A national laboratory of the U.S. Department of Energy

Office of Energy Efficiency & Renewable Energy

National Renewable Energy Laboratory 

Innovation for Our Energy Future 

Source Energy and Emission 

Factors for Energy Use in 

Buildings 

M. Deru and P. Torcellini 

Technical Report 

NREL/TP-550-38617 

Revised June 2007 

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Technical Report 

NREL/TP-550-38617 

Revised June 2007 

Source Energy and Emission 

Factors for Energy Use in 

Buildings 

M. Deru and P. Torcellini 

Prepared under Task No. BEC71004 
NOTICE

This report was prepared as an account of work sponsored by an agency of the United States government. 

Neither the United States government nor any agency thereof, nor any of their employees, makes any 

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Source Energy and Emission Factors for Energy Use in 

Buildings 

Errata 

The June 2006 version of NREL/TP-550-38617 contained errors in the emissions data that have 

been corrected with this revised version of the report. The wrong numbers were displayed for 

the emission factors for mercury, PM10, and solid waste. In addition to correcting the errors, 

revised calculation methods were used and subbituminous coal was treated separately from 

bituminous coal. In addition, the emissions for CO2, SO2, NOX, and mercury from fossil fuels 

was adjusted to align with data from the EIA Electric Power Annual 2006 and EPA eGRID 

2006. Finally, ozone season NOX emission factors by state are included at the end of the 

document. 

The following specific changes were made to the document: 

1. The emission factor name “Equivalent carbon dioxide (CO2e)” replaces “global warming

potential (GWP).” GWP is an index comparing the radiative properties of a compound to

that of CO2.

2. The following tables were updated with revised energy and emission factors: 1 to 4, 6 to 11,

B-1 to B-11.

3. Figure 1 was replaced with the new figure from NERC with the new subregions.

4. Figure 2 was replaced with a graph of the revised data.

5. Table B-12 was added.

6. Two references were added with life cycle analysis data on the construction and operation of

coal and natural gas fired power plants.

This report is available at no cost from the National Renewable Energy Laboratory (NREL) at www.nrel.gov/publications
Acknowledgments 

The authors would like to thank the following individuals for reviewing this document: David Hansen, 

Drury Crawley, and John Ryan of DOE, Ron Judkoff, Craig Christensen, Dennis Barley, and Shanti Pless 

of NREL. In addition, the authors would like to thank James Littlefield of Franklin Associates for 

technical advice on energy and emissions inventories. 

iii

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Contents 

ACKNOWLEDGMENTS..........................................................................................................III

FOREWORD................................................................................................................................ V

SECTION 1 – PURPOSE............................................................................................................. 1

SECTION 2 – SCOPE.................................................................................................................. 1

2.1 – OVERVIEW .......................................................................................................................................1

2.2 – WHAT THIS REPORT DOES...............................................................................................................1

2.3 – WHAT THIS REPORT DOES NOT DO.................................................................................................1

SECTION 3 – DEFINITIONS, ABBREVIATIONS, AND ACRONYMS .............................. 1

3.1 – DEFINITIONS.....................................................................................................................................1

3.2 – ABBREVIATIONS...............................................................................................................................3

3.3 – ACRONYMS ......................................................................................................................................4

SECTION 4 – BACKGROUND .................................................................................................. 4

4.1 – GENERAL..........................................................................................................................................4

4.2 – ELECTRICITY GENERATION AND DISTRIBUTION..............................................................................5

SECTION 5 – ENERGY AND EMISSION FACTORS............................................................ 7

5.1 – ELECTRICITY ENERGY AND EMISSION FACTORS .............................................................................7

5.2 – DELIVERED FUEL ENERGY AND EMISSION FACTORS ......................................................................9

5.3 – EMISSION FACTORS FOR ON-SITE COMBUSTION ...........................................................................10

SECTION 6 – REFERENCES................................................................................................... 13

APPENDIX A – DERIVATION OF ENERGY AND EMISSION FACTORS..................... 14

APPENDIX B – ADDITIONAL ENERGY AND EMISSION DATA................................... 19

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Foreword 

People measure and analyze the energy performance of buildings for many reasons. Comparisons of 

energy use may be made between nations, regions, individual buildings, or systems within a building. 

Policy makers, owners, designers, operators, raters, and researchers use energy performance data. Many 

tools (or approaches) have been developed to analyze energy performance in different ways, at different 

levels of effort and precision, and at different stages in the life of a building. Each tool quantifies the 

building energy performance to fit the users’ needs. However, methods and metrics are often inconsistent 

with each other. In addition, performance numbers may be misrepresented or misused to predict energy 

savings beyond the accuracy of the numbers. 

The Performance Metrics Project is a U.S. Department of Energy commercial buildings research activity 

whose goal is to standardize the measurement and characterization of building energy performance. Its 

main products are clearly defined energy performance metrics and standard procedures for determining 

the performance metrics; its intents are to define common language and to create standards that produce 

consistent results independently of the user. Therefore, the terms and techniques are clearly defined with 

little room for interpretation. The more opportunity there is for interpretation, the higher the probability 

for disparity and “gaming” of the results. These procedures focus on reporting absolute numbers and not 

on comparisons of energy performance. Benchmarks are included only where well-established values 

apply. However, benchmarking of results by others can be improved by using the clearly defined 

absolute metrics determined by these procedures. 

This document supports the other measurement procedures and all building energy-monitoring projects by 

providing methods to calculate the source energy and emissions from the energy measured at the building. 

Energy and emission factors typically account for the conversion inefficiencies at the power plant and the 

transmission and distribution losses from the power plant to the building. The energy and emission 

factors provided here also include the precombustion effects, which are the energy and emissions 

associated with extracting, processing, and delivering the primary fuels to the point of conversion in the 

electrical power plants or directly in the buildings. Source energy factors for electricity are provided for 

the total fossil fuel, total nonrenewable energy, and total energy. The breakdown of the energy used to 

generate electricity is provided on the national level, interconnection level, and state level.

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Section 1 – Purpose 

This procedure provides source energy factors and emission factors to calculate the source (primary) 

energy and emissions from a building’s annual site energy consumption. 

Section 2 – Scope 

2.1 – Overview 

Source energy consumption and emissions from energy use must be calculated to determine the 

environmental impact of buildings; however, these calculations are often not completed and are usually 

not done in a consistent manner. Most analyses use the energy measured at the site, which is useful for 

understanding the performance of the building and the building systems, but it is not a good indicator of 

the environmental impacts from resource consumption and emissions associated with energy use. Site 

energy is also not a good metric for comparing buildings that use different energy types, buildings with 

on-site energy generation such as photovoltaics (PV), or buildings with cogeneration systems. 

2.2 – What This Report Does 

This report provides the energy and emission factors to calculate the source energy and emissions for 

electricity and fuels delivered to a facility and combustion of fuels at a facility. The factors for electricity 

are broken down by fuel type and presented for the continental United States, three grid interconnections, 

and each state. The electricity fuel and emission factors are adjusted for the electricity and the useful 

thermal output generated by combined heat and power (CHP) plants larger than one megawatt. The 

energy and emissions from extracting, processing, and transporting the fuels, also known as the 

precombustion effects, are included. 

