version 4.10 

(v4.10) of the Integrated Planning Model (IPM) (http://www.epa.gov/airmarkt/progsregs/epaipm/index.html). The IPM is a multiregional, dynamic, deterministic linear programming model of the U.S. 

electric power sector. Version 4.10 reflects state rules and consent decrees through December 1, 2010 and 

incorporates information on existing controls collected through the Information Collection Request (ICR), 

and information from comments received on the IPM-related Notice of Data Availability (NODA) published 

on September 1, 2010. The 2030 IPM emissions reflect the CSAPR as finalized in July 2011 and the final 

Mercury and Air Toxics (MATS) rule. They do not reflect the Boiler MACT regulatory assumptions because 

the rule was stayed at the time the modeling was performed. IPM v4.10 Final included the addition of over 

20 GW of existing Activated Carbon Injection (ACI) reported to the EPA via the ICR. Units with SO2 or 

NOX advanced controls (e.g., scrubber, SCR) that were not required to run for compliance with Title IV, 

New Source Review (NSR), state settlements, or state-specific rules were modeled by IPM to either operate 

those controls or not based on economic efficiency parameters. 

IPM 4.10 includes adjustments to assumptions regarding the performance of acid gas control technologies, 

new costs imposed on fuel-switching (e.g., bituminous to sub-bituminous), correction of lignite availability 

to some plants, incorporation of additional planned retirements, a more inclusive implementation of the 

scrubber upgrade option, and the availability of a scrubber retrofit to waste-coal fired fluidized bed 

combustion units without an existing scrubber. Further details on the future-year EGU emissions inventory 

used for this rule can be found in the incremental documentation of the IPM v.4.10 platform, available at 

http://www.epa.gov/airmarkets/progsregs/epa-ipm/BaseCasev410.html. A complete list of state regulations, 

NSR settlements, and state settlements included in the IPM modeling is given in Appendices 3-2, 3-3, and 3-

4 beginning on p. 68 of http://www.epa.gov/airmarkets/progsregs/epaipm/CSAPR/docs/DocSuppv410_FTransport.pdf. 

Directly emitted PM emissions (i.e., PM2.5 and PM10) from the EGU sector are computed via a post 

processing routine which applies emission factors to the IPM-estimated fuel throughput based on fuel, 

configuration and controls to compute the filterable and condensable components of PM. This methodology 

is documented in the IPM CSAPR TSD.

4.2 Stationary source projections: non-EGU sectors (ptnonipm, nonpt, ag, 

afdust)

To project U.S. stationary sources other than the ptipm sector, we applied growth factors and/or controls to 

certain categories within the ptnonipm, nonpt, ag and afdust platform sectors. This subsection provides 

details on the data and projection methods used for these sectors. In estimating future-year emissions, we 

assumed that emissions growth does not track with economic growth for many stationary non-IPM sources. 
20

This “no-growth” assumption is based on an examination of historical emissions and economic data. More 

details on the rationale for this approach can be found in Appendix D of the Regulatory Impact Assessment 

for the PM NAAQS rule (EPA, 2006).

The starting point was the emission projections done for the 2005v4.2 platform for the CSAPR, which 

incorporated responses to public comments on the modeling inventories. The 2012 and 2014 projection 

factors developed for the CSAPR (see http://www.epa.gov/ttn/chief/emch/index.html#final) were updated to 

reflect year 2030 projections.

Year-specific projection factors for year 2030 were used for creating the 2030 reference case unless noted 

otherwise. Growth factors (and control factors) are provided in the following sections where feasible. 

However, some sectors used growth or control factors that varied geographically and their contents could not 

be provided in the following sections (e.g., gasoline distribution varies by state and pollutant and has 

hundreds of records).

Table 4-2 lists the stationary non-EGU inputs and projection factors that were applied to account for year 

2030 RFS2 mandate impacts on emissions to the reference and control cases. These inputs are discussed in 

more detail in Section 4.2.1 through Section 4.2.9. All other stationary non-EGU projections, controls and 

plant closure information not related to the RFS2 impacts are discussed in Section 4.2.10 through Section 

4.2.14.

Table 4-2. LDGHG FRM reference case stationary non-EGU source-related projection methods

Input Type Sector(s) Description

Corn ethanol plants SMOKE ORL file that 

replaces 2005 base case 

ORL file

ptnonipm Based on RFS2 analysis and production 

volumes. Point source format.

Biodiesel plants SMOKE ORL file ptnonipm Accounts for facilities with current production 

capacities, to support RFS2 biodiesel 

production. Point source format.

Cellulosic fuel 

production

SMOKE ORL file nonpt Accounts for cellulosic ethanol and cellulosic 

diesel to support RFS2 cellulosic production. 

County-level (nonpoint) format.

Ethanol transport 

and distribution

SMOKE ORL file nonpt Accounts for ethanol vapor losses and 

spillage at any point in the transport and 

distribution chain. County-level (nonpoint) 

format.

Portable Fuel 

Containers (PFCs)

SMOKE ORL nonpt NONROAD-model based emissions from 

PFCs, including vapor displacement, tank 

permeation, and diurnal evaporation. Countylevel (nonpoint) format.

Onroad refueling SMOKE ORL file nonpt MOVES-based gasoline and diesel fuel 

spillage and displacement vapor losses. 

County-level (nonpoint) format, monthly 

resolution.

Refinery 

adjustments

Projection factors ptnonipm Not in base cases, accounts for changes in 

various refinery processes due to 

incorporation of RFS2 fuels.
21

Ethanol transport 

gasoline & ethanol 

blends

Projection factors nonpt, 

ptnonipm

Not in base cases, accounts for RFS impacts 

on emissions from bulk plant storage, refinery 

to bulk terminal, and bulk terminal to pump.

Upstream 

agricultural 

adjustments

Projection factors afdust, ag, 

nonpt, 

ptnonipm

Not in base cases, accounts for changes in ag 

burning/dust, fertilizer application/production, 

livestock dust/waste and pesticide 

application/production.

4.2.1 Ethanol plants (ptnonipm)

As discussed in Section 2.4.1, for 2005 we replaced all corn ethanol plants that OTAQ had supplied from the 

RFS2 rule –see Section 2.1.2 in the CSAPR Final TSD- with an updated list. Additional ethanol plants cited 

for development in support of increased ethanol production for RFS2 are the cause for the increased number 

of facilities and emissions. Table 4-3 provides the summaries for the corn ethanol plants in the 2030 cases.

Table 4-3. 2030 corn ethanol plant emissions [tons]

Pollutant 2030

1,3-Butadiene 0.0003

Acrolein 10.5

Formaldehyde 13.3

Benzene 5.7

Acetaldehyde 314.4

CO 7,023

NOX 7,396

PM10 10,107

PM2.5 3,691

SO2 9,001

VOC 10,754

4.2.2 Biodiesel plants ptnonipm)

OTAQ developed an inventory of biodiesel plants for 2030 that were sited at existing plant locations in 

support of producing biodiesel fuels for the RFS2 mandate. The RFS2 calls for 1.67 billion gallons per year 

(Bgal) of biodiesel fuel production by year 2030. Only plants with current production capacities were 

assumed to be operating in 2030. Total plant capacity at these existing facilities is limited to just over 1 

Bgal. There was no attempt to site future year plants to account for the need to match biodiesel production 

needed for RFS2. Therefore, OTAQ applied scalar adjustments to each individual biodiesel plant to match 

the 2030 production level of 1.67 Bgal.. Once facility-level production capacities were scaled, emission 

factors were applied based on soybean oil feedstock. Inventories were modeled as point sources with Google 

Earth and web searching validating facility coordinates and correcting state-county FIPS. Table 4-4 provides 

the 2030 biodiesel plant emissions estimates.

Table 4-4. 2030 biodiesel plant emissions [tons]

Pollutant 2030

Acrolein 3.56E-04

Formaldehyde 2.56E-03

Benzene 5.42E-05
22

Acetaldehyde 4.14E-04

CO 836

NOX 1,349

PM10 114

PM2.5 114

SO2 10

VOC 73

4.2.3 Portable fuel container growth and control (nonpt)

We obtained future-year VOC emissions from Portable Fuel Containers (PFCs) from inventories developed 

and modeled for the EPA’s MSAT2 rule (EPA, 2007b). The 10 PFC SCCs are summarized below (note that 

the full SCC descriptions for these SCCs include “Storage and Transport; Petroleum and Petroleum Product 

Storage” as the beginning of the description). 

2501011011 Residential Portable Fuel Containers: Permeation

2501011012 Residential Portable Fuel Containers: Evaporation

2501011013 Residential Portable Fuel Containers: Spillage During Transport

2501011014 Residential Portable Fuel Containers: Refilling at the Pump: Vapor Displacement

2501011015 Residential Portable Fuel Containers: Refilling at the Pump: Spillage

2501012011 Commercial Portable Fuel Containers: Permeation

2501012012 Commercial Portable Fuel Containers: Evaporation

2501012013 Commercial Portable Fuel Containers: Spillage During Transport

2501012014 Commercial Portable Fuel Containers: Refilling at the Pump: Vapor Displacement

2501012015 Commercial Portable Fuel Containers: Refilling at the Pump: Spillage

Additional information on the PFC inventories is available in Section 2.2.3 of the documentation for the 

2002 Platform (http://www.epa.gov/ttn/chief/emch/index.html#2002). 

The future-year emissions reflect projected increases in fuel consumption, state programs to reduce PFC 

emissions, standards promulgated in the MSAT2 rule, and impacts of the Renewable Fuel Standard (RFS) on 

gasoline volatility. OTAQ provided year 2030 PFC emissions that include estimated Reid Vapor Pressure 

(RVP) and oxygenate impacts on VOC emissions, and more importantly, large increases in ethanol

emissions from RFS2. These emission estimates also include refueling from the NONROAD model for gas 

can vapor displacement, changes in tank permeation and diurnal emissions from evaporation. Because these 

PFC inventories contain ethanol and benzene, we developed a VOC E-profile that integrated ethanol and 

benzene, see Section 3 for more details. Emissions for 2030 are provided in Table 4-5.

Table 4-5. PFC emissions for 2030 [tons]

Pollutant 2030

VOC 146,593

Benzene 1,622

Ethanol 31,632

4.2.4 Cellulosic fuel production (nonpt)

OTAQ developed county-level inventories for cellulosic diesel and cellulosic ethanol production for 2030 to 

satisfy RFS2 requirements. The methodology for building cellulosic plant emissions inventories is fairly 

similar conceptually to that for building the biodiesel plant inventories. First, we assume that cellulosic 
23

diesel and cellulosic ethanol are produced in the same counties where current production capacity exists, 

based on RFS2 FRM inventories. The total county production capacity was over 16 Bgal; therefore, OTAQ 

applied a scalar adjustment to each county’s production capacity to match the 2030 production estimate of 

11.44 Bgal (6.5 Bgal diesel and 4.92Bgal ethanol): 0.715 for 2030. Once county-level cellulosic production 

capacities were scaled, emission factors were applied. Table 4-6 provides the year 2030 cellulosic plant 

emissions estimates. These emission factors were obtained from the RFS2 rule for criteria pollutants; 

emission factors for toxics were derived from 2005 NEI data.

Table 4-6. 2030 cellulosic plant emissions [tons]

Pollutant 2030

Acrolein 61

Formaldehyde 168

Benzene 79

Acetaldehyde 2,286

CO 124,336

Ethanol 5,530

NH3 1.6

NOX 185,745

PM10 21,862

PM2.5 10,986

SO2 14,475

VOC 15,489

We had no refined information on potential VOC speciation differences between cellulosic diesel and 

cellulosic ethanol sources. Therefore, we summed up cellulosic diesel and cellulosic ethanol sources and 

used the same SCC (30125010: Industrial Chemical Manufacturing, Ethanol by Fermentation production) for 

VOC speciation as was used for corn ethanol plants. However, these cellulosic inventories contain ethanol; 

therefore we developed a VOC E-profile that integrated ethanol, see Section 3 for more details.

4.2.5 Ethanol transport and distribution (nonpt)

OTAQ developed county-level inventories for ethanol transport and distribution for 2030 to account for 

losses for the processes such as truck, rail and waterways loading/unloading and intermodal transfers such as 

highway-to-rail, highways-to-waterways, and all other possible combinations of transfers. Emission rates 

were applied based on June 2008 AP-42 factors and ethanol versus gasoline vapor mass equations. These 

emissions are entirely evaporative and therefore limited to VOC and are summarized in Table 4-7. The 

leading descriptions are “Industrial Processes; Food and Agriculture; Ethanol Production” for each SCC.