2.3 – What This Report Does Not Do 

This report does not provide hourly or seasonal source energy factors. Time of use effects for electricity 

can be significant, but the data for such an analysis are difficult to obtain on a national basis and are 

beyond the scope of this report. The emissions from and the energy used for construction and 

decommissioning the power plants, hydroelectric dams, and energy infrastructure are not included. The 

energy and climate change emissions from these phases form a small fraction of the energy and emissions 

produced over the life of the facilities (Spath et al. 1999; Spath and Mann 2000). The energy associated 

with storage and disposal of spent nuclear waste is not included because reliable data are not available. 

This information should be analyzed when it becomes available to determine whether it is significant. 

Section 3 – Definitions, Abbreviations, and Acronyms 

3.1 – Definitions 

Annual 

A period that consists of 12 consecutive months. 

Criteria Pollutants 

The U.S. Environmental Protection Agency (EPA) has set national air quality standards for six 

principal air pollutants (also referred to as criteria pollutants): nitrogen dioxide (NO2), ozone, sulfur 

dioxide (SO2), particulate matter (PM), carbon monoxide (CO), and lead. Four of these pollutants 

(CO, lead, NO2, and SO2) result primarily from direct emissions from a variety of sources. PM 

results from direct emissions, but is also commonly formed when emissions of nitrogen oxides (NOx), 

sulfur oxides (SOx), ammonia, organic compounds, and other gases react in the atmosphere. Ozone is 

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not directly emitted, but is formed when NOx and volatile organic compounds react in the presence of 

sunlight (EPA 2005a). 

Emission Factor 

The mass of a pollutant emitted to the environment per unit of energy or fuel associated with the 

production, distribution, and use of the energy or fuel. 

Facility 

A set of one or more buildings or outdoor applications, or both, that is defined for the purpose of an 

energy analysis. The boundary of the facility used in the energy analysis should be clearly defined. 

Fuel Oil 

A liquid petroleum product that includes distillate fuel oil (No. 1, No. 2, and No. 4), and residual fuel 

oil (No. 5 and No. 6). 

Distillate Fuel Oil: A general classification for one of the petroleum fractions produced in 

conventional distillation operations. It is used primarily for space heating, on- and off-highway diesel 

engine fuel (including railroad engine fuel and fuel for agriculture machinery), and electric power 

generation. Included are Fuel Oils No. 1, No. 2, and No. 4; and Diesel Fuels No. 1, No. 2, and No. 4. 

Fuel oils and diesel fuel oils are very similar, but they do have different specifications. 

Residual Fuel Oil: The topped crude of refinery operation that includes No. 5 and No. 6 fuel oils as 

defined in American Society for Testing and Materials Specification D396 and Federal Specification 

VV-F-815C; Navy Special fuel oil as defined in Military Specification MIL-F-859E, including 

Amendment 2 (NATO Symbol F-77); and Bunker C fuel oil. Residual fuel oil is used to produce 

electric power, space heating, vessel bunkering, and for various industrial purposes. Imports of 

residual fuel oil include imported crude oil burned as fuel (EIA 2005a). 

Global Warming Potential (GWP) 

GWP is an index that describes the radiative characteristics of well-mixed greenhouse gases. It 

represents the combined effect of the times these gases remain in the atmosphere and their relative 

effectiveness in absorbing outgoing infrared radiation. This index approximates the time-integrated 

warming effect of a unit mass of a given greenhouse gas in today’s atmosphere, relative to that of 

carbon dioxide (CO2). GWP is an index for estimating the relative global warming contribution of 

atmospheric emissions of 1 kg of a particular greenhouse gas compared to emissions of 1 kg of CO2. 

This document uses the following GWPs based on a 100-year time horizon: 1 for CO2, 23 for 

methane (CH4), and 296 for nitrous oxide (N2O) (IPCC 2001). The equivalent CO2 emissions are 

calculated with the GWPs. 

Measure 

To determine a quantity with a calibrated instrument. This includes using previously measured data 

such as those shown on a utility bill or engineering log. 

Metric 

A standard definition of a measurable quantity. 

Particulate Matter PM10 and PM2.5 

Particulates can be directly introduced to the atmosphere from transportation vehicles, combustion, 

farming, and dirt roads. Particulates can also be formed in the atmosphere from chemical reactions of 

sunlight with emissions of NOx, SOx, ammonia, organic compounds, and other gases. PM10 is 

measure of particles in the atmosphere with a diameter of 10 micrometers or smaller. PM2.5 is a 

measure of particles 2.5 micrometers and smaller in the air and are sometimes called fine particles. 

PM2.5 have been associated with significant respiratory and cardiovascular health risks; however, 

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consistent and reliable data for emission factors are not available. EPA maintains separate National 

Ambient Air Quality Standards for PM10 and PM2.5 because they have different monitoring and 

implementation plans (EPA 2005a). 

Performance Metric 

A standard definition of a measurable quantity that indicates some aspect of performance. Section 4 

contains definitions of the specific performance metrics used in this procedure. 

Power Control Area (PCA) 

A PCA is a portion of an integrated power grid for which a single dispatcher has operational control 

of all electric generators. There are 112 PCAs reported in eGRID2006 (EPA 2007). 

Precombustion Effects 

The source energy used for and the emissions resulting from extracting, processing, and delivering a 

fuel to the point of use in a power plant or a building. 

Primary Energy 

The sum of the energy consumed at a facility and the energy required to extract, convert, and transmit 

that energy to the facility. (same as source energy) 

Site Energy 

The energy directly consumed at a facility typically measured with utility meters. 

Source Energy 

The sum of the energy consumed at a facility and the energy required to extract, convert, and transmit 

that energy to the facility. The source energy for electricity from hydroelectric power, solar energy, 

and wind is assumed to be equal to the electricity produced at the source; however, the transmission 

and distribution losses are accounted for in the electricity delivered to the facility. Source energy for 

electricity from thermal electric power plants fueled by geothermal and biomass is determined by 

assuming an efficiency of 33% for electricity production. 

Source Energy Factor 

The unit of source energy consumed per unit of energy or fuel delivered to the facility. 

Useful Thermal Output 

The thermal energy made available for use in any industrial or commercial process, or used in any 

heating or cooling application; i.e., total thermal energy made available for processes and applications 

other than electrical generation (EIA 2005b). 

Year 

A period of 365 consecutive days. 

3.2 – Abbreviations 

Anth anthracite coal 

Bit bituminous coal 

Btu British thermal unit 

CH4 methane 

CO carbon monoxide 

CO2 carbon dioxide 

CO2e equivalent carbon dioxide based on the GWP 

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GWP global warming potential 

HPS pumped hydro storage 

IP inch-pound – refers to the English system of measurement units 

kWh kilowatt hour 

LCI life cycle inventory 

LPG liquefied petroleum gas 

NO nitrogen oxide 

NOx nitrogen oxides 

N2O nitrous oxide 

PCA power control area 

PV photovoltaic 

PM2.5 particulate matter 2.5 micrometers in diameter and smaller 

PM10 particulate matter 10 micrometers in diameter and smaller 

SI International System of Units – refers to the metric system of measurement units 

SOx sulfur oxides 

SO2 sulfur dioxide 

Sub subituminous coal 

T&D transmission and distribution 

TNMOC total non-methane organic compounds 

3.3 – Acronyms 

DOE U.S. Department of Energy 

eGRID Emissions & Generation Resource Integrated Database 

EIA Energy Information Administration 

EPA U.S. Environmental Protection Agency 

ERCOT Electric Reliability Council of Texas 

GREET Greenhouse Gases, Regulated Emissions, and Energy Use in Transportation 

NERC North American Electrical Reliability Council 

Section 4 – Background 

4.1 – General 

Most building energy analyses are completed with the energy measured on site. The building site energy 

is typically measured by the utility meters and is the total of the electrical, gas, and other energies 

delivered to the facility. Site energy consumption can be useful for understanding the performance of the 

building and the building systems, but it does not tell the whole story of the environmental impacts from 

resource consumption and emissions associated with the energy use. In addition, site energy is not a good 

comparison metric for buildings that have different mixes of energy types, buildings with on-site energy 

generation such as PV, or buildings with cogeneration units. 

Energy analyses that use source or primary energy consumption typically use a fixed multiplier or source 

energy factor to estimate the source energy consumed to generate electricity based on national averages. 

There is usually no support or reference for the derivation of the source energy factor. For electricity 

production, the source energy multiplier typically varies from 3.0 to 3.33 depending on the study. This 

number is based on the assumption that most of the electricity was produced from thermal electric power 

plants. The result tells nothing of the fuel types consumed or the emissions from the electricity 

production. 

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4.2 – Electricity Generation and Distribution 

The electricity grid in the continental United States is divided into three main grids that have few 

connections and little energy transfer between them. These grids are named the Western Interconnection, 

Eastern Interconnection, and Electric Reliability Council of Texas (ERCOT) Interconnection (Figure 1). 

Note that the U.S., Canadian, and Mexican grids are separate with limited connections and energy 

transfer. Alaska and Hawaii have a variety of small local grids. The grid interconnections are managed 

by NERC through 10 regional reliability councils. The energy mixtures used to generate electricity in the 

continental United States, the three interconnections, Alaska, and Hawaii are listed in Table 1 and shown 

in Figure 2. For 2004 in the continental United States, the mix of primary energy used to generate 

electricity was 71% fossil fuels, 20% nuclear, 7% hydro, and 2% renewable. The “Other Fossil” fuel 

category includes tire-derived fuels, purchased steam, and other fuels. 

Figure 1 North American electrical grid interconnections, including the 10 

NERC regional reliability councils (NERC 2007) 

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Table 1 Percent Electricity Generation by Energy Type for 2004 

Energy Type National 

% 

Eastern

% 

Western

% 

ERCOT 

% 

Alaska 

% 

Hawaii 

% 

Bituminous Coal 27.8 34.3 13.1 0.0 0.0 1.0 

Subbitumious Coal 19.8 19.6 19.8 21.4 9.9 13.1 

Lignite Coal 2.3 1.4 0.0 14.8 0.0 0.0 

Natural Gas 18.3 12.7 27.4 49.4 55.5 1.5 

Petroleum Fuels 2.8 3.6 0.5 0.5 11.5 77.4 

Other Fossil Fuel 0.2 0.2 0.3 0.2 0.0 0.2 

Nuclear 19.9 23.0 9.9 12.4 0.0 0.0 

Hydro 6.8 3.4 24.6 0.3 23.0 0.8 

Renewable Fuels 1.5 1.7 1.3 0.2 0.1 4.2 

Geothermal 0.4 0.0 2.1 0.0 0.0 1.9 

Wind 0.4 0.1 1.0 0.9 0.0 0.1 

Solar (PV) 0.0 0.0 0.1 0.0 0.0 0.0 

Fossil Fuel Total 71.2 71.8 60.9 86.2 76.9 93.1 

Renewable (non hydro) 2.2 1.8 4.6 1.1 0.1 6.1 

0%

20%

40%

60%

80%

100%

Eastern Western ERCOT Alaska Hawaii National

Percent of Electricity Generatio

n

Solar (PV)

Wind

Geothermal

Renewable fuels

Hydro

Nuclear

Other Fossil

Petroleum Fuels

Natural Gas

Lignite Coal

Subbituminous Coal

Bituminous Coal

Total Fossil

Figure 2 Electricity generation fuel mix for the continental United States (national), three 

interconnections, Alaska, and Hawaii for 2004 (EIA 2006a) 

The question of what level of electricity generation data to use for a source energy analysis is not easy to 

answer. The options are national, interconnection, NERC region, NERC subregion, state, PCA, and 

utility. Typically, the goal of an energy analysis is to understand the impact of energy use or energy 

savings in a building compared to other options or to other buildings. It is often tempting to use source 

energy information at the utility level, which delivers the energy to the building. However, utilities are 

6 

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not isolated; energy is transferred around the grid where it is needed. Even between states, there is 

significant energy transfer; nine states in the Eastern Interconnection import more than 25% of their

electricity. The District of Columbia imports more than 98% of its electricity. The source of the 

imported energy is difficult to account for. However, less than 1% of the energy generated and us

the interconnections is transferred to an adjacent interconnection. The interconnection level for fuel and 

emission factors within the continental United States should be used to ensure consistent analysis. The 

information for Alaska and Hawaii should be used for buildings in these states. One problem with using

the interconnection level is that the boundaries of the interconnections are not well defined, and 

determining the correct interconnection for locations near the boundaries may be difficult. For e

some parts of Texas are outside of ERCOT; parts of northern and eastern Texas are in the Eastern 

Interconnection and parts of western Texas are in the Western Interconnection. The national fuel a

emission factors should be used for cases where the interconnection is not known. 

In cases where the analyzed building is within a state that has a small net imported 

ed with 

xample, 

nd 

amount of electricity 

r 

Section 5 – Energy and Emission factors 

5.1 – Electricity Energy and Emission Factors 

d emission factors for electricity generation. 

se 

ctors per unit of delivered electricity are provided in Table 2. These factors include the 

r 

gy source 

wer 

or is a net exporter of electricity, the state-level data can be used. The net imports and exports of 

electricity by state are supplied in Table B-7 (Appendix B). Source energy and emission factors fo

electricity generation at the state level are listed in Tables B-9 and B-10. 

Data from several sources were used to derive the energy an

(These data are summarized in Table A-1, and the calculation methods are presented in Appendix A. 

Addition data are presented in Appendix B.) The data presented are based on electricity generation in 

2004 reported on EIA Forms 906 and 920 (EIA 2006a) and the U.S. Life Cycle Inventory (LCI) Databa

(NREL 2005). 

Source energy fa

transmission and distribution (T&D) losses (first row of Table 2). Precombustion effects, which include 

extraction, processing, and transportation of the fuels, are also included. The precombustion energy 

accounts for 5% of the national total source energy factor and almost 12% of the total source factor fo

Hawaii. Energy to construct the power plants and energy infrastructures is not included as it is 

insignificant compared to the energy generated over the life of the facility. The Renewable Ener

energy factors are calculated using the fuel consumption reported on EIA forms 906 and 920 for 

geothermal and renewable fuels and assuming an energy factor of one for hydro, wind, and PV po

plants. The T&D losses are then added to get the source energy factor for the delivered electricity. 