Table 4-7. 2030 VOC losses (Emissions) due to ethanol transport and distribution [tons]

SCC Description 2030

30205031 Denatured Ethanol Storage Working Loss 34,642

30205052 Ethanol Loadout to Truck 23,794

30205053 Ethanol Loadout to Railcar 11,991

4.2.6 Refinery adjustments (ptnonipm)

Refinery emissions were adjusted for changes in fuels due to the RFS2 mandate. These adjustments were 

provided by OTAQ and impact processes such as process heaters, catalytic cracking units, blowdown 
24

systems, wastewater treatment, condensers, cooling towers, flares and fugitive emissions. The impact of the 

RFS2-based reductions is shown in Table 4-8.

Table 4-8. Impact of refinery adjustments on 2030 emissions [tons]

Pollutant Reductions 2030

CO 13,602

NOX 34,850

PM10 7,550

PM2.5 4,365

SO2 24,014

VOC 6,428

4.2.7 Ethanol transport gasoline and blends (ptnonipm, nonpt)

Emissions changes in the transport of changing fuels from the RFS2 mandate impact several processes 

including bulk plant storage (BPS), refinery to bulk terminal (RBT) and bulk terminal to pump (BTP). These 

impacts, provided by OTAQ, result in approximately 46,000 tons of VOC reductions in 2030 for these 

processes. See Appendix E for cross-walk between SCC and each type of petroleum transport and storage.

4.2.8 Upstream agricultural adjustments (afdust, ag, nonpt, ptnonipm)

Changes in domestic biofuel volumes, resulting from the RFS2 fuels mandate, impact upstream agriculturalrelated source categories in several emissions modeling sectors. These source categories include fertilizer 

application, pesticide application and livestock waste (NH3 only), agricultural tilling, unloading and livestock 

dust (PM only) and fertilizer production mixing and blending, pesticide production and agricultural burning 

(all pollutants). As seen in Table 4-9, the cumulative impact of these source-specific changes is a net 

increase in emissions for upstream agricultural sources.

Table 4-9. Upstream agricultural emission increases due to RFS2 fuels in 2030 [tons]

Pollutant Increases 2030

CO 416

NH3 61,793

NOX 500

PM10 59,004

PM2.5 8,972

SO2 95

VOC 23

4.2.9 Livestock emissions growth (ag, afdust)

Growth in ammonia (NH3) and dust (PM10 and PM2.5) emissions from livestock in the ag, afdust and 

ptnonipm sectors was based on projections of growth in animal population. Error! Reference source not 

ound. provides the growth factors from the 2005 base-case emissions to year 2030 scenarios for animal 

categories applied to the ag, afdust, and ptnonipm sectors for livestock-related SCCs.

Table 4-10. Growth factors from year 2005 to 2030 for animal operations

Animal Category 2030

Dairy Cow 1.0000

Beef 1.0385
25

Pork 1.1666

Broilers 1.6426

Turkeys 1.0000

Layers 1.4491

Poultry Average 1.4991

Overall Average 1.1745

Except for dairy cows and turkey production, the animal projection factors are derived from national-level 

animal population projections from the U.S. Department of Agriculture (USDA) and the Food and 

Agriculture Policy and Research Institute (FAPRI). For dairy cows and turkeys, we assumed that there 

would be no growth in emissions. This assumption was based on an analysis of historical trends in the 

number of such animals compared to production rates. Although productions rates have increased, the 

number of animals has declined. Thus, we do not believe that production forecasts provide representative 

estimates of the future number of cows and turkeys; therefore, we did not use these forecasts for estimating 

future-year emissions from these animals. In particular, the dairy cow population is projected to decrease in 

the future as it has for the past few decades; however, milk production will be increasing over the same 

period. Note that the ammonia emissions from dairies are not directly related to animal population but also 

nitrogen excretion. With the cow numbers going down and the production going up we suspect the excretion 

value will be changing, but we assumed no change because we did not have a quantitative estimate.

The inventory for livestock emissions used 2002 emissions values therefore, our projection method projected 

from 2002 rather than from 2005.

Appendix E in the 2002v3 platform documentation provides the animal population data and regression 

curves used to derive the growth factors: 

http://www.epa.gov/scram001/reports/Emissions%20TSD%20Vol2_Appendices_01-15-08.pdf. Appendix F 

in the same document provides the cross references of livestock sources in the ag, afdust and ptnonipm 

sectors to the relevant animal categories.

4.2.10 Residential wood combustion growth (nonpt)

We projected residential wood combustion (RWC) emissions based on the expected increase in the number 

of low-emitting wood stoves and the corresponding decrease in other types of wood stoves. As newer, 

cleaner woodstoves replace older, higher-polluting wood stoves, there will be an overall reduction of the 

emissions from these sources. The approach cited here was developed as part of a modeling exercise to 

estimate the expected benefits of the woodstoves change-out program (http://www.epa.gov/burnwise). 

Details of this approach can be found in Section 2.3.3 of the PM NAAQS Regulatory Impact Analysis (EPA, 

2006).

The specific assumptions we made were:

 Fireplaces, source category code (SCC)=2104008001: increase 1%/year

 Old woodstoves, SCC=2104008002, 2104008010, or 2104008051: decrease 2%/year

 New woodstoves, SCC=2104008003, 2104008004, 2104008030, 2104008050, 2104008052 or 

2104008053: increase 2%/year

For the general woodstoves and fireplaces category (SCC 2104008000) we computed a weighted average 

distribution based on 19.4% fireplaces, 71.6% old woodstoves, 9.1% new woodstoves using 2002v3 

Platform missions for PM2.5. These fractions are based on the fraction of emissions from these processes in 

the states that did not have the “general woodstoves and fireplaces” SCC in the 2002v3 NEI. This approach 
26

results in an overall decrease of 1.056% per year for this source category. Table 4-11 presents the projection 

factors used to project the 2005 base case (2002 emissions) for RWC. 

Table 4-11. Projection factors for growing year 2005 residential wood combustion sources

SCC SCC Description 2030

2104008000 Total: Woodstoves and Fireplaces 0.70

2104008001 Fireplaces: General 1.28 2104008070 Outdoor Wood Burning Equipment

2104008002 Fireplaces: Insert; non-EPA certified

2104008010 Woodstoves: General 0.44

2104008051 Non-catalytic Woodstoves: Non-EPA certified

2104008003 Fireplaces: Insert; EPA certified; non-catalytic

1.56

2104008004 Fireplaces: Insert; EPA certified; catalytic

2104008030 Catalytic Woodstoves: General

2104008050 Non-catalytic Woodstoves: EPA certified

2104008052 Non-catalytic Woodstoves: Low Emitting

2104008053 Non-catalytic Woodstoves: Pellet Fired

4.2.11 Gasoline Stage II growth and control (nonpt, ptnonipm)

Emissions from Stage II gasoline operations in the 2005 v4.2 platform are contained in both nonpt and 

ptnonipm sectors. The only SCC in the nonpt inventory used for gasoline Stage II emissions is 2501060100 

(Storage and Transport; Petroleum and Petroleum Product Storage; Gasoline Service Stations; Stage II: 

Total). The following SIC and SCC codes are associated with gasoline Stage II emissions in the ptnonipm 

sector:

 SIC 5541 (Automotive Dealers & Service Stations, Gasoline Service Stations, Gasoline service 

stations)

 SCC 40600401 (Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum 

Products;Filling Vehicle Gas Tanks - Stage II;Vapor Loss w/o Controls)

 SCC 40600402 (Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum 

Products;Filling Vehicle Gas Tanks - Stage II;Liquid Spill Loss w/o Controls)

 SCC 40600403 (Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum 

Products;Filling Vehicle Gas Tanks - Stage II;Vapor Loss w/o Controls)

 SCC 40600499 (Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum 

Products;Filling Vehicle Gas Tanks - Stage II;Not Classified

In the LDGHG modeling, these SCCs were removed from the nonpt and ptnonipm inventories and replaced 

with a separate refueling inventory in the nonpt sector. This refueling inventory was generated from draft 

MOVES2010b, provided monthly emissions for both gasoline and diesel refueling, and was year and 

scenario specific. The speciation of the refueling emissions integrated ethanol as well as BAFM (EBAFM) 

and was speciated using E-profiles, see Section 3 for more details.

For the 2030 reference case, the MOVES refueling results account for projected fuel properties, VMT 

growth over time, the phase-in of onboard vapor control, and the phase-in of previously finalized fuel 

consumption regulations. 
27

4.2.12 Aircraft growth (ptnonipm)

These 2005 point-source emissions are projected to future years by applying activity growth using data on 

itinerant (ITN) operations at airports. The ITN operations are defined as aircraft take-offs whereby the 

aircraft leaves the airport vicinity and lands at another airport, or aircraft landings whereby the aircraft has 

arrived from outside the airport vicinity. We used projected ITN information available from the Federal 

Aviation Administration’s (FAA) Terminal Area Forecast (TAF) System: 

http://www.apo.data.faa.gov/main/taf.asp (publication date January 2010). This information is available for 

approximately 3,300 individual airports, for all years up to 2030. We aggregated and applied this 

information at the national level by summing the airport-specific (U.S. airports only) ITN operations to 

national totals by year and by aircraft operation, for each of the four available operation types: commercial, 

general, air taxi and military. We computed growth factors for each operation type by dividing future-year 

ITN by 2005-year ITN. We assigned factors to inventory SCCs based on the operation type. 

The methods that the FAA used for developing the ITN data in the TAF are documented in:

http://www.faa.gov/data_research/aviation/aerospace_forecasts/2009-

2025/media/2009%20Forecast%20Doc.pdf

Table 4-12 provides the national growth factors for aircraft; all factors are applied to year 2005 emissions. 

For example, year 2030 commercial aircraft emissions are 50.59% higher than year 2005 emissions.

Table 4-12. Factors used to project 2005 base-case aircraft emissions to year 2030

SCC SCC Description Projection Factor

2275001000 Military aircraft 1.0275

2275020000 Commercial aircraft 1.5059

2275050000 General aviation 0.9916

2275060000 Air taxi 1.0259

27501015 Internal Combustion Engines;Fixed Wing Aircraft L & TO 

Exhaust;Military;Jet Engine: JP-5

1.0275

27502001 Internal Combustion Engines;Fixed Wing Aircraft L & TO 

Exhaust;Commercial;Piston Engine: Aviation Gas 1.5059

27502011 Internal Combustion Engines;Fixed Wing Aircraft L & TO 

Exhaust;Commercial;Jet Engine: Jet A 1.5059

27505001 Internal Combustion Engines;Fixed Wing Aircraft L & TO 

Exhaust;Civil;Piston Engine: Aviation Gas 0.9916

27505011 Internal Combustion Engines;Fixed Wing Aircraft L & TO 

Exhaust;Civil;Jet Engine: Jet A 0.9916

27601014 Internal Combustion Engines;Rotary Wing Aircraft L & TO 

Exhaust;Military;Jet Engine: JP-4

1.0275

27601015 Internal Combustion Engines;Rotary Wing Aircraft L & TO 

Exhaust;Military;Jet Engine: JP-5

1.0275

We did not apply growth factors to any point sources with SCC 27602011 (Internal Combustion Engines; 

Rotary Wing Aircraft L & TO Exhaust; Commercial; Jet Engine: Jet A) because the facility names 

associated with these point sources appeared to represent industrial facilities rather than airports. This SCC 

is only in one county, Santa Barbara, California (State/County FIPS 06083).

4.2.13 Stationary source control programs, consent decrees & settlements, and 

plant closures (ptnonipm, nonpt)

We applied emissions reduction factors to the 2005 emissions for particular sources in the ptnonipm and 

nonpt sectors to reflect the impact of stationary-source control programs including consent decrees, 
28

settlements, and plant closures. Some of the controls described in this section were obtained from comments 

on the CSAPR proposal. Here we describe the contents of the controls and closures for the 2030 reference

case. Detailed summaries of the impacts of the control programs are provided in Appendix D of the CSAPR 

TSD: ftp://ftp.epa.gov/EmisInventory/2005v4_2/transportrulefinal_eitsd_appendices_28jun2011.pdf.

Controls from the NOX SIP call were assumed to have been implemented by 2005 and captured in the 2005 

base case (2005v2 point inventory). This assumption was confirmed by review of the 2005 NEI that showed 

reductions from Large Boiler/Turbines and Large Internal Combustion Engines in the Northeast states 

covered by the NOx SIP call. The future-year base controls consist of the following:

We did not include MACT rules where compliance dates were prior to 2005, because we assumed 

these were already reflected in the 2005 inventory. The EPA OAQPS Sector Policies and Programs 

Division (SPPD) provided all controls information related to the MACT rules, and this information is 

as consistent as possible with the preamble emissions reduction percentages for these rules.

Various emissions reductions from the CSAPR comments, including but not limited to: fuel 

switching at units, shutdowns, future-year emission limits, ozone SIP VOC controls for some sources 

in Virginia and Connecticut, and state and local control programs.