Table 2 Source Energy Factors for Delivered Electricity for 2004 

(kWh of source energy per kWh of delivered electricity) 

National Eastern Western ERCOT Alaska Hawaii 

T&D Losses 9.9% 9.6% 8.4% 16.1% 12.9 % 8.9 % 

Fossil Fuel Energy * 2.500 2.528 2.074 3.168 3.368 3.611 

Nonrenewable Energy ** 3.188 3.321 2.415 3.630 3.386 3.653 

Renewable Energy *** 0.177 0.122 0.480 0.029 0.264 0.368 

Total Energy 3.365 3.443 2.894 3.658 3.650 4.022 

* Fossil Fuel Energy includes all coal, natur etroleu and o il fuel al gas, p m fuels, ther foss

** Nonrenewable Energy includes Fossil Fuel Energy and nuclear 

*** Renewable Energy includes hydro, renewable fuels, geothermal, wind, and solar PV 

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The total emission factors (combustion plus precombustion) per delivered kWh of electricity for major 

pollutants in the continental United States and each major grid are shown in Tables 3 and 4. The separate 

emission factors from combustion and precombustion effects for electricity generation are shown in 

Tables B-3 through B-6 in IP and SI units. The precombustion emissions account for about 5% of the 

CO2 and 10% of the CO2e emissions. The precombustion emissions of CH4 are approximately two orders 

of magnitude greater than the combustion emissions because of the high amount of CH4 released when 

coal is mined and processed. 

The PM factors are for direct emissions and do not include the effect of particulate formation in the 

atmosphere from chemical reactions of sunlight with emissions of NOX, SOX, organic compounds, and 

other gases. The PM composition and emission levels are complex functions of boiler firing 

configuration, boiler operation, pollution control equipment, and fuel properties. The solid waste 

emissions consists of bottom ash, fly ash, boiler slag, and flue gas desulfurization sludge, minus the 

amount diverted from the waste stream and used in other products. The GWPs are based on 100-year 

time horizon for CO2, CH4, and N2O. See the definition for GWP in Section 3.1 for more information. 

Table 3 Total Emission Factors for Delivered Electricity 

(lb of pollutant per kWh of electricity) 

Pollutant (lb) National Eastern Western ERCOT Alaska Hawaii 

CO2e 1.67E+00 1.74E+00 1.31E+00 1.84E+00 1.71E+00 1.91E+00 

CO2 1.57E+00 1.64E+00 1.22E+00 1.71E+00 1.55E+00 1.83E+00 

CH4 3.71E-03 3.59E-03 3.51E-03 5.30E-03 6.28E-03 2.96E-03 

N2O 3.73E-05 3.87E-05 2.97E-05 4.02E-05 3.05E-05 2.00E-05 

NOX 2.76E-03 3.00E-03 1.95E-03 2.20E-03 1.95E-03 4.32E-03 

SOX 8.36E-03 8.57E-03 6.82E-03 9.70E-03 1.12E-02 8.36E-03 

CO 8.05E-04 8.54E-04 5.46E-04 9.07E-04 2.05E-03 7.43E-03 

TNMOC 7.13E-05 7.26E-05 6.45E-05 7.44E-05 8.40E-05 1.15E-04 

Lead 1.31E-07 1.39E-07 8.95E-08 1.42E-07 6.30E-08 1.32E-07 

Mercury 3.05E-08 3.36E-08 1.86E-08 2.79E-08 3.80E-08 1.72E-07 

PM10 9.16E-05 9.26E-05 6.99E-05 1.30E-04 1.09E-04 1.79E-04 

Solid Waste 1.90E-01 2.05E-01 1.39E-01 1.66E-01 7.89E-02 7.44E-02 

Table 4 Total Emission Factors for Delivered Electricity 

(kg of pollutant per kWh of electricity) 

Pollutant (kg) National Eastern Western ERCOT Alaska Hawaii 

CO2e 7.58E-01 7.88E-01 5.94E-01 8.34E-01 7.74E-01 8.65E-01 

CO2 7.14E-01 7.45E-01 5.54E-01 7.74E-01 7.05E-01 8.32E-01 

CH4 1.68E-03 1.63E-03 1.59E-03 2.40E-03 2.85E-03 1.34E-03 

N2O 1.69E-05 1.76E-05 1.35E-05 1.82E-05 1.38E-05 9.06E-06 

NOX 1.25E-03 1.36E-03 8.84E-04 9.98E-04 8.83E-04 1.96E-03 

SOX 3.79E-03 3.89E-03 3.09E-03 4.40E-03 5.09E-03 4.10E-03 

CO 3.65E-04 3.87E-04 2.48E-04 4.12E-04 9.31E-04 3.37E-03 

TNMOC 3.24E-05 3.29E-05 2.93E-05 3.38E-05 3.81E-05 5.20E-05 

Lead 5.92E-08 6.30E-08 4.06E-08 6.44E-08 2.86E-08 5.99E-08 

Mercury 1.39E-08 1.52E-08 8.42E-09 1.27E-08 1.72E-08 7.79E-08 

PM10 4.16E-05 4.20E-05 3.17E-05 5.92E-05 4.94E-05 8.12E-05 

Solid Waste 8.63E-02 9.28E-02 6.29E-02 7.55E-02 3.58E-02 3.37E-02 

8 

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5.2 – Delivered Fuel Energy and Emission Factors 

The source energy factors for fuel delivered to buildings are listed in Table 5. These factors represent the 

energy required to extract, process, and deliver the fuel to the building per unit of energy in the fuel 

assuming the heating values listed in the table. The precombustion emission factors for delivering fuels 

to buildings are shown in Tables 6 and 7. These numbers are based on national averages and are derived 

from the Fuels and Energy Precombustion LCI data module (NREL 2005). These emission factors do not 

include emissions from use of the fuel in the building, which is reported in Section 5.3. 

Table 5 Source Energy Factors for Fuel Delivered to Buildings 

Fuel Source Energy Factor Higher Heating Value 

Anthracite Coal 1.029 12,700 Btu/lb 29,539 kJ/kg 

Bituminous Coal 1.048 12,155 Btu/lb 28,270 kJ/kg 

Subbitumious Coal 1.066 8,818 Btu/lb 20,509 kJ/kg 

Lignite Coal 1.102 6,465 Btu/lb 15,038 kJ/kg 

Natural Gas 1.092 1,010 Btu/ft3 * 37,631 kJ/m3 * 

Residual Fuel Oil 1.191 149,500 Btu/gal 41,666 kJ/L 

Distillate Fuel Oil 1.158 138,700 Btu/gal 38,656 kJ/L 

Gasoline 1.187 100,000 Btu/gal 27,870 kJ/L 

LPG 1.151 91,000 Btu/gal 25,362 kJ/L 

Kerosene 1.205 135,000 Btu/gal 27,870 kJ/L 

* Heating value for 60°F and 14.70 psia (15.6°C and 101325 Pa). 

Table 6 Precombustion Emission Factors for Fuel Delivered to Buildings 

(lb of pollutant per unit of fuel) 

Anthracite 

Coal 

Bituminous 

Coal 

Lignite 

Coal 

Natural 

Gas 

Residual 

Fuel Oil 

Distillate 

Fuel Oil Gasoline LPG Kerosene Pollutant 

(lb) 

1000 lb 1000 lb 1000 lb 1000 ft3 * 1000 gal 1000 gal 1000 gal 1000 gal 1000 gal 

CO2e 9.76E+1 1.89E+2 1.37E+2 2.78E+1 4.47E+3 4.10E+3 3.50E+3 2.56E+3 3.83E+3 

CO2 5.85E+1 9.32E+1 1.07E+2 1.16E+1 3.57E+3 3.28E+3 2.80E+3 2.05E+3 3.06E+3 

CH4 1.69E+0 4.15E+0 1.30E+0 7.04E-1 3.81E+1 3.49E+1 2.98E+1 2.18E+1 3.26E+1 

N2O 1.08E-3 1.80E-3 1.45E-3 2.35E-4 6.57E-2 6.03E-2 5.14E-2 3.77E-2 5.63E-2 

NOX 2.51E-1 7.69E-1 3.33E-1 1.64E-2 2.73E+1 2.50E+1 2.13E+1 1.57E+1 2.34E+1 

SOX 2.02E-1 3.34E-1 4.52E-1 1.22E+0 3.86E+1 3.55E+1 3.02E+1 2.22E+1 3.31E+1 

CO 2.40E-1 4.30E-1 4.73E-1 1.36E-2 1.15E+2 1.06E+2 9.00E+1 6.61E+1 9.86E+1 

TNMOC 3.74E-4 7.36E-4 8.55E-4 4.56E-5 2.31E-2 2.12E-2 1.81E-2 1.33E-2 1.98E-2 

Lead 3.44E-6 5.21E-6 3.13E-5 2.41E-7 1.47E-4 1.35E-4 1.15E-4 8.43E-5 1.26E-4 

Mercury 7.45E-7 1.29E-6 1.20E-6 5.51E-8 2.42E-5 2.22E-5 1.89E-5 1.39E-5 2.07E-5 

PM10 6.04E-3 2.10E-2 1.01E-2 8.17E-4 6.99E-1 6.42E-1 5.47E-1 4.01E-1 5.99E-1 

PMunspecified 2.11E+0 1.65E+0 1.31E-1 1.42E-3 2.71E+0 2.49E+0 2.12E+0 1.56E+0 2.32E+0 

Solid Waste 2.74E+2 2.40E+2 5.77E+0 1.60E+0 4.21E+2 3.87E+2 3.30E+2 2.42E+2 3.61E+2 

* Gas volume at 60°F and 14.70 psia. 

9 

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Table 7 Precombustion Emission Factors for Fuel Delivered to Buildings 

(kg of pollutant per unit of fuel) 

Anthracite 

Coal 

Bituminous 

Coal 

Lignite 

Coal 

Natural 

Gas 

Residual 

Fuel Oil 

Distillate 

Fuel Oil Gasoline LPG Kerosene 

Pollutant 

(kg) 

1000 kg 1000 kg 1000 kg 1000 m3 * 1000 L 1000 L 1000 L 1000 L 1000 L 

CO2e 9.76E+1 1.89E+2 1.37E+2 4.46E-1 5.35E+2 4.92E+2 4.19E+2 3.07E+2 4.59E+2 

CO2 5.85E+1 9.32E+1 1.07E+2 1.86E-1 4.28E+2 3.93E+2 3.35E+2 2.46E+2 3.67E+2 

CH4 1.69E+0 4.15E+0 1.30E+0 1.13E-2 4.56E+0 4.19E+0 3.57E+0 2.62E+0 3.91E+0 

N2O 1.08E-3 1.80E-3 1.45E-3 3.77E-6 7.87E-3 7.23E-3 6.16E-3 4.52E-3 6.74E-3 

NOX 2.51E-1 7.69E-1 3.33E-1 2.62E-4 3.27E+0 3.00E+0 2.56E+0 1.88E+0 2.80E+0 

SOX 2.02E-1 3.34E-1 4.52E-1 1.95E-2 4.63E+0 4.25E+0 3.62E+0 2.66E+0 3.96E+0 

CO 2.40E-1 4.30E-1 4.73E-1 2.18E-4 1.38E+1 1.27E+1 1.08E+1 7.91E+0 1.18E+1 

TNMOC 3.74E-4 7.36E-4 8.55E-4 7.30E-7 2.77E-3 2.54E-3 2.17E-3 1.59E-3 2.37E-3 

Lead 3.44E-6 5.21E-6 3.13E-5 3.86E-9 1.76E-5 1.62E-5 1.38E-5 1.01E-5 1.51E-5 

Mercury 7.45E-7 1.29E-6 1.20E-6 8.82E-10 2.89E-6 2.66E-6 2.26E-6 1.66E-6 2.48E-6 

PM10 6.04E-3 2.10E-2 1.01E-2 1.31E-5 8.38E-2 7.70E-2 6.56E-2 4.81E-2 7.18E-2 

PMunspecified 2.11E+0 1.65E+0 1.31E-1 2.27E-5 3.25E-1 2.98E-1 2.54E-1 1.86E-1 2.78E-1 

Solid Waste 2.74E+2 2.40E+2 5.77E+0 2.57E-2 5.05E+1 4.64E+1 3.95E+1 2.90E+1 4.32E+1 

* Gas volume at 15.6°C and 101325 Pa. 

5.3 – Emission Factors for On-Site Combustion 

The emission factors for combustion of fuels in buildings are listed in Tables 8 to 11. Unless otherwise 

noted, these emission factors are based on data from GREET 1.6 (ANL 2005), which uses EPA AP-42 

(EPA 2005B) and other sources. The numbers include the emissions from combustion on site; the 

precombustion emissions in Tables 6 and 7 are not included. No data are available for some pollutants; 

this does not mean that the emissions are zero or negligible. The emission factors should be calculated 

for these pollutants when reliable data are available. 

Emissions from combustion depend on the composition of the fuel, the equipment, and the maintenance 

of the equipment. In general, these factors provide baseline emissions from uncontrolled combustion 

sources. If more detailed information is known about the fuel or the combustion equipment, it should be 

used.

10 

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Table 8 Emission Factors for On-Site Combustion in a Commercial Boiler 

(lb of pollutant per unit of fuel) 

Commercial Boiler 

Bituminous 

Coal* 

Lignite 

Coal ** Natural Gas Residual 

Fuel Oil 

Distillate 

Fuel Oil LPG Pollutant 

(lb) 

1000 lb 1000 lb 1000 ft3 *** 1000 gal 1000 gal 1000 gal 

CO2e 2.74E+03 2.30E+03 1.23E+02 2.56E+04 2.28E+04 1.35E+04

CO2 2.63E+03 2.30E+03 1.22E+02 2.55E+04 2.28E+04 1.32E+04

CH4 1.15E-01 2.00E-02 2.50E-03 2.31E-01 2.32E-01 2.17E-01

N2O 3.68E-01 ND † 2.50E-03 1.18E-01 1.19E-01 9.77E-01

NOX 5.75E+00 5.97E+00 1.11E-01 6.41E+00 2.15E+01 1.57E+01

SOX 1.66E+00 1.29E+01 6.32E-04 4.00E+01 3.41E+01 0.00E+00

CO 2.89E+00 4.05E-03 9.33E-02 5.34E+00 5.41E+00 2.17E+00

VOC ND † ND † 6.13E-03 3.63E-01 2.17E-01 3.80E-01

Lead 1.79E-03 6.86E-02 5.00E-07 1.51E-06 ND † ND †

Mercury 6.54E-04 6.54E-04 2.60E-07 1.13E-07 ND † ND †

PM10 2.00E+00 ND † 8.40E-03 4.64E+00 1.88E+00 4.89E-01

* from the U.S. LCI data module: Bituminous Coal Combustion in an Industrial Boiler (NREL 2005) 

** from the U.S. LCI data module: Lignite Coal Combustion in an Industrial Boiler (NREL 2005) 

*** Gas volume at 60°F and 14.70 psia. 

†

 no data available 

Table 9 Emission Factors for On-Site Combustion in a Commercial Boiler 

(kg of pollutant per unit of fuel) 

Commercial Boiler 

Bituminous 

Coal * Lignite Coal ** Natural Gas Residual 

Fuel Oil 

Distillate 

Fuel Oil 

Pollutant LPG 

(kg) 