Evolutionary information gathering of plant closures (i.e., emissions were zeroed out for future years) 

were also included where information indicated that the plant was actually closed after the 2005 base 

year and prior to CSAPR and LDGHG modeling that began in the fall of 2010. We also applied unit 

and plant closures received from the CSAPR comments. However, plants projected to close in the 

future (post-2010) were not removed in the future years because these projections can be inaccurate 

due to economic improvements. We also applied cement kiln (unit) and cement plant closures 

discussed later in Section 4.2.6.1. More detailed information on the overall state-level impacts of all 

control programs and projection datasets, including units and plants closed in the 2012 and 2014 

base-case ptnonipm inventories are provided in Appendix D of the CSAPR TSD: 

ftp://ftp.epa.gov/EmisInventory/2005v4_2/transportrulefinal_eitsd_appendices_28jun2011.pdf. The 

magnitude of all unit and plant closures on the non-EGU point (ptnonipm) sector 2005 base-case 

emissions is shown in Table 4-13 below.

Table 4-13. Summary of Non-EGU Emission Reductions Applied to the 2005 Inventory due to Unit and 

Plant Closures

CO NH3 NOX PM10 PM2.5 SO2 VOC

Reductions 125,162 636 109,237 21,143 12,600 190,734 26,750

In addition to plant closures, we included the effects of the Department of Justice Settlements and 

Consent Decrees on the non-EGU (ptnonipm) sector emissions. We also included estimated impacts 

of HAP standards per Section 112, 129 of the Clean Air Act on the non-EGU (ptnonipm) and 

nonpoint (nonpt) sector emissions, based on expected CAP co-benefits to sources in these sectors.

Numerous controls have compliance dates beyond 2008; these include refinery and the Office of 

Compliance and Enforcement (OECA) consent decrees, Department of Justice (DOJ) settlements, as 

well as most national VOC MACT controls. Additional OECA consent decree information is 

provided in Appendix B of the Proposed Toxics Rule TSD: 

http://www.epa.gov/ttn/chief/emch/toxics/proposed_toxics_rule_appendices.pdf. The detailed data 

used are available at the website listed in Section 1.
29

Refinery consent decrees controls at the facility and SCC level (collected through internal 

coordination on refineries by the EPA).

Fuel sulfur fuel limits were enforceable for Maine, New Jersey and New York. These fuel limits 

were incremental and not applicable until after 2012.

Criteria air pollutant (cap) reductions a cobenefit to RICE NESHAP controls, including SO2 RICE 

cobenefit controls.

We applied New York State Implementation Plan available controls for the 1997 8-hour Ozone 

standard for non-EGU point and nonpoint NOX and VOC sources based on NY State Department of 

Environmental Conservation February 2008 guidance. These reductions are found in Appendix J in: 

http://www.dec.ny.gov/docs/air_pdf/NYMASIP7final.pdf. See Section 3.2.6 in the CSAPR TSD: 

ftp://ftp.epa.gov/EmisInventory/2005v4_2/transportrulefinal_eitsd_28jun2011.pdf.

Most of the control programs were applied as replacement controls, which means that any existing percent 

reductions (“baseline control efficiency”) reported in the NEI were removed prior to the addition of the 

percent reductions due to these control programs. Exceptions to replacement controls are “additional” 

controls, which ensure that the controlled emissions match desired reductions regardless of the baseline 

control efficiencies in the NEI. We used the “additional controls” approach for many permit limits, 

settlements and consent decrees where specific plant and multiple-plant-level reductions/targets were desired 

and at municipal waste landfills where VOC was reduced 75% via a MACT control using projection factors 

of 0.25.

4.2.13.1 Reductions from the Portland Cement NESHAP

As indicated in 
30

Table 4-1, the Industrial Sectors Integrated Solutions (ISIS) model (EPA, 2010) was used to project the 

cement industry component of the ptnonipm emissions modeling sector to 2013. There were no future year 

estimates for year 2030, so 2013 estimates were used for the 2030 Reference case. This approach provided 

reductions of criteria and hazardous air pollutants, including mercury. The ISIS cement emissions were 

developed in support for the Portland Cement NESHAPs and the NSPS for the Portland cement 

manufacturing industry.

The ISIS model produced a Portland Cement NESHAP policy case of multi-pollutant emissions for 

individual cement kilns (emission inventory units) that were relevant for years 2013 through 2017. These 

ISIS-based emissions included information on new cement kilns, facility and unit-level closures, and updated 

policy case emissions at existing cement kilns. The units that opened or closed before 2010 were included in 

the projections as were the ISIS-based policy case predictions of emissions reductions and activity growth.

The ISIS model results for the future show a continuation of the recent trend in the cement sector of the 

replacement of lower capacity, inefficient wet and long dry kilns with bigger and more efficient preheater 

and precalciner kilns. Multiple regulatory requirements such as the NESHAP and NSPS currently apply to 

the cement industry to reduce CAP and HAP emissions. Additionally, state and local regulatory 

requirements might apply to individual cement facilities depending on their locations relative to ozone and 

PM2.5 nonattainment areas. The ISIS model provides the emission reduction strategy that balances: 1) 

optimal (least cost) industry operation, 2) cost-effective controls to meet the demand for cement, and 3) 

emission reduction requirements over the time period of interest. Table 4-14 shows the magnitude of the 

ISIS-based cement industry reductions in the future-year emissions that represent 2013 (and 2030 for 

LDGHG), and the impact that these reductions have on total stationary non-EGU point source (ptnonipm) 

emissions.

Table 4-14. Future-year ISIS-based cement industry annual reductions (tons/yr) 

for the non-EGU (ptnonipm) sector

Pollutant

Cement Industry 

emissions in 2005

Decrease in cement 

industry emissions 

in 2030 vs 2005

% decrease in 

ptnonipm from 

cement reduction

NOX 193,000 56,740 2.4%

PM2.5 14,400 7,840 1.8%

SO2 128,400 106,000 5.0%

VOC 6,900 5,570 0.4%

HCl 2,900 2,220 4.5%

4.2.13.2 Boiler reductions not associated with the MACT rule

The Boiler MACT ICR collected data on existing controls. We used an early version of a data base 

developed for that rulemaking entitled “survey_database_2008_results2.mdb” (EPA-HQ-OAR-2002-0058-

0788) which is posted under the Technical Information for the Boiler MACT major source rule 

(http://www.epa.gov/ttn/atw/boiler/boilerpg.html). We extracted all controls that were installed after 2005,

determined a percent reduction, and verified with source owners that these controls were actively in use. In 

many situations we learned that the controls were on site but were not in use. A summary of the plant-unit 

specific reductions that were verified to be actively in use are summarized in Table 4-15.

Table 4-15. State-level non-MACT Boiler Reductions from ICR Data Gathering
31

State Pollutant

Pre-controlled 

Emissions 

(tons)

Controlled 

Emissions 

(tons)

Reductions 

(tons)

Percent 

Reduction 

%

Michigan NOX 907 544 363 40

North Carolina SO2 652 65 587 90

Virginia SO2 3379 338 3041 90

Washington SO2 639 383 256 40

North Carolina HCl 31 3 28 90

4.2.13.3 RICE NESHAP

There are three rulemakings for National Emission Standards for Hazardous Air Pollutants (NESHAP) for 

Reciprocating Internal Combustion Engines (RICE). These rules reduce HAPs from existing and new RICE 

sources. In order to meet the standards, existing sources with certain types of engines will need to install 

controls. In addition to reducing HAPs, these controls also reduce CAPs, specifically, CO, NOX, VOC, PM, 

and SO2. In 2014 and beyond, compliance dates have passed for all three rules; thus all three rules are 

included in the 2030 LDGHG emissions projection. 

The rules can be found at http://www.epa.gov/ttn/atw/rice/ricepg.html and are listed below:

National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion 

Engines; Final Rule (69 FR 33473) published 06/15/04

National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion 

Engines; Final Rule (FR 9648 ) published 03/03/10

National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion 

Engines; Final Rule (75 FR 51570) published 08/20/2010

The difference among these three rules is that they focus on different types of engines, different facility types 

(major for HAPs, versus area for HAPs) and different engine sizes based on horsepower (HP). In addition, 

they have different compliance dates. We project CAPs from the 2005 NEI RICE sources, based on the 

requirements of the rule for existing sources only because the inventory includes only existing sources and 

the current projection approach does not estimate emissions from new sources.

A complete discussion on the methodology to estimate RICE controls is provided in Appendix F in the 

Proposed MATS Rule TSD: 

http://www.epa.gov/ttn/chief/emch/toxics/proposed_toxics_rule_appendices.pdf. Impacts of the RICE 

controls on stationary non-EGU emissions (nonpt and ptnonipm sectors), excluding WRAP, Texas, and 

Oklahoma oil and gas emissions (see Section 4.2.7) are provided in Table 4-16.

Table 4-16. National Impact of RICE Controls on 2030 Non-EGU Projections

CO NOX PM10 PM2.5 SO2 VOC

Reductions 116,434 111,749 1,595 1,368 21,957 14,669

4.2.13.4 Fuel sulfur rules

Fuel sulfur rules that were signed (enforceable) at the time of the LDGHG emissions processing are limited 

to Maine, New Jersey and New York. Several other states have fuel sulfur rules that were in development 

but not finalized prior to CSAPR and LDGHG Rule emissions processing: 

http://www.ilta.org/LegislativeandRegulatory/MVNRLM/NEUSASulfur%20Rules_09.2010.pdf. 
32

The fuel sulfur content for all home heating oil SCCs in 2005 is assumed to by 3000 part per million (ppm). 

Effective July 1, 2012, New York requires all heating oil sold in New York to contain no more than 15ppm 

of sulfur, thus reducing SO2 emissions by 99.5% for post-2012 (2030) projections. These New York sulfur 

content reductions are further discussed here:

http://switchboard.nrdc.org/blogs/rkassel/governor_paterson_signs_new_la.html.

The New Jersey year 2017 standard of 15ppm (assuming 500ppm baseline for Kersone) sulfur content yields 

a 96.25% SO2 emissions reduction for kersone (fuel #1). The New Jersey sulfur content reductions are 

discussed here: http://njtoday.net/2010/09/01/nj-adopts-rule-limiting-sulfur-content-in-fuel-oil/.

The Maine fuel sulfur rule effective January 1, 2014 reduces sulfur to 15ppm, resulting in a 99.5% reduction 

from 3000 ppm. These Maine sulfur content reductions are discussed here: 

http://www.mainelegislature.org/legis/bills/bills_124th/billpdfs/SP062701.pdf.

The impact of these fuel sulfur content reductions on SO2 is shown in Table 4-17.

Table 4-17. Impact of Fuel Sulfur Controls on 2030 Non-EGU Projections

State SO2 Reductions

Maine 18,470

New Jersey 998

New York 54,431

Total 73,898

4.2.14 Oil and gas projections in TX, OK, and non-California WRAP states 

(nonpt)

For the 2005v4.2 platform, we incorporated updated 2005 oil and gas emissions from Texas and Oklahoma. 

For Texas oil and gas production, we used the last available future year, year 2021, estimates from the Texas 

Commission of Environmental Quality (TCEQ) and used them as described in: 

http://www.tceq.state.tx.us/assets/public/implementation/air/am/contracts/reports/ei/5820783985FY0901-

20090715-ergi-Drilling_Rig_EI.pdf.

We also received 2008 data for Oklahoma that we used as the best available data to represent 2030. We

utilized the latest available future year, year 2018, Phase II WRAP oil and gas emissions data for the nonCalifornia Western Regional Air Partnership (WRAP) states to represent year 2030. RICE NESHAP 

reductions, which are effective by year 2014, were applied to the year 2008 Oklahoma oil and gas inventory 

but not applied to the 2021 TCEQ oil and gas estimates or 2018 WRAP Phase II oil and gas inventory.

For Oklahoma, we applied CO, NOX, SO2 and VOC emissions reductions from the RICE NESHAP, which 

we assumed has some applicability to this industry (see Appendix F in the Proposed Toxics Rule TSD: 

http://www.epa.gov/ttn/chief/emch/toxics/proposed_toxics_rule_appendices.pdf). Table 4-18 shows the 

2005 and 2030 NOX and SO2 emissions including RICE reductions for Oklahoma.