1000 kg 1000 kg 1000 m3 *** 1000 L 1000 L 1000 L 

CO2e 2.74E+03 2.30E+03 1.97E+00 3.06E+03 2.73E+03 1.62E+03 

CO2 2.63E+03 2.30E+03 1.96E+00 3.06E+03 2.73E+03 1.59E+03 

CH4 1.15E-01 2.00E-02 4.00E-05 2.76E-02 2.78E-02 2.60E-02 

N2O 3.68E-01 ND † 4.00E-05 1.41E-02 1.43E-02 1.17E-01 

NOX 5.75E+00 5.97E+00 1.78E-03 7.68E-01 2.58E+00 1.88E+00 

SOX 1.66E+00 1.29E+01 1.01E-05 4.79E+00 4.09E+00 0.00E+00 

CO 2.89E+00 4.05E-03 1.50E-03 6.40E-01 6.48E-01 2.60E-01 

VOC ND † ND † 9.82E-05 4.35E-02 4.39E-02 4.55E-02 

Lead 1.79E-03 6.86E-02 8.01E-09 1.81E-07 ND † ND †

Mercury 6.54E-04 6.54E-04 4.16E-09 1.35E-08 ND † ND †

PM10 2.00E+00 ND † 1.35E-04 5.56E-01 2.25E-01 5.86E-02 

* from the U.S. LCI data module: Bituminous Coal Combustion in an Industrial Boiler (NREL 2005) 

** from the U.S. LCI data module: Lignite Coal Combustion in an Industrial Boiler (NREL 2005) 

*** Gas volume at 15.6°C and 101325 Pa. 

†

 no data available 

11 

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Table 10 Emission Factors for On-Site Combustion in Other Equipment 

(lb of pollutant per unit of fuel) 

Stationary Reciprocating Engine Small Turbine Residential 

Furnace *

Natural Gas Distillate 

Fuel Oil Gasoline Natural Gas Distillate Fuel Oil Natural Gas 

Pollutant 

(lb) 

1000 ft3 ** 1000 gal 1000 gal 1000 ft3 ** 1000 gal 1000 ft3 ** 

CO2e 1.37E+02 2.27E+04 1.76E+04 1.25E+02 2.29E+04 1.21E+02 

CO2 1.16E+02 2.25E+04 1.72E+04 1.22E+02 2.28E+04 1.20E+02 

CH4 8.38E-01 1.20E+00 8.31E+00 5.26E-02 2.58E-01 2.30E-03 

N2O 3.41E-03 6.11E-01 5.51E-01 4.54E-03 6.11E-01 2.20E-03 

NOX 3.56E+00 4.76E+02 3.02E+02 3.51E-01 4.02E+01 9.40E-02 

SOX 6.32E-04 3.24E+01 4.18E+00 6.32E-04 3.24E+01 6.00E-04 

CO 2.29E+00 1.26E+02 1.22E+03 1.75E-01 2.66E+00 4.00E-02 

VOC 2.06E-03 1.22E+01 2.56E+01 2.06E-03 4.08E-01 5.50E-03 

Lead 5.00E-07 ND † ND † 5.00E-07 1.40E-08 5.00E-07 

Mercury 2.60E-07 ND † ND † 2.60E-07 1.20E-09 2.60E-07 

PM10 1.66E-02 1.49E+01 2.40E+00 2.64E-02 5.19E+00 7.60E-03 *

 data from EPA’s AP-42, volume 1, 5th edition, 1995 (EPA 2005b) 

** Gas volume at 60°F and 14.70 psia. 

†

 no data available 

Table 11 Emission Factors for On-Site Combustion in Other Equipment 

(kg of pollutant per unit of fuel) 

Stationary Reciprocating Engine Small Turbine Residential 

Furnace *

Natural Gas Distillate 

Fuel Oil Gasoline Natural Gas Distillate Fuel Oil Natural Gas 

Pollutant 

(kg) 

1000 m3 ** 1000 L 1000 L 1000 m3 ** 1000 L 1000 m3 ** 

CO2e 2.19E+00 2.72E+03 2.11E+03 2.00E+00 2.75E+03 1.93E+00 

CO2 1.86E+00 2.70E+03 2.07E+03 1.96E+00 2.73E+03 1.92E+00 

CH4 1.34E-02 1.44E-01 9.96E-01 8.42E-04 3.09E-02 3.68E-05 

N2O 5.46E-05 7.32E-02 6.60E-02 7.28E-05 7.32E-02 3.52E-05 

NOX 5.70E-02 5.70E+01 3.62E+01 5.62E-03 4.82E+00 1.51E-03 

SOX 1.01E-05 3.88E+00 5.01E-01 1.01E-05 3.88E+00 9.61E-06 

CO 3.66E-02 1.51E+01 1.46E+02 2.81E-03 3.19E-01 6.41E-04 

VOC 1.36E-03 1.46E+00 3.07E+00 3.30E-05 4.89E-02 8.81E-05 

Lead 8.01E-09 ND † ND † 8.01E-09 1.68E-09 8.01E-09 

Mercury 4.16E-09 ND † ND † 4.16E-09 1.44E-10 4.16E-09 

PM10 2.67E-04 1.78E+00 2.87E-01 4.22E-04 6.22E-01 1.22E-04 

* data from the EPA's AP-42, volume 1, 5th edition, 1995 (EPA 2005B) 

** Gas volume at 15.6°C and 101325 Pa. 

†

 no data available 

12 

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Section 6 – References 

ANL (2005). Greenhouse Gases, Regulated Emissions, and Energy Use in Transportation. GREET 

Version 1.6 (draft). www.transportation.anl.gov/software/GREET/index.html. Center for Transportation 

Research, Chicago, IL: Argonne National Laboratory (accessed July 26, 2005). 

EIA (2005a). Energy Information Administration Glossary of Electricity Terms. 

www.eia.doe.gov/cneaf/electricity/page/glossary.html. Washington, DC: U.S. Department of Energy 

(accessed July 6, 2005). 

EIA (2005b). Energy Information Administration Energy Glossary. 

www.eia.doe.gov/glossary/glossary_main_page.htm. Washington, DC: U.S. Department of Energy. 

(accessed July 6, 2005). 

EIA (2006a). Form 906 and Form 920, www.eia.doe.gov/cneaf/electricity/page/eia906_920.html Energy 

Information Administration. www.eia.doe.gov/. Washington, DC: U.S. Department of Energy (accessed 

April 17, 2006). 

EIA (2006b). Electric Power Annual 2005, Energy Information Administration. www.eia.doe.gov/. 

Washington, DC: U.S. Department of Energy (accessed January, 2007). 

EPA (2002). eGRID 2002. Emissions and Generation Resource Integrated Database. 

www.epa.gov/cleanenergy/egrid. Washington, DC: U.S. Environmental Protection Agency. 

EPA (2005a). Six Common Air Pollutants. www.epa.gov/oar/urbanair/6poll.html. Washington, DC: 

U.S. Environmental Protection Agency (accessed September 2005). 

EPA (2005b). Clearing House for Inventories & Emissions Factors (Chief). www.epa.gov/ttn/chief/. 

Washington, DC: U.S. Environmental Protection Agency (accessed July 29, 2005). 

EPA (2007). eGRID 2006 version 2.1. Emissions and Generation Resource Integrated Database. 

www.epa.gov/cleanenergy/egrid. Washington, DC: U.S. Environmental Protection Agency. 