Table 4-18. Oil and Gas NOX and SO2 Emissions for 2005 and 2030 including additional reductions due to 

the RICE NESHAP

NOX PM2.5 SO2 VOC

2005 2030 2005 2030 2005 2030 2005 2030

Alaska 836 453 62 1 68 12
33

Arizona 13 15 37 49

Colorado 32,188 33,517 350 11 35,500 43,639

Montana 10,617 13,880 640 6 9,187 14,110

Nevada 71 63 1 0 105 163

New Mexico 61,674 74,648 369 12 215,636 267,846

North Dakota 6,040 20,869 688 4 8,988 17,968

Oklahoma 39,668 42,402 1,918 2,231 1,014 2 155,908 163,598

Oregon 61 44 19 14

South Dakota 566 557 43 0 370 562

Texas 42,854 26,061 2,945 435 5,977 33 4,337 1,504

Utah 6,896 6,297 149 1 43,403 81,890

Wyoming 36,172 34,142 541 3 166,939 304,748

Total 237,656 252,948 4,862 2,666 9,834 73 640,498 896,104

4.3 Mobile source projections

Mobile source monthly inventories of onroad and nonroad mobile emissions were created for 2030 using a 

the NMIM and MOVES2010a models. Future-year emissions reflect onroad mobile control programs 

including the Light-Duty Vehicle Tier 2 Rule, the Onroad Heavy-Duty Rule, and the Mobile Source Air 

Toxics (MSAT2) final rule. Nonroad mobile emissions reductions for these years include regulations 

affecting locomotives, various nonroad engines including diesel engines and various marine engine types, 

fuel sulfur content, and evaporative emissions.

Onroad mobile sources are comprised of several components and are discussed in the next subsection (4.3.1). 

Nonroad mobile emission projections are discussed in subsection 4.4. Locomotives and Class 1 and Class 2 

commercial marine vessel (C1/C2 CMV) projections are discussed in subsection 4.4.2, and Class 3 (C3) 

CMV projected emissions are discussed in subsection 4.4.3.

4.3.1 Onroad mobile (on_noadj, on_moves_runpm, on_moves_startpm)

The onroad emissions for states other than California were generated with the 2010 version of the Motor 

Vehicle Emissions Simulator (MOVES2010a) – the same version that was used for the 2005 baseline 

inventory and the 2030 control case. For all three cases, the model was run with custom default inputs that 

accounted for the Heavy Duty Greenhouse Gas standards and allowed for the separate calculation of heavy 

duty emissions of different weight categories as described in the “Final Rulemaking to Establish Greenhouse 

Gas Emissions Standards and Fuel Efficiency Standards for Medium- and Heavy-Duty Engines and Vehicles 

Regulatory Impact Analysis” (http://www.epa.gov/oms/climate/documents/420r11901.pdf). 

California onroad (on_noadj)

California onroad inventory: California year 2030 complete CAP/HAP onroad inventories are monthly 

onroad emissions and are based on March 2007 California Air Resources Board (CARB) data (Martin 

Johnson: mjohnson@arb.ca.gov). Like year 2005 emissions, future-year California NH3 emissions are from 

MOVES runs for California, disaggregated to the county level using NMIM. We estimated HAP emissions 

by applying HAP-to-CAP ratios computed from California 2005 NEI submittal provided by EPA in 12/2007. 

This was done because the CARB submittal from March 2007 did not include estimates for HAPs. We 

retained only those HAPs that were also estimated by NMIM for nonroad mobile sources; all other HAPs

were dropped.
34

Onroad mobile sector with no adjustment for daily temperature (on_noadj)

As discussed in Section 2, the MOVES2010a model was used for all vehicles, road types, and pollutants. 

Vehicle Miles Travelled (VMT) was projected using growth rates from the Department of Energy’s 

AEO2011. We used MOVES2010a to create emissions by state, SCC, pollutant, emissions mode and month. 

We then allocated these emissions to counties using ratios based on 2030 NMIM county-level data by state, 

SCC, pollutant, and emissions mode. 

Onroad PM gasoline running and cold start mode sectors (on_moves_startpm and on_moves_runpm)

MOVES-based cold start and running mode emissions consist of gasoline exhaust speciated PM and 

naphthalene. These pre-temperature-adjusted emissions at 72°F are projected to year 2030 from year 2005 

inventories using the 2030-specific runs of MOVES2010a. VMT were projected using growth rates from the 

AEO2009. As with the on_noadj sector, the 2030 MOVES2010a data were created at the state-month level, 

and the 2030 NMIM results were used to disaggregate the state level results to the county level.

MOVES-based temperature adjustment factors were applied to gridded, hourly emissions using gridded, 

hourly meteorology. As seen in Figure 4-1, for year 2030, we used the same temperature adjustment factors 

as the 2005 base case for both start and running modes. However, cold start temperature adjustment factors 

decrease in future years, and for year 2030 processing, we updated the temperature adjustment curves for 

these cold start emissions. Note that running exhaust temperature adjustment factors are the same for all 

years. Also, it is worth noting that the running mode gasoline exhaust emissions are considerably larger than 

cold start mode gasoline exhaust emissions before application of the temperature adjustments.

Figure 4-1. MOVES exhaust temperature adjustment functions for 2005 and 2030

4.4 Nonroad mobile source projections (nonroad, alm_no_c3, seca_c3)

The components of the nonroad mobile sectors are discussed in Section 2.3. Nonroad mobile emissions 

reductions for the LDGHG reference case includes year-specific regulations affecting locomotives, various 

nonroad engines including diesel engines and various marine engine types, fuel sulfur content, and 

evaporative emissions. This section discusses the changes due to the NONROAD/NMIM system (nonroad 

sector) and additional C1/C2 CMV and locomotive emissions from volume increases resulting from 

incorporation of larger amounts of renewable fuels in the 2030 reference case.

0

10

20

30

40

50

60

70

80

-20-15-10 -5 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70

Adjustment Factor

Temperature (F)

Run Exhaust Both Years

Start Exhaust 2005

Start Exhaust 2030
35

4.4.1 Emissions generated with the NONROAD model (nonroad)

OTAQ provided several runs of NMIM emissions that were blended together to create the 2030 nonroad 

sector emissions. We used these same nonroad emissions for both the reference and control cases. Table 4-11 

shows how the various NMIM runs were combined to create the non-California nonroad mobile inventories. 

The first component “2002v3-based 2030 Base Case” is from the 2030 Base case in our 2002v3 platform for 

the SCCs listed in Table 4-11. OTAQ also provided diesel recreational marine (pleasure craft) emissions in 

November 2009. 

Table 4-11. Components of 2030 HDGHG Nonroad Sector 

NMIM file SCCs Description of Nonroad 

SCCs 

2002v3-based 2030 Base Case 2267x LPG equipment 

2268x CNG equipment 

2270x Diesel engines 

2285002015, 

2285006015 

Railway maintenance 

LdGhgN2030e0_nponzseg11die

s.txt 

22820200x Diesel recreational-marine 

LdGhgN2030e10.txt 2260x 2-stroke gasoline engines 

2265x 4-stroke gasoline engines 

228200x, 228201x Gasoline recreational 

marine 

We have not included voluntary nonroad programs in our projections such as programs encouraging either 

no refueling or evening refueling on Ozone Action Days and diesel retrofit programs. The national nonroad 

regulations are those promulgated prior to December 2009, and beginning about 1990. Recent rules include:

“Clean Air Nonroad Diesel Final Rule - Tier 4”: (http://www.epa.gov/nonroaddiesel/2004fr.htm ), 

published June 29, 2004, and,

Control of Emissions from Nonroad Large Spark-Ignition Engines, and Recreational Engines (Marine 

and Land-Based), November 8, 2002 (“Pentathalon Rule”).

OTAQ’s Locomotive Marine Rule, March 2008: 

(http://www.epa.gov/otaq/regs/nonroad/420f08004.htm)

OTAQ’s Small Engine Spark Ignition (“Bond”) Rule, November 2008: 

(http://www.epa.gov/otaq/equip-ld.htm)

All future year nonroad emissions used NMIM data that are based on AEO2009 fuels and the same NMIM 

county database NCD20101201Tier3. We converted emissions from monthly totals to monthly average-day 

values based the on number of days in each month. Only criteria and select HAPs (benzene, acetaldehyde, 

butadiene, acrolein, and formaldehyde) were retained when creating SMOKE one record per line (ORL)

files.
36

California monthly nonroad emissions are year 2030 and are based on March 2007 California Air Resources 

Board (CARB) data (Martin Johnson: mjohnson@arb.ca.gov). NH3 emissions are from NMIM runs for 

California (same data as were used in 2030 from the 2002 v3 platform). We allocated refueling emissions to 

the gasoline equipment types based on evaporative mode VOC emissions from the 2002 v3 platform 2030 

NMIM data, and the refueling emissions were computed by multiplying SCC 2505000120 emissions by 

0.61, to adjust to remove double counting with Portable Fuel Container inventory for California. We 

estimated HAP emissions by applying HAP-to-CAP ratios computed from the California data provided for 

the 2005 NEI v2, collected by EPA on 12/2007. This was done because the CARB submittal from March 

2007 did not include estimates for HAPs. We retained only those HAPs that are also estimated by NMIM for 

nonroad mobile sources; all other HAPs were dropped.

4.4.2 Locomotives and Class 1 & 2 commercial marine vessels (alm_no_c3)

Aircraft emissions reside in the nonEGU point inventory (ptnonipm), and the projection factors used to 

create year 2030 estimates, are discussed in Section 4.2. The remaining 2005 NEI emissions for locomotives 

and Class 1 and Class 2 commercial marine vessel (C1/C2 CMV) use year-specific projection estimates. 

Base future year locomotive and C1/C2 CMV emissions were calculated using projection factors that were 

computed based on national, annual summaries of emissions in 2005 and 2030. Some additional emissions 

were then factored in due to changes in fuels. These national summaries were used to create national bypollutant, by-SCC projection factors; these factors include final locomotive-marine controls and are provided 

in Table 4-19. Modest additive Class I railroad and C1/C2 CMV emissions that account for RFS2 volume 

increases in the LDGHG future year reference scenarios were then added into the reference case due to the 

volume differences in corn, cellulosic and imported ethanol and cellulosic diesel fuels. These additional 

emissions are summarized in 
37

Table 4-20. 

Table 4-19. Factors applied to year 2005 emissions to project locomotives and class 1 and class 2 

commercial marine vessel emissions to 2030

SCC SCC Description Pollutant 2030

2280002X00 Marine Vessels, Commercial;Diesel;Underway & port emissions CO 0.956

2280002X00 Marine Vessels, Commercial;Diesel;Underway & port emissions NH3 1.285

2280002X00 Marine Vessels, Commercial;Diesel;Underway & port emissions NOX 0.372

2280002X00 Marine Vessels, Commercial;Diesel;Underway & port emissions PM10 0.350

2280002X00 Marine Vessels, Commercial;Diesel;Underway & port emissions PM2.5 0.356

2280002X00 Marine Vessels, Commercial;Diesel;Underway & port emissions SO2 0.045

2280002X00 Marine Vessels, Commercial;Diesel;Underway & port emissions VOC 0.402

2285002006 Railroad Equipment;Diesel;Line Haul Locomotives: Class I Operations CO 1.640

2285002006 Railroad Equipment;Diesel;Line Haul Locomotives: Class I Operations NH3 1.627

2285002006 Railroad Equipment;Diesel;Line Haul Locomotives: Class I Operations NOX 0.357

2285002006 Railroad Equipment;Diesel;Line Haul Locomotives: Class I Operations PM10 0.260

2285002006 Railroad Equipment;Diesel;Line Haul Locomotives: Class I Operations PM2.5 0.263

2285002006 Railroad Equipment;Diesel;Line Haul Locomotives: Class I Operations SO2 0.006

2285002006 Railroad Equipment;Diesel;Line Haul Locomotives: Class I Operations VOC 0.293

2285002007 Railroad Equipment;Diesel;Line Haul Locomotives: Class II / III Operations CO 0.403

2285002007 Railroad Equipment;Diesel;Line Haul Locomotives: Class II / III Operations NH3 1.627

2285002007 Railroad Equipment;Diesel;Line Haul Locomotives: Class II / III Operations NOX 0.350

2285002007 Railroad Equipment;Diesel;Line Haul Locomotives: Class II / III Operations PM10 0.272

2285002007 Railroad Equipment;Diesel;Line Haul Locomotives: Class II / III Operations PM2.5 0.275

2285002007 Railroad Equipment;Diesel;Line Haul Locomotives: Class II / III Operations SO2 0.001

2285002007 Railroad Equipment;Diesel;Line Haul Locomotives: Class II / III Operations VOC 0.387

2285002008 Railroad Equipment;Diesel;Line Haul Locomotives: Passenger Trains (Amtrak) CO 1.188

2285002008 Railroad Equipment;Diesel;Line Haul Locomotives: Passenger Trains (Amtrak) NH3 1.627

2285002008 Railroad Equipment;Diesel;Line Haul Locomotives: Passenger Trains (Amtrak) NOX 0.241

2285002008 Railroad Equipment;Diesel;Line Haul Locomotives: Passenger Trains (Amtrak) PM10 0.148

2285002008 Railroad Equipment;Diesel;Line Haul Locomotives: Passenger Trains (Amtrak) PM2.5 0.149

2285002008 Railroad Equipment;Diesel;Line Haul Locomotives: Passenger Trains (Amtrak) SO2 0.005

2285002008 Railroad Equipment;Diesel;Line Haul Locomotives: Passenger Trains (Amtrak) VOC 0.136

2285002009 Railroad Equipment;Diesel;Line Haul Locomotives: Commuter Lines CO 1.172

2285002009 Railroad Equipment;Diesel;Line Haul Locomotives: Commuter Lines NH3 1.627

2285002009 Railroad Equipment;Diesel;Line Haul Locomotives: Commuter Lines NOX 0.237

2285002009 Railroad Equipment;Diesel;Line Haul Locomotives: Commuter Lines PM10 0.146

2285002009 Railroad Equipment;Diesel;Line Haul Locomotives: Commuter Lines PM2.5 0.146

2285002009 Railroad Equipment;Diesel;Line Haul Locomotives: Commuter Lines SO2 0.005

2285002009 Railroad Equipment;Diesel;Line Haul Locomotives: Commuter Lines VOC 0.134

2285002010 Railroad Equipment;Diesel;Yard Locomotives CO 1.649

2285002010 Railroad Equipment;Diesel;Yard Locomotives NH3 1.627

2285002010 Railroad Equipment;Diesel;Yard Locomotives NOX 0.851

2285002010 Railroad Equipment;Diesel;Yard Locomotives PM10 0.690

2285002010 Railroad Equipment;Diesel;Yard Locomotives PM2.5 0.704

2285002010 Railroad Equipment;Diesel;Yard Locomotives SO2 0.007

2285002010 Railroad Equipment;Diesel;Yard Locomotives VOC 1.074
38

Table 4-20. Additional class 1 railroad and C1/C2 CMV emissions from RFS2 fuel volume changes