IPCC (2001). Climate Change 2001: A Scientific Basis, Intergovernmental Panel on Climate Change; 

Houghton, J.T.; Ding, Y.; Griggs, D.J.; Noguer, M.; van der Linden, P.J.; Dai, X.; Johnson, C.A.; and 

Maskell, K. eds. Cambridge, U.K.: Cambridge University Press. 

NERC (2007). NERC. www.nerc.com/. Princeton, NJ: North American Eclectic Reliability Council 

(accessed May 31, 2007). 

NREL (2005). U.S. LCI Database. www.nrel.gov/lci. Golden, CO: National Renewable Energy 

Laboratory (accessed June 6, 2005). 

Spath, P. L., Mann, M. K., and Kerr, D. R. (1999). Life Cycle Assessment of Coal-fired Power 

Production. NREL/TP-570-25119. Golden, CO: National Renewable Energy Laboratory. 

Spath, P. L. and Mann, M. K. (2000). Life Cycle Assessment of a Natural Gas Combined-Cycle Power 

Generation System. NREL/TP-570-27715. Golden, CO: National Renewable Energy Laboratory. 

13 

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Appendix A – Derivation of Energy and Emission Factors 

Table A-1 summarizes the data sources used in deriving the energy and emission factors. The EIA uses 

34 fuel type codes for reporting electricity generation. Table A-2 shows how these fuel type codes were 

mapped to the 11 energy groups used in this document based on similar production and combustion 

effects. 

Table A-3 presents a summary of the steps used for calculating the source energy factors. The electricity 

from pumped hydro storage (HPS) is sometimes reported as a negative number and sometimes as a 

positive number. When it was positive, it was added to the Hydro electricity total. Negative values were 

divided and subtracted from the bituminous coal and nuclear totals, which are the most probable base load 

energy groups. 

The emission factors were calculated by following the steps in Table A-4. 

Nomenclature 

k,i e Combustion emissions per physical quantity of fuel for each pollutant 

pc k,i

e Combustion emissions per physical quantity of fuel for each pollutant 

Ej Total annual electricity generation by region 

pci E Precombustion energy per quantity of fuel type 

fi, j Combustion source energy factor by energy type and region 

j,i pc f Precombustion source energy factor by energy type and region 

j

Fd Total source energy factor for delivered electricity by region (includes precombustion) 

j

Fg Combustion source energy factor for generated electricity by region 

j

Fpc Precombustion source energy factor by region 

Lj T*D losses by region 

Mi, j Physical quantity of fuel used for electricity generation by fuel type and region (adjusted 

for useful thermal heat from CHP plants greater than 1 MW) 

j,k

Pg Total emission factor per generated kWh of electricity by pollutant and region 

j,k

Pd Total emission factor per delivered kWh of electricity by pollutant and region 

Si, j Energy quantity of fuel used for electricity generation by fuel type and region (adjusted 

for useful thermal heat from CHP plants greater than 1 MW) 

j,i δ Fraction of electricity generated by energy type and region 

j Adjusted electricity generation totals for HPS by source energy type and region ,i ε

ρ j,k Combustion emission factor per generated kWh of electricity by pollutant and region 

j,k ρpc Precombustion emission factor per generated kWh of electricity by pollutant and region 

θ j,i Combustion source energy factor for a composite unit of electricity by energy type and 

region 

Subscripts: 

i Fuel type index 

j Region index 

k Pollutant index 

pc Precombustion 

14 

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Table A-1 Data Sources 

Data Source Data Used 

EIA Forms 906/920 for 2004 (EIA 2006a) Power plant data for: 

Electric fuel consumption by quantity 

Electric fuel consumption by energy 

Net electricity generation 

EIA Electric Power Annual 2005 (EIA 2006b) CO2 emission factors for bituminous, subbituminous, 

and lignite coals; natural gas; and residual fuel oil. 

Total annual emissions for CO2, NOx, and SOx for 

2004. 

eGRID 2000 (EPA 2002) T&D losses by NERC region 

Annual net imported and exported electricity by state 

eGRID 2006 version 2.1 (EPA 2007) Hg, NOx, and SOx emission factors for bituminous, 

subbituminous, and lignite coals; natural gas; and 

residual fuel oil. 

Total annual emissions for CO2, NOx, Sox, and Hg for 

2004. 

Electricity Generation LCI data module (NREL 2005) T&D losses by NERC region 

LCI data modules for Fuels and Energy 

Precombustion and Petroleum Refining (NREL 2005) 

Precombustion energy and emissions for processing the 

fuels per physical quantity of fuel 

Biomass Combustion in Utility Turbine LCI data 

module (NREL 2005) 

Precombustion energy for wood 

Emissions for wood combustion in utility turbines 

LCI data modules for Combustion in Utility Boilers for 

Bituminous Coal, Lignite Coal, Natural Gas, Residual 

Fuel Oil, and Distillate Fuel Oil (NREL 2005) 

Emissions for combustion in utility boilers for each fuel 

type 

LCI data modules for Combustion in Industrial Boilers 

for Bituminous Coal and Lignite Coal (NREL 2005) 

Emission data for on-site combustion in building 

equipment 

GREET 1.6 (ANL 2005) Emission data for on-site combustion in building 

equipment 

Clearing House for Inventories & Emissions Factors 

(EPA 2005b) 

Emission data for natural gas combustion in a 

residential furnace 

Climate Change 2001 (IPCC 2001) GWP indices 

15 

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Table A-2 Mapping of EIA Fuel Type Codes to Energy Groups 

Energy Group EIA Fuel Type Codes EIA Fuel Descriptions 

Bituminous Coal BIT, WC, SC bituminous coal, anthracite coal, coal, waste coal, 

coal based synfuel 

Subbituminous Coal SUB subbituminous coal 

Lignite Coal LIG lignite coal 

Natural Gas NG, BFG, OG, PG natural gas, blast furnace gas, other gas, 

gaseous propane 

Petroleum Fuels DFO, JF, KER, PC, RFO, 

WO 

distillate fuel oil, jet fuel, kerosene, petroleum 

coke, residual fuel oil, waste oil 

Other Fossil Fuel TDF, OTH, PUR Tire-derived fuels, other, purchased steam 

Nuclear NUC nuclear 

Hydro HYC conventional hydro power 

Renewable Fuels AB, MSW, OBS, WDS, OBL, 

BLQ, SLW, WDL, LFG, OBG 

agricultural crop by-product, municipal solid 

waste, other biomass solids, wood solids, other 

biomass liquids, black liquor, sludge waste, wood 

waste liquids, landfill gas, other biomass gas 

Geothermal GEO geothermal 

Wind WND wind 

Solar (PV) SUN PV solar 

HPS * pumped hydro storage 

* The electricity from HPS was added to the hydro electricity if it was positive and subtracted from the Bit/sub/anth Coal 

and Nuclear electricity if it was negative. 

16 

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Table A-3 Steps for Calculating Electricity Source Energy Factors 

Step Description 

1 

Starting with the EIA 906/920 2004 data (EIA 2006a), fill in missing NERC region names for 

imputed data based on the reported state. Use the NERC region that most of the state lies in. The 

imputed data represent 2.3% of the total generation. 

2 Sort the data by NERC region and fuel type. Sort this data again by mapping the EIA Fuel Type 

codes to the energy groups as shown in Table A-2. Repeat at the state level. 