Pollutant

2030 Class 1

Rail (tons)

2030 C1/C2 

CMV (tons)

1,3-Butadiene 0.56 0.01

Acrolein 0.54 0.05

Formaldehyde 7.50 2.23

Benzene 0.45 0.30

Acetaldehyde 3.26 1.11

CO 1,906 272

NH3 5.99 0.95

NOX 4,298 642

PM10 86 21

PM2.5 83 20

SO2 4.51 5.99

VOC 173 15

The future-year locomotive emissions account for increased fuel consumption based on Energy Information 

Administration (EIA) fuel consumption projections for freight rail, and emissions reductions resulting from 

emissions standards from the Final Locomotive-Marine rule (EPA, 2009). This rule lowered diesel sulfur 

content and tightened emission standards for existing and new locomotives and marine diesel emissions to 

lower future-year PM, SO2, and NOX, and is documented at: 

http://www.epa.gov/otaq/regs/nonroad/420f08004.htm. Voluntary retrofits under the National Clean Diesel 

Campaign (http://www.epa.gov/otaq/diesel/index.htm) are not included in our projections.

We applied HAP factors for VOC HAPs by using the VOC projection factors to obtain 1,3-butadiene, 

acetaldehyde, acrolein, benzene, and formaldehyde.

Class 1 and 2 CMV gasoline emissions (SCC = 2280004000) were not changed for future-year processing. 

C1/C2 diesel emissions (SCC = 2280002100 and 2280002200) were projected based on the Final 

Locomotive Marine rule national-level factors provided in Table 4-19. Similar to locomotives, VOC HAPs 

were projected based on the VOC factor.

Delaware provided updated future-year NOX, SO2, and PM emission estimates for C1/C2 CMV as part of the 

Transport Rule comments. These updated emissions were applied to the 2030 inventory and override the 

C1/C2 projection factors in Table 4-19.

4.4.3 Class 3 commercial marine vessels (seca_c3)

The seca_c3 sector emissions data were provided by OTAQ in an ASCII raster format used since the SO2

Emissions Control Area-International Marine Organization (ECA-IMO) project began in 2005. The (S)ECA 

Category 3 (C3) commercial marine vessel 2002 base-case emissions were projected to year 2005 for the 

2005 base case and to 2030, which includes ECA-IMO controls. An overview of the ECA-IMO project and 

future-year goals for reduction of NOX, SO2, and PM C3 emissions can be found at: 

http://www.epa.gov/oms/regs/nonroad/marine/ci/420f09015.htm

The resulting coordinated strategy, including emission standards under the Clean Air Act for new marine 

diesel engines with per-cylinder displacement at or above 30 liters, and the establishment of Emission 

Control Areas is at: http://www.epa.gov/oms/oceanvessels.htm
39

These projection factors vary depending on geographic region and pollutant; where VOC HAPs are assigned 

the same growth rates as VOC. The projection factors used to create the 2030 seca_c3 sector emissions are 

provided in Table 4-21. Note that these factors are relative to 2002. Factors relative to 2005 can be 

computed from the 2002-2005 factors.

The geographic regions are described in the ECA Proposal technical support document: 

http://www.epa.gov/oms/regs/nonroad/marine/ci/420r09007-chap2.pdf. These regions extend up to 200 

nautical miles offshore, though less at international boundaries. North and South Pacific regions are divided 

by the Oregon-Washington border, and East Coast and Gulf Coast regions are divided east-west by roughly 

the upper Florida Keys just southwest of Miami.

The factors to compute HAP emission are based on emissions ratios discussed in the 2005v4 documentation 

(ftp://ftp.epa.gov/EmisInventory/2005v4/2005_emissions_tsd_07jul2010.pdf). As with the 2005 base case, 

this sector uses CAP-HAP VOC integration.

Table 4-21. NOX, SO2, PM2.5 and VOC factors to project class 3 CMV emissions for 2030

Region NOX SO2 PM2.5 VOC

Alaska East 1.702 0.095 0.312 2.487

Alaska West (AW) 2.052 0.456 0.571 2.396

East Coast 1.072 0.123 0.47 3.464

Gulf Coast 0.688 0.079 0.303 2.217

Hawaii East (HE) 1.416 0.147 0.506 3.839

Hawaii West (HW) 2.783 0.733 0.871 3.842

North Pacific (NP) 0.874 0.098 0.348 2.528

South Pacific (SP) 1.232 0.166 0.589 4.225

Great Lakes (GL) 1.09 0.057 0.214 1.621

Outside ECA 2.427 0.623 0.745 3.417

4.5 Canada, Mexico, and Offshore sources (othar, othon, and othpt)

Emissions for Canada, Mexico, and offshore sources were not projected to future years, and are therefore the 

same as those used in the 2005 base case. Therefore, the Mexico emissions are based on year 1999, offshore 

oil is based on year 2005, and Canada is based on year 2006. For both Mexico and Canada, their responsible 

agencies did not provide future-year emissions that were consistent with the base year emissions.

5 2030 Control Case

The LDGHG control case represents the future with implementation of new LDGHG standards. Similar to 

the 2030 base case discussed in Section 4, the control case also includes MSAT2 and HDGHG. 

This section will address only those components that are different between the reference and control 

scenarios. VOC speciation is identical in the control and the reference cases as discussed in Section 3.

5.1 2030 Control Case Point and Nonpoint sources

The point sources for the 2030 LDGHG Control Case include the same emissions as the 2030 Reference

Case for the sources from Mexico, Canada, and the Gulf of Mexico (othpt). The nonpoint sources for the 
40

2030 LDGHG Control Case include the same emissions as the 2030 Reference Case for the following 

nonpoint source emissions modeling sectors: area fugitive dust (afdust), agricultural ammonia (ag), averageyear fires (avefire) and sources from Mexico and Canada (othar).

The LDGHG year 2030 control case includes changes to the EGU emissions (ptipm). IPM version 4.10 was 

run to simulate additional electricity demand from electric vehicles as detailed in the Regulatory Impact 

Analysis for this rule. Additional pollutant-specific adjustment factors were applied to the ptipm results to 

reflect the reduction in EGU emissions due to a decrease in petroleum refinery production. These 

adjustments are provided in Table 5-1. Table 5-2 provides total air quality inventory impacts on electrical 

power plants from electric and electric plug-in vehicles as well as reductions in production of electricity for 

refinery use.

Table 5-1. Adjustments to IPM Emissions to Account for Reduced Refinery Demand

Pollutant

Adjustment 

Factor

CO 0.99912

NOx 0.99892

PM10 0.99660

PM2.5 0.99871

SO2 0.99884

VOC 0.99513

Table 5-2. Total Air Quality Inventory Impacts on ptipm (Electric Power Plants from Electric and Electric 

Plug-in Vehicles, and Reductions in Production of Electricity for Refinery Use).

Pollutant Tons Percent of Total 

Ptipm Inventory

PM2.5 --136 0.06

PM10 -923 0.31

NOX 459 0.02

VOC -7 0.01

CO 7618 0.72

SOX 3131 0.15

NH3 541 1.10

Acetaldehyde 0 0.49

Acrolein 0 0

Benzene -12 0.24

1,3-Butadiene 0 0

Formaldehyde 112 1.25

The control case also includes inventory adjustments to the following upstream processes: domestic crude 

production and transport losses during transport to refineries, petroleum production and refining emissions, 

production of energy for refinery use, combustion emissions from transport of refinery products, and 

gasoline transport, storage and distribution losses.

3

 

3 These upstream adjustments were supplied by OTAQ in the Excel® workbook “upstream scalars LD GHG_ram_RC.xlsx” with 

additional adjustments on 6/13/2012 in the workbook “Upstream_Scalars_Rerun_v6.xlsx”.
41

To adjust inventories for domestic crude production and transport, we assumed 50% of the change in 

gasoline and diesel supply would come from domestic refineries, and (b) 10% of the change in crude being 

used by domestic refineries would be domestic crude. Using the assumption that 1.0 gallon less of gasoline 

equates to approximately 1.0 gallon less crude throughput, the reduction in crude extraction and transport 

from this rule would equal about 5% of the change in gasoline volume. Since the reduction in fuel 

consumption is estimated at 31.6 billion gallons for this rule, the reduction in crude production is about 1.58 

billion gallons for this rule. To generate the emission inventory adjustment factors for air quality modeling 

these reductions were applied to the projected crude supply of 230 billion gallons to US refineries in 2030, 

per AEO 2011.i Thus, the adjustment is 0.68%. In addition, petroleum refinery emissions were reduced by 

21% to account for lower gasoline production resulting from the rule.

Decreased petroleum refinery output also resulted in reduced emissions from energy feedstock production. 

Table 5-3 presents adjustment factors for emissions associated with residual oil production, natural gas 

production and coal, due to decreased petroleum refinery production. Methods used to develop these 

adjustments are described in the Regulatory Impact Analysis.

Table 5-3. Upstream Refinery Emission Impacts in Tons and Inventory Scalars

Residual Oil 

Production

Natural Gas 

Production

Coal 

Production

Pollutant Impact Scalar Impact Scalar Impact Scalar

VOC -51 0.9992 -474 0.9883 -270 0.9026

CO -93 0.9990 -676 0.9758 -97 0.9817

NOx -351 0.9943 -2010 0.9583 -551 0.9136

PM10 -36 0.9997 -51 0.9199 -6366 0.7195

PM2.5 -17 0.9990 -39 0.9353 -1584 0.7874

SOx -179 0.9913 -1168 0.9753 -325 0.8947

Decreased gasoline production also results in lower emissions of VOC and benzene produced by storage and 

transfer activities associated with distribution of gasoline. Emissions from these storage and transfer 

activities were partitioned into a refinery to bulk terminal component (RBT), a bulk plant storage (BPS) 

component, and a bulk terminal to gasoline dispensing pump (BTP) component (see Appendix C for SCCs). 

One set of scalars was applied to RBT/BPS emissions and another to BTP emissions. These scalars are 

provided in Table 5-4. The scalars for BTP emissions reflect the change in total gasoline plus ethanol 

volume in gasoline and gasoline/ethanol blends. However, it does not account for changes in 

gasoline/ethanol blends used. Impacts were assumed to be spread evenly across the U. S. Methods used to 

develop these scalars are described in the Regulatory Impact Analysis.

Table 5-4. Scalars Applied to Base Inventory (2005 Platform with RFS2 Impacts) to Obtain Reference and 

Control Case Gasoline Storage, Transport and Distribution Emissions

Process Reference Case (Impacts of 

Medium- and Heavy-Duty 

Greenhouse Gas Rule)

Control Case (Impacts of 

Medium- and Heavy-Duty 

Greenhouse Gas Rule Plus 

this Rule)

Refinery to Bulk Terminal/ 

Bulk Plant Storage

0.9972 0.7944

Bulk Terminal to Pump 0.9976 0.8234
42

Finally, in addition to non-combustion emissions associated with storage, transport and distribution, there are 

combustion emissions associated with transport of gasoline by pipeline, commercial marine vessel, rail, and 

tanker truck. Estimates of emission impacts by transport model were developed using methods detailed in 

the Regulatory Impact Analysis for this rule and applied to total emissions from transport sources to develop 

scaling factors. Emission inventory and inventory scalars for pipelines (pumps and other equipment) are 

given in Table 5-5. Impacts for mobile sources are discussed in the next section.

Table 5-5. Gasoline Transport Pipeline Emission Impacts in Tons and Inventory Scalars

Pollutant Impact Scalar

VOC -287 0.9959

CO -1447 0.9864

NOx -6137 0.9192

PM10 -241 0.9895

PM2.5 -130 0.9932

SOx -1292 0.9890

Total air quality inventory impacts for the ptnonipm and nonpt sources described above are provided in 

Table 5-6.

Table 5-6. Total Air Quality Inventory Impacts on Ptnonipm and Nonpt Inventory

Pollutant Tons Percent of Total 

Ptnonipm and 

Nonpt Inventory

PM2.5 -3,578 0.26

PM10 -8,412 0.45

NOX -15,538 0.40

VOC -149,193 1.76

CO -13,004 0.13

SO2 -14,714 0.55

NH3 0 0

Acetaldehyde -5 0.01

Acrolein 0 0

Benzene -1499 1.42

1,3-Butadiene -2 0.04

Formaldehyde -687 0.19

5.2 2030 Control Case Mobile sources

The onroad mobile and nonroad mobile sources for the 2030 LDGHG Control Case include the same 

emissions as the 2030 Reference Case for the following emissions modeling sectors: US nonroad mobile 

(nonroad), C3 commercial marine (seca_c3), Canada and Mexico onroad mobile emissions (othon) and 

Canada and Mexico nonroad emissions (also in the othar sector with Canada and Mexico stationary sources). 
43

The LDGHG year 2030 control case changes to the mobile sectors are limited to US locomotives and non-C3 

commercial marine (alm_no_c3), the MOVES2010a-based onroad non-California (except NH3) inventories

(on_moves_runpm, on_moves_startpm and on_noadj sectors), and the California onroad mobile emissions.

The 2030 control case for onroad (MOVES and California based) includes a rebound effect (increased VMT 

due to improved fuel efficiency), and a decrease in SO2 and SO4 emissions due to decrease fuel usage. An 

adjustment factor accounting for rebound impact was calculated by running MOVES2010a at the national 

level with output by model year. Model-year specific rebound-related VMT changes were applied, and 

emissions were summed across model years and divided by the original emissions to develop pollutantspecific adjustment factor for the the exhaust, tire wear, and brake wear modes. Similarly, the SO2 and SO4 

reductions were calculated by applying appropriate reductions to national emissions by model year and using 

these reductions to compute SCC-specific reduction ratios. These adjustment factors were applied to the 

2030 reference onroad inventories (on_moves_runpm, on_moves_startpm, and on_noadj including CA). 

These updated inventories were then processed through SMOKE in the same manner as the reference and 

base cases.

The control case also includes Annual Energy Outlook (AEO) year2010-based upstream adjustments: 

refinery supply estimates and estimated reductions in consumption that impact the transport/distribution fuel 

via rail, marine vessels (c1 and c2), and heavy and medium duty trucks.4These adjustments impact the 

alm_no_c3 and onroad sectors from the 2030 reference case.

 

4 These upstream adjustments to alm_no_c3 due to decreased petroleum refinery production were supplied by OTAQ on 6/13/2012 

in the workbook “Upstream_Scalars_Rerun_v7.xlsx”. The adjustment to onroad including rebound, SO2/SO4 reductions, and 

refinery upstream impacts on medium and heavy duty truck were provide by OTAQ on 6/8/2012 in 

“LDGHGctl2030_adj_080612.csv”
44

6 References

EPA, 2005. Clean Air Interstate Rule Emissions Inventory Technical Support Document, U.S. 

Environmental Protection Agency, Office of Air Quality Planning and Standards, March 005. 

Available at http://www.epa.gov/cair/pdfs/finaltech01.pdf.

EPA, 2006. Regulatory Impact Analyses, 2006 National Ambient Air Quality Standards for Particle 

Pollution. U.S. Environmental Protection Agency, Office of Air Quality Planning and Standards, 

October, 2006. Docket # EPA-HQ-OAR-2001-0017, # EPAHQ-OAR-2006-0834. Available at 

http://www.epa.gov/ttn/ecas/ria.html.

EPA, 2007a. Guidance for Estimating VOC and NOx Emission Changes from MACT Rules, U.S. 

Environmental Protection Agency Office of Air Quality Planning and Standards, Air Quality Policy 

Division, Research Triangle Park, NC 27711, EPA-457/B-07-001, May 2007. Available at 

http://www.epa.gov/ttn/naaqs/ozone/o3imp8hr/documents/guidance/200705_epa457_b-07-

001_emission_changes_mact_rules.pdf.

EPA. 2007b. National Scale Modeling for the Final Mobile Source Air Toxics Rule, Office of Air Quality 

Planning and Standards, Emissions Analysis and Monitoring Division, Research Triangle Park, NC 

27711, EPA 454/R-07-002, February 2007. Available at 

http://www.epa.gov/otaq/regs/toxics/454r07002.pdf

EPA, 2009. Regulatory Impact Analysis: Control of Emissions of Air Pollution from Locomotive Engines 

and Marine Compression Ignition Engines Less than 30 Liters Per Cylinder. U.S. Environmental 

Protection Agency Office of Transportation and Air Quality, Assessment and Standards Division, 

Ann Arbor, MI 48105, EPA420-R-08-001a, May 2009. Available at: 

http://www.epa.gov/otaq/regs/nonroad/420r08001a.pdf

EPA, 2010. Technical Support Document: The Industrial Sectors Integrated Solutions (ISIS) Model and the 

Analysis for the National Emission Standards for Hazardous Air Pollutants and New Source 

Performance Standards for the Portland Cement Manufacturing Industry, U.S. Environmental 

Protection Agency, Sectors Policies and Program Division and Air Pollution Prevention and Control 

Division, Research Triangle Park, NC 27711, August 2010.

SRI, 2009. Southwest Research Insititute, Final Report prepared for Coordinating Research Council, Inc.: 

ACES Phase I: Phase 1 of the Advanced Collaborative Emissions Study, June 2009. Available at: 

http://www.crcao.org/reports/recentstudies2009/ACES%20Phase%201/ACES%20Phase1%20Final%

20Report%2015JUN2009.pdf
45

APPENDIX A

Modified LDGHG Equations to adapt pre-speciated diesel emissions from MOVES to air quality 

modeling species needed for CMAQ

As shown in equation (1) below, MOVES provides total PM2.5, PEC and PSO4. A remainder term, R, makes 

up the difference between the two species and the total PM2.5. 

MOVES total PM2.5 = PEC + PSO4 + R (1)

The R term includes POM, which consists of POC and the hydrogen and oxygen atoms attached to the 

carbon as part of the organic matter, PNO3, soil oxides and metals (also known as “crustal” and called 

METAL here), ammonium, and water, and thus can be also written as:

R = POM + PNO3 + METAL + NH4 + H20 (2)

To correctly calculate the five PM2.5 species needed for CMAQ, we first needed to break out the POC, 

PNO3, and PMFINE from R. Different calculations are used for light-duty diesel vehicles and heavy-duty 

diesel vehicles, since the speciation profiles for these are different. The speciation profiles used for these 

calculations are:

For both light duty diesel vehicles and heavy duty diesel vehicles, the SPECIATE 4.0 PM2.5 speciation 

profiles “3914” (HHDV) and “92042” (LDDV) will be used to help calculate the other species. At the time, 

OTAQ did not provide a justification for choosing this profile, but the fractions of metals and PNO3 are 

small and so presumably the choice does not matter too much as long as the smallest of those fractions is 

representative.

We computed the primary nitrate based on speciation profile 92011 from the SPECIATE4.1 database (Hsu et 

al., 2006) using equation (3) shown below.

PNO3 = PEC × FNO3 / FEC (3)

where,

FEC = Fraction of elemental carbon in speciation profile:

- LDDV: 57.4805% (based on profile 92042)5

- HDDV: 77.1241% (based on profile 3914)

FNO3 = Fraction of nitrate in speciation profile

- LDDV: 0.1141% (based on profile 3914, intentionally inconsistent)

- HDDV: 0.1141% (based on profile 3914)

To identify which sources should get the LDDV and which should get the HDDV approach, see Table 1, 

below.

Since CMAQ’s PMFINE species is the sum of soil oxides, metals, ammonium, and water, we needed to 

calculate all of its components. First, the metals and ammonium are computed using equations (4) and (5). 

Equation (5) is based on stoichiometric calculations.

 

5 All profile fractions provided in email from Catherine Yanca on 11/6/2009, 1:49pm in attachment “Equations for diesel MOVES 

speciation use in CMAQ 110609.doc”
46

METAL = PEC × Fmetal / FEC (4)

NH4 = (PNO3/MWNO3 +2 × PSO4/MWSO4) × MWNH4 (5)

where,

Fmetal = Fraction of metals in speciation profile (0.0026636)

MWSO4 = Molecular weight of sulfate (96.0576)

MWNO3 = Molecular weight of nitrate (62.0049)

MWNH4 = Molecular weight of ammonium (18.0383)

The final component of PMFINE is the non-carbon mass of organic carbon. To calculate the non-carbon 

mass, we first needed to compute organic carbon from the remainder term, R. 

A key assumption is that POM is a factor of 1.2 greater than the mass of primary organic carbon, which is 

also used in the CMAQ postprocessing software at EPA.

POM = 1.2 × POC (6)

Using this assumption and assuming that the H20 is negligible, the equation needed for the calculation of 

POC is shown in equations 7a and 7b for gasoline exhaust and diesel exhaust, respectively. As discussed in 

Section 2.3, for LDGHG, the NH4 component was removed for diesel exhaust only. 

Gasoline Exhaust: POC = 5/6 × (R – METAL – NH4 – PNO3) (7a)

Diesel Exhaust: POC = 5/6 × (R – METAL – PNO3) (7b)

See Appendix B of the 2005v4 TSD for more complete discussion on PM speciation for gasoline exhaust 

processes: ftp://ftp.epa.gov/EmisInventory/2005v4/2005_emissions_tsd_appendices_11may2010.pdf.

From equation (6), the non-carbon portion of the organic carbon matter is 20%, of the POC. By definition, 

PMFINE is the sum of the non-carbon portion of the mass, METAL and NH4. Thus, we computed 

PMFINE_72 using equations (8a and 8b) shown below for gasoline and diesel exhaust.

Gasoline Exhaust: PMFINE_72 = METAL + NH4 + 0.2 × POC_72 (8a)

Diesel Exhaust: PMFINE_72 = METAL + 0.2 × POC_72 (8b)

Equations 7a and 8a (with NH4) will be obsolete in all subsequent MOVES post-processing; we did not have 

time to reprocess the gasoline exhaust emissions for LDGHG; however, the computed NH4 component in 

gasoline exhaust was much smaller than for diesel exhaust so this impact should be negligible.

For mobile sources, we assumed that PMC is 8.6% of the PM2.5 mass. Equation (9) shows how we 

calculated it. 

PMC = 0.086 × (PMFINE + PEC + POC + PSO4 + PNO3) (9)

Table A-1. List of SCC groups for application of LDDV or HDDV approach

Approach SCC list

LDDV 2230001000 through 2230060334

HDDV 2230071110 through 2230075330

 

6 Value provided by Catherine Yanca and Joe Somers to OAQPS in email provided 11/5/2009
47

APPENDIX B

Summary of LDGHG Rule 2030 Reference Case Non-EGU Control Programs, Closures and 

Projections
48

Lists of control, closure, projection packet datasets used to create LDGHG year 2030 Reference case inventories from the 2005 LDGHG base case 

are provided in Tables B-1 and B-2.

Table B-1. Datasets used to Create LDGHG 2030 Inventories for Non-EGU Point Sources

Name Type Dataset Version Description

CLOSURES LotusNotes, ABCG, plus Timin 

2016cr

Plant 

Closure

CLOSURES_LotusNotes_Linda_Timin_2016

cr_23AUG2010 1

Plant and unit closures identified through EPA 

review.

CLOSURES TR1 comments and consent decrees 

2014cs

Plant 

Closure CLOSURES_TR1_2014cs_01FEB2011 0

Plant and unit closures through 2014 identified as

a result of Transport Rule comments.

CLOSURES cement ISIS 2013 policy

Plant 

Closure

CLOSURES_cementISIS_2016cr_17AUG201

0 1

Cement plant and unit closures identified via the 

ISIS 2013 policy case.

closures: 2005 to 2012ck

Plant 

Closure

CLOSURES_2005ck_to_2012ck_CoST_form

at 0

Plant and unit closures identified 2008 or before.