3 

Adjust the electricity generation totals ( ) to include the HPS. j,i ε

Assumptions: Add positive values to the hydro electricity total. Subtract negative values from the 

bituminous coal and nuclear totals 

4 

Calculate the fraction of electricity generated by energy type and region (see Table 1). 

j

j,i

j,i E

ε

=δ

5 

Calculate the combustion source energy factors by energy type and region (see Table B-1). 

j,i

j,i

j,i

S

f

ε = 

Assumptions: The source energy factor for hydro, wind, and solar PV is one. 

6 

Calculate the combustion source energy factors for a composite unit of electricity by energy type 

and region (see Table B-2). 

j,ij,ij,i f δ∗=θ

7 

Calculate the total combustion source energy factors for generated electricity by region. 

∑θ=

i

g j,i j

F

8 

Determine the precombustion source energy factors by energy type and region. The 

precombustion energy per quantity of fuel is from the Fuels and Energy Precombustion LCI data 

module (NREL 2005). 

j

j,ipc

pc E

ME

f i

j,i

× =

9 

Calculate the total precombustion source energy factors by region (see Table B-2). 

=∑

i

pc pc j j,i

fF

10 

Calculate the total fuel factors for delivered energy including the T&D losses (see Table B-2). The 

T&D losses (see Table 1) are from the Electricity Generation LCI data module (NREL 2005) and 

eGRID 2000 (EPA 2002). ( )( ) pcgd L1FFF j jj j = + +

17 

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Table A-4 Steps for Calculating Emission Factors for Electricity Generation 

Step Description 

1 

Extract the emission factors for fuel combustion in utility boilers for each pollutant and fuel type 

from the appropriate LCI data module. Use the CO2 emission factors for coal, natural gas, and 

residual fuel oil from EIA Electric Power Annual (EIA 2006b). Determine the NOx, SOx, SO2, and 

Hg emission factors for coal, natural gas, and residual fuel oil from eGRID 2006 version 1 (EPA 

2006).

Assumptions: Emission factors for combustion of residual fuel oil are used for all petroleum fuels. 

Emission factors for bituminous coal are used for other fossil fuels. Emissions for electricity 

generation from gasification of wood are used for all renewable fuels. 

2 

Compile the precombustion emission factors for each pollutant and fuel type from the Fuels and 

Energy Precombustion LCI data module. 

Assumptions: The emissions for petroleum products were allocated by mass between all of the 

petroleum refining coproducts. 

3 

Calculate the combustion emissions for each pollutant and region in lb pollutant/kWh generated 

electricity. 

∑ ×=ρ

i

Me j,ik,ij,k

4 

Calculate the precombustion emissions for each pollutant and region in lb pollutant/kWh generated 

electricity. 

∑ ×=ρ

i

pc Me j,ipc j,k k,i

5 

Calculate the total emissions for generated electricity for each pollutant and region. 

j,k j,k

P = ρ + ρpcj,kg

6 

Calculate the total emissions for generated electricity for each pollutant and region. ( ) j,kj,k TDj = gd + L1PP

18 

This report is available at no cost from the National Renewable Energy Laboratory (NREL) at www.nrel.gov/publications
Appendix B – Additional Energy and Emission Data 

The source energy factors for generating electricity for each fuel type are listed in Table B-1. These 

numbers are calculated from the source energy used and electricity generated as reported by the electricity 

generators in the EIA Forms 906 and 920 (step 5 of Table A-3). The source energy for hydro, wind, and 

solar are set equal to the electricity generated, which provides a source energy factor of 1.0. 

Table B-1 Source Energy Factors by Fuel Type for Generating Electricity 

(kWh of source energy per kWh of generated electricity) 

Energy Group National Eastern Western ERCOT Alaska Hawaii 

Bituminous Coal 2.996 2.993 3.035 5.696 

Subbituminous Coal 3.089 3.084 3.126 3.059 3.937 2.863 

Lignite Coal 3.262 3.252 3.272 

Natural Gas 2.627 2.629 2.631 2.620 3.405 3.198 

Petroleum Fuels 3.117 3.094 3.404 4.022 3.311 3.049 

Other Fossil Fuel 2.465 2.377 2.859 2.140 2.856 

Nuclear 3.075 3.075 3.083 3.060 

Hydro 1.000 1.000 1.000 1.000 1.000 1.000 

Renewable Fuels 4.459 4.527 3.947 6.419 2.868 5.157 

Geothermal 6.160 6.160 6.160 

Wind 1.000 1.000 1.000 1.000 1.000 

Solar (PV) 1.000 1.000 

The source energy factors for delivered electricity are listed in Table B-2. These factors represent the 

components by energy type used to generated one kWh of electricity based on annual energy totals. For 

example, for every kWh of electricity delivered to the consumer in the United States, the first column lists 

all the fuel that went into that electricity based on annual totals. The numbers in table were calculated 

following steps in Table A-3 (the top section from step 6, the precombustion energy from steps 8 and 9, 

and the totals from step 10). 

19 

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Table B-2 Source Energy Factor Components per Delivered kWh of Electricity for 2004 

(kWh of source energy per kWh of delivered electricity) 

Energy Group National Eastern Western ERCOT Alaska Hawaii 

Bituminous Coal 0.916 1.125 0.430 0.000 0.000 0.061 

Subbituminous Coal 0.672 0.663 0.670 0.759 0.442 0.407 

Lignite Coal 0.081 0.049 0.000 0.562 0.000 0.000 

Natural Gas 0.528 0.367 0.780 1.502 2.134 0.051 

Petroleum Fuels 0.096 0.122 0.017 0.024 0.428 2.568 

Other Fossil Fuel 0.005 0.005 0.008 0.005 0.000 0.007 

Nuclear 0.671 0.774 0.329 0.441 0.000 0.000 

Hydro 0.074 0.037 0.267 0.003 0.259 0.009 

Renewable Fuels 0.073 0.083 0.057 0.015 0.005 0.233 

Geothermal 0.025 0.000 0.143 0.000 0.000 0.125 

Wind 0.004 0.002 0.011 0.010 0.000 0.001 

Solar (PV) 0.000 0.000 0.001 0.000 0.000 0.000 

Fossil Precombustion Energy 0.152 0.148 0.128 0.233 0.283 0.413 

Total Precombustion Energy 0.168 0.166 0.140 0.253 0.300 0.455 

Totals without Precombustion Energy

Total Fossil Fuel 2.299 2.332 1.905 2.851 3.004 3.094 

Total Nonrenewable Energy 2.970 3.106 2.234 3.292 3.004 3.094 

Total Energy 3.146 3.228 2.713 3.321 3.268 3.462 

Totals with Precombustion Energy

Total Fossil Fuel 2.450 2.480 2.033 3.084 3.287 3.507 

Total Nonrenewable Energy 3.138 3.272 2.374 3.545 3.304 3.549 

Total Energy 3.315 3.394 2.853 3.574 3.568 3.917 

Tables B-3 through B-6 show the emission factors per generated kWh for combustion in utility boilers 

and precombustion effects in IP and SI units. The emissions are based on the emissions data from the 

LCI data modules for each fuel type combustion in utility boilers (NREL 2005), and on the fuel totals 

used for electricity generation as reported on the 2004 EIA Forms 906 and 920 (EIA 2006). These 

numbers do not include the effects of losses in T&D of the electricity. 

20 

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Table B-3 Combustion Emission Factors for Generated Electricity 

(lb of pollutant per kWh of electricity) 

Emission