CONTROL ADDITIONAL OECA 2005cr to 

2016cr Control

CONTROLS_additional_NEIpf4_OECA_200

5cr_2016cr_29JUL2010 1

Controls that implement OECA consent decrees.

CONTROL REPLACE DOJ 2005cr to 2016cr Control

CONTROLS_replacement_NEIpf4_DOJ_200

5cr_2016cr_02AUG2010.txt 0

Controls resulting from the 2002v3 DOJ Texas

settlement.

CONTROL REPLACE HWI 2005cr to 2016cr Control

CONTROLS_replacement_NEIpf4_HWI_200

5cr_2016cr_02AUG2010.txt 1

Hazardous Waste Incinerator controls for CAPs 

and Haps carried over from 2002v31.

CONTROL REPLACE IndustrialBoiler 

nonMACT 2005cr to 2016cr Control

CONTROLS_replacement_IndBoilers_nonM

ACT_by2008_20AUG2010 0

Industrial boiler controls not related to application 

of the MACT but derived from the Boiler MACT 

ICR database dated 4/30/10.

CONTROL REPLACE LMWC 2005cr to 2016cr Control

CONTROLS_replacement_NEIpf4_LMWC_

2005cr_2016cr_02AUG2010.txt 0

Controls for large municipal combustors carried 

over from 2002v31.

CONTROL REPLACE MACT 2005cr to 2016cr Control

CONTROLS_replacement_NEIpf4_MACT_2

005cr_2016cr_02AUG2010.txt 0

MACT controls carried over from 2002v3 and 

updated as appropriate.

CONTROL REPLACE NY SIP 2005cr to 2016cr Control

CONTROLS_replacement_NYSIP_O3_SCC_

2016cr_26AUG2010 0

Controls that reflect enforceable controls for NOx 

and VOC from the New York ozone SIP.

CONTROL REPLACE Refineries 2005cr to 

2016cr Control

CONTROLS_replacement_NEIpf4_refineries

_2005cr_2016cr_02AUG2010.txt 0

Controls for refineries specified by EPA expert 

refinery staff.

CONTROL RICE 2016cr_05b Control

CONTROLS_replacement_RICE_2016cr_21

SEP2010 1

Controls for 2014 and 2016 that represent three 

separate RICE NESHAPs

CONTROL RICE SO2 2014cs_05b Control

CONTROLS_replacement_RICE_SO2_2014c

s_05JAN2011 1

SO2 reductions from the Ultra-low Sulfur Diesel 

requirement for CI engines

CONTROL SULF rules: ME, NY, NJ 2018 and 

beyond Control

CONTROLS_SULF_rules_2018_and_beyond

_03FEB2011 1

SO2 reductions due to state sulfur content rules for 

fuel oil.

CONTROL St Gobain and LaFarge 2017 Control

CONTROLS_rep_Lafarge_StGobain_2017cs

_25JAN2011.txt 0

Controls for NOx, SO2, PM., and HCl resulting 

from Saint Gobain and Lafarge consent decrees

CONTROL TR1 Final CONTROL packet: 2021 Control CONTROLS_TR1_2021_09FEB2011 1

Controls for TCEQ oil and gas and non-ISIS 

related cement controls.

CONTROL TR1 Final consent decrees 2019 Control

CONTROLS_additional_TR1final_consent_d

ecrees_2005cs_to_2019cs 1

Controls related to consent decrees identified 

during the Transport Rule comment period. 
49

CONTROL cement ISIS 2013 policy Control

CONTROLS_replacement_cementISIS_2016

cr_17AUG2010 0

Controls for cement plants based on 2013 ISIS 

policy case

PROJECTION 2005 to 2030 ag emissions

Projecti

on PROJECTION_2005cs_2030_ag_09FEB2011 0

Projection factors for agriculture based on animal 

population stats.

PROJECTION LMWC 2005cr to 2016cr

Projecti

on

PROJECTION_2005cr_2016cr_LMWC_29J

UL2010 0

Projection factors for Solid and Liquid Municipal 

Waste Combustors.

PROJECTION TR1 comments 2005cs to 20XXcs 

-ptnonipm

Projecti

on

PROJECTION_2005cs_20XX_TR1_ptnonip

m_01FEB2011 0

Projection factors derived from Transport Rule 

comments.

PROJECTION aircraft 2005cs to 2030 JAN2010 

FAATAF

Projecti

on

PROJECTION_2005cs_2030_aircraft_JAN20

10_based_FAATAF_10FEB2011 0

Projection factors for aircraft derived from the 

FAA Terminal Area Forecast System.

PROJECTION cement ISIS 2013 policy

Projecti

on

PROJECTION_cementISIS_2016cr_17AUG2

010 0

Projection factors that implement the 2013 ISIS 

policy case for cement.

PROJECTION refueling 2005cs to 

2030cs_LDGHG_ref

Projecti

on

PROJECTION_2005cs_2030cs_LDGHG_ref

_onroad_refueling_04FEB2011 0 Projection factors for gasoline stage 2 refueling.

Table B-2. Datasets used to Create LDGHG 2030 Inventories for Nonpoint Sources

Control Program Name Type Dataset Version Description

CONTROL REPLACE NY 

SIP 2005cr to 2016cr Control

CONTROLS_replacement_NYSIP_O3_SC

C_2016cr_26AUG2010 0

Controls that reflect enforceable controls for NOx and VOC from the 

New York ozone SIP.

CONTROL RICE 

2016cr_05b Control

CONTROLS_replacement_RICE_2016cr_

21SEP2010 1

Controls for 2014 and 2016 that represent three separate RICE 

NESHAPs

CONTROL RICE SO2 

2014cs_05b Control

CONTROLS_replacement_RICE_SO2_20

14cs_05JAN2011 0

SO2 reductions from the Ultra-low Sulfur Diesel requirement for CI 

engines

CONTROL SULF rules: 

ME, NY, NJ 2018 and 

beyond Control

CONTROLS_SULF_rules_2018_and_beyo

nd_03FEB2011 0

SO2 reductions due to state sulfur content rules for fuel oil.

CONTROL TR1 Final 

CONTROL packet: 2021 Control CONTROLS_TR1_2021_09FEB2011 0 Controls for TCEQ oil and gas and non-ISIS related cement controls.

PROJECTION 2005 to 2030 

ag sector Projection

PROJECTION_2005cs_2030_ag_09FEB20

11 0 Projection factors for agriculture based on animal population stats.

PROJECTION RWC and 

landfills 2005 to 2030 Projection

PROJECTION_2005cs_2030cs_RWC_land

fills_08FEB2011 0 Projection factors for residential wood combustion and landfills.

PROJECTION refueling 

2005cs to 

2030cs_LDGHG_ref Projection

PROJECTION_2005cs_2030cs_LDGHG_r

ef_onroad_refueling_04FEB2011 0 Projection factors for gasoline stage 2 refueling.
50

Appendix C

Fuel distribution SCCs in nonpt and ptnonipm

Cross-walk between SCC and portable fuel containers (PFC), bulk plant storage (BPS), refinery to bulk terminal (RBT) and bulk terminal to pump 

(BTP).

scc SCC description

Cod

e

40600100 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Tank Cars and Trucks;undefined BTP

40400100 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;undefined RBT

40400173 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 7: Standing Loss - Int. Floating Roof w/ Secondary Seal RBT

2501060052 Storage and Transport;Petroleum and Petroleum Product Storage;Gasoline Service Stations;Stage 1: Splash Filling BTP

2501060100 Storage and Transport;Petroleum and Petroleum Product Storage;Gasoline Service Stations;Stage 2: Total BTP

2501050120 Storage and Transport;Petroleum and Petroleum Product Storage;Bulk Terminals: All Evaporative Losses;Gasoline RBT

2501011011 Storage and Transport;Petroleum and Petroleum Product Storage;Residential Portable Gas Cans;Permeation PFC

2505040120 Storage and Transport;Petroleum and Petroleum Product Transport;Pipeline;Gasoline RBT

2501060201 Storage and Transport;Petroleum and Petroleum Product Storage;Gasoline Service Stations;Underground Tank: Breathing and Emptying BTP

2501011012 Storage and Transport;Petroleum and Petroleum Product Storage;Residential Portable Gas Cans;Evaporation (includes Diurnal losses) PFC

2501055120 Storage and Transport;Petroleum and Petroleum Product Storage;Bulk Plants: All Evaporative Losses;Gasoline BPS

2501060053 Storage and Transport;Petroleum and Petroleum Product Storage;Gasoline Service Stations;Stage 1: Balanced Submerged Filling BTP

2501060051 Storage and Transport;Petroleum and Petroleum Product Storage;Gasoline Service Stations;Stage 1: Submerged Filling BTP

2501011013 Storage and Transport;Petroleum and Petroleum Product Storage;Residential Portable Gas Cans;Spillage During Transport PFC

2505020120 Storage and Transport;Petroleum and Petroleum Product Transport;Marine Vessel;Gasoline RBT

2501011014 Storage and Transport;Petroleum and Petroleum Product Storage;Residential Portable Gas Cans;Refilling at the Pump - Vapor Displacement PFC

40600401 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Filling Vehicle Gas Tanks - Stage II;Vapor Loss w/o Controls BTP

2501011015 Storage and Transport;Petroleum and Petroleum Product Storage;Residential Portable Gas Cans;Refilling at the Pump - Spillage PFC

2505000120 Storage and Transport;Petroleum and Petroleum Product Transport;All Transport Types;Gasoline RBT

2501012011 Storage and Transport;Petroleum and Petroleum Product Storage;Commercial Portable Gas Cans;Permeation PFC

2505030120 Storage and Transport;Petroleum and Petroleum Product Transport;Truck;Gasoline BTP

40600131 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Tank Cars and Trucks;Gasoline: Submerged Loading (Normal Service) BTP

40400250 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Loading Racks BPS

2501012012 Storage and Transport;Petroleum and Petroleum Product Storage;Commercial Portable Gas Cans;Evaporation (includes Diurnal losses) PFC
51

40600141 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Tank Cars and Trucks;Gasoline: Submerged Loading (Balanced Service) BTP

2660000000 Waste Disposal, Treatment, and Recovery;Leaking Underground Storage Tanks;Leaking Underground Storage Tanks;Total: All Storage Types BTP

2501012013 Storage and Transport;Petroleum and Petroleum Product Storage;Commercial Portable Gas Cans;Spillage During Transport PFC

40600136 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Tank Cars and Trucks;Gasoline: Splash Loading (Normal Service) BTP

40600403 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Filling Vehicle Gas Tanks - Stage II;Vapor Loss w/o Controls BTP

40400111 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 10: Standing Loss (67000 Bbl Capacity)-Floating Roof Tank RBT

40301151 Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Floating Roof Tanks (Varying Sizes);Gasoline: Standing Loss - Internal RBT 

40400150 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Miscellaneous Losses/Leaks: Loading Racks RBT

40400153 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Vapor Control Unit Losses RBT

40600238 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Marine Vessels;Gasoline: Barges Loading - Uncleaned Tanks RBT

40400179 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Specify Liquid: Internal Floating Roof (Primary/Secondary Seal) RBT

40400116 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 13/10/7: Withdrawal Loss (67000 Bbl Cap.) - Float Rf Tnk RBT

40400199 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;See Comment ** RBT

40400151 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Valves, Flanges, and Pumps RBT

40600307 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Gasoline Retail Operations - Stage I;Underground Tank Breathing and Emptying BTP

40400160 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Specify Liquid: Standing Loss - Internal Floating Roof w/ Primary Seal RBT

40301001 Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Fixed Roof Tanks (Varying Sizes);Gasoline RVP 13: Breathing Loss (67000 Bbl. Tank Size) RBT 

40400148 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 13/10/7: Withdrawal Loss - Ext. Float Roof (Pri/Sec Seal) RBT

40301102

Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Floating Roof Tanks (Varying Sizes);Gasoline RVP 10: Standing Loss (67000 Bbl. Tank 

Size) RBT

40301103 Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Floating Roof Tanks (Varying Sizes);Gasoline RVP 7: Standing Loss (67000 Bbl. Tank Size) RBT 

40688801 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Fugitive Emissions;Specify in Comments Field BTP

2501012014 Storage and Transport;Petroleum and Petroleum Product Storage;Commercial Portable Gas Cans;Refilling at the Pump - Vapor Displacement PFC

40600306 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Gasoline Retail Operations - Stage I;Balanced Submerged Filling BTP

40600240 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Marine Vessels;Gasoline: Barge Loading - Average Tank Condition RBT

40600501 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Pipeline Petroleum Transport - General - All Products;Pipeline Leaks RBT

40600236 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Marine Vessels;Gasoline: Ship Loading - Uncleaned Tanks RBT

40400178 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 13/10/7: Withdrawal Loss - Int. Float Roof (Pri/Sec Seal) RBT

40400170 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Specify Liquid: Standing Loss - Int. Floating Roof w/ Secondary Seal RBT

40600299 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Marine Vessels;Not Classified ** RBT

40400108 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 10: Working Loss (Diameter Independent) - Fixed Roof Tank RBT

40600298 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Marine Vessels;Not Classified ** RBT

40300201 Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Deleted - Do Not Use (See 4-03-011 and 4-07);Gasoline ** RBT 
52

40400152 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Vapor Collection Losses RBT

40600163 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Tank Cars and Trucks;Gasoline: Return with Vapor (Transit Losses) BTP

40400110 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 13: Standing Loss (67000 Bbl Capacity)-Floating Roof Tank RBT

40688802 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Fugitive Emissions;Specify in Comments Field BTP

2501012015 Storage and Transport;Petroleum and Petroleum Product Storage;Commercial Portable Gas Cans;Refilling at the Pump - Spillage PFC

40600301 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Gasoline Retail Operations - Stage I;Splash Filling BTP

40400162 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 10: Standing Loss - Int. Floating Roof w/ Primary Seal RBT

40400118 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 13: Filling Loss (10500 Bbl Cap.) - Variable Vapor Space RBT

40600232 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Marine Vessels;Gasoline: Ocean Barges Loading RBT

40600197 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Tank Cars and Trucks;Not Classified ** BTP

40400113 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 13: Standing Loss (250000 Bbl Cap.) - Floating Roof Tank RBT

40600302 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Gasoline Retail Operations - Stage I;Submerged Filling w/o Controls BTP

40400251 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Valves, Flanges, and Pumps BPS

40400161 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 13: Standing Loss - Int. Floating Roof w/ Primary Seal RBT

40400130 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Specify Liquid: Standing Loss - External Floating Roof w/ Primary Seal RBT

40400101 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 13: Breathing Loss (67000 Bbl Capacity) - Fixed Roof Tank RBT

40600101 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Tank Cars and Trucks;Gasoline: Splash Loading ** BTP

40301101

Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Floating Roof Tanks (Varying Sizes);Gasoline RVP 13: Standing Loss (67000 Bbl. Tank 

Size) RBT

40301007

Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Fixed Roof Tanks (Varying Sizes);Gasoline RVP 13: W orking Loss (Tank Diameter 

Independent) RBT

40400140 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Specify Liquid: Standing Loss - Ext. Float Roof Tank w/ Second'y Seal RBT

40400149 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Specify Liquid: External Floating Roof (Primary/Secondary Seal) RBT

40400210 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 13/10/7: Withdrawal Loss (67000 Bbl Cap.) - Float Rf Tnk BPS

40400279 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Specify Liquid: Internal Floating Roof (Primary/Secondary Seal) BPS

40400171 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 13: Standing Loss - Int. Floating Roof w/ Secondary Seal RBT

40400107 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 13: Working Loss (Diam. Independent) - Fixed Roof Tank RBT

40400262 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 10: Standing Loss - Int. Floating Roof w/ Primary Seal BTP

40400141 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 13: Standing Loss - Ext. Floating Roof w/ Secondary Seal RBT

40301105

Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Floating Roof Tanks (Varying Sizes);Gasoline RVP 10: Standing Loss (250000 Bbl. Tank 

Size) RBT

40400112 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 7: Standing Loss (67000 Bbl Capacity)- Floating Roof Tank RBT

40400203 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 7: Breathing Loss (67000 Bbl. Capacity) - Fixed Roof Tank BPS

40400114 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 10: Standing Loss (250000 Bbl Cap.) - Floating Roof Tank RBT

40600199 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Tank Cars and Trucks;Not Classified ** BTP
53

40400117 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 13/10/7: Withdrawal Loss (250000 Bbl Cap.) - Float Rf Tnk RBT

2501995000 Storage and Transport;Petroleum and Petroleum Product Storage;All Storage Types: Working Loss;Total: All Products BTP

40600239 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Marine Vessels;Gasoline: Tanker Ship - Ballasted Tank Condition RBT

40400205 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 10: Working Loss (67000 Bbl. Capacity) - Fixed Roof Tank BPS

40400230 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Specify Liquid: Standing Loss - External Floating Roof w/ Primary Seal BTP

40400132 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 10: Standing Loss - Ext. Floating Roof w/ Primary Seal RBT

40600502 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Pipeline Petroleum Transport - General - All Products;Pipeline Venting RBT

40600237 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Marine Vessels;Gasoline: Ocean Barges Loading - Uncleaned Tanks RBT

40400172 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 10: Standing Loss - Int. Floating Roof w/ Secondary Seal RBT

40600126 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Tank Cars and Trucks;Gasoline: Submerged Loading ** BTP

40400103 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 7: Breathing Loss (67000 Bbl. Capacity) - Fixed Roof Tank RBT

40400201 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 13: Breathing Loss (67000 Bbl Capacity) - Fixed Roof Tank BTP

40301003 Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Fixed Roof Tanks (Varying Sizes);Gasoline RVP 7: Breathing Loss (67000 Bbl. Tank Size) RBT 

40400202 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 10: Breathing Loss (67000 Bbl Capacity) - Fixed Roof Tank BTP

40400261 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 13: Standing Loss - Int. Floating Roof w/ Primary Seal BTP

40400404 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Petroleum Products - Underground Tanks;Gasoline RVP 10: Working Loss BTP

40600147 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Tank Cars and Trucks;Gasoline: Submerged Loading (Clean Tanks) BTP

40600234 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Marine Vessels;Gasoline: Ship Loading - Ballasted Tank RBT

40400260 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Specify Liquid: Standing Loss - Internal Floating Roof w/ Primary Seal RBT

40600399 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Gasoline Retail Operations - Stage I;Not Classified ** BTP

40301202 Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Variable Vapor Space;Gasoline RVP 10: Filling Loss RBT 

40301002 Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Fixed Roof Tanks (Varying Sizes);Gasoline RVP 10: Breathing Loss (67000 Bbl. Tank Size) RBT 

40400204 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 13: Working Loss (67000 Bbl. Capacity) - Fixed Roof Tank BPS

40400240 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Specify Liquid: Standing Loss - Ext. Floating Roof w/ Secondary Seal RBT

40400402 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Petroleum Products - Underground Tanks;Gasoline RVP 13: Working Loss BTP

40400249 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Specify Liquid: External Floating Roof (Primary/Secondary Seal) RBT

40400401 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Petroleum Products - Underground Tanks;Gasoline RVP 13: Breathing Loss BTP

40600231 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Marine Vessels;Gasoline: Ship Loading - Cleaned and Vapor Free Tanks RBT

40400115 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 7: Standing Loss (250000 Bbl Cap.) - Floating Roof Tank RBT

40400102 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 10: Breathing Loss (67000 Bbl Capacity) - Fixed Roof Tank RBT

40400232 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 10: Standing Loss - Ext. Floating Roof w/ Primary Seal BPS

40400142 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 10: Standing Loss - Ext. Floating Roof w/ Secondary Seal RBT
54

40400233 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 7: Standing Loss - External Floating Roof w/ Primary Seal BTP

40400131 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 13: Standing Loss - Ext. Floating Roof w/ Primary Seal RBT

40400109 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 7: Working Loss (Diameter Independent) - Fixed Roof Tank RBT

40400406 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Petroleum Products - Underground Tanks;Gasoline RVP 7: Working Loss BTP

40400253 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Miscellaneous Losses/Leaks: Vapor Control Unit Losses BPS

40300302 Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Deleted - Do Not Use (See 4-03-011 and 4-07);Gasoline ** RBT 

40400207 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 13: Standing Loss (67000 Bbl Cap.) - Floating Roof Tank BTP

40600162 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Tank Cars and Trucks;Gasoline: Loaded with Fuel (Transit Losses) BTP

40600707

Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Consumer (Corporate) Fleet Refueling - Stage I;Underground Tank Breathing 

and Emptying BTP

40400208 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 10: Standing Loss (67000 Bbl Cap.) - Floating Roof Tank BPS

40400403 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Petroleum Products - Underground Tanks;Gasoline RVP 10: Breathing Loss BTP

40600503 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Pipeline Petroleum Transport - General - All Products;Pump Station RBT

40400271 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 13: Standing Loss - Int. Floating Roof w/ Secondary Seal BTP

40600305 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Gasoline Retail Operations - Stage I;Unloading ** BTP

40400248 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 10/13/7: Withdrawal Loss - Ext. Float Roof (Pri/Sec Seal) BPS

40400206 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 7: Working Loss (67000 Bbl. Capacity) - Fixed Roof Tank BTP

40400104 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 13: Breathing Loss (250000 Bbl Capacity)-Fixed Roof Tank RBT

40400105 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 10: Breathing Loss (250000 Bbl Capacity)-Fixed Roof Tank RBT

40400278 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 10/13/7: Withdrawal Loss - Int. Float Roof (Pri/Sec Seal) BTP

40688805 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Fugitive Emissions;Specify in Comments Field BTP

40400106 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 7: Breathing Loss (250000 Bbl Capacity) - Fixed Roof Tank RBT

40600144 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Tank Cars and Trucks;Gasoline: Splash Loading (Balanced Service) BTP

40600198 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Tank Cars and Trucks;Not Classified ** BTP

40600233 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Marine Vessels;Gasoline: Barge Loading - Cleaned and Vapor Free Tanks BTP

40600241 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Marine Vessels;Gasoline: Tanker Ship - Ballasting BTP

40400143 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 7: Standing Loss - Ext. Floating Roof w/ Secondary Seal RBT

40400405 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Petroleum Products - Underground Tanks;Gasoline RVP 7: Breathing Loss BTP

40688803 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Fugitive Emissions;Specify in Comments Field RBT

40400270 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Specify Liquid: Standing Loss - Int. Floating Roof w/ Secondary Seal BPS

40400263 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 7: Standing Loss - Internal Floating Roof w/ Primary Seal BTP

40400231 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 13: Standing Loss - Ext. Floating Roof w/ Primary Seal BTP

40600702 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Consumer (Corporate) Fleet Refueling - Stage I;Submerged Filling w/o Controls BTP
55

40400119 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 10: Filling Loss (10500 Bbl Cap.) - Variable Vapor Space RBT

40400133 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 7: Standing Loss - External Floating Roof w/ Primary Seal RBT

40400163 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 7: Standing Loss - Internal Floating Roof w/ Primary Seal RBT

40400252 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Miscellaneous Losses/Leaks: Vapor Collection Losses BPS

40400272 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 10: Standing Loss - Int. Floating Roof w/ Secondary Seal BPS

40400241 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 13: Standing Loss - Ext. Floating Roof w/ Secondary Seal BPS

40400213 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 7: Filling Loss (10500 Bbl Cap.) - Variable Vapor Space BTP

40400211 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 13: Filling Loss (10500 Bbl Cap.) - Variable Vapor Space BTP

40301004 Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Fixed Roof Tanks (Varying Sizes);Gasoline RVP 13: Breathing Loss (250000 Bbl. Tank Size) RBT 

40600706 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Consumer (Corporate) Fleet Refueling - Stage I;Balanced Submerged Filling BTP

40600701 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Consumer (Corporate) Fleet Refueling - Stage I;Splash Filling BTP

40301006 Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Fixed Roof Tanks (Varying Sizes);Gasoline RVP 7: Breathing Loss (250000 Bbl. Tank Size) RBT 

40400212 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 10: Filling Loss (10500 Bbl Cap.) - Variable Vapor Space BTP

40301203 Petroleum and Solvent Evaporation;Petroleum Product Storage at Refineries;Variable Vapor Space;Gasoline RVP 7: Filling Loss RBT 

40600602 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Consumer (Corporate) Fleet Refueling - Stage II;Liquid Spill Loss w/o Controls BTP

40600504 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Pipeline Petroleum Transport - General - All Products;Pump Station Leaks RBT

2505020121 Storage and Transport;Petroleum and Petroleum Product Transport;Marine Vessel;Gasoline - Barge RBT

40400120 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Terminals;Gasoline RVP 7: Filling Loss (10500 Bbl Cap.) - Variable Vapor Space RBT

40400273 Petroleum and Solvent Evaporation;Petroleum Liquids Storage (non-Refinery);Bulk Plants;Gasoline RVP 7: Standing Loss - Int. Floating Roof w/ Secondary Seal BPS

40600235 Petroleum and Solvent Evaporation;Transportation and Marketing of Petroleum Products;Marine Vessels;Gasoline: Ocean Barges Loading - Ballasted Tank BTP

 

i U. S. Energy Information Administration. Annual Energy Outlook 2011 with Projections to 2035. Report No. DOE/EIA-0383. April 2011. 

http://205.254.135.7/forecasts/aeo/pdf/0383(2011).pdf
United States

Environmental Protection

Agency

Office of Air Quality Planning and Standards

Air Quality Assessment Division

Research Triangle Park, NC

Publication No. EPA-454/R-12-005

August, 2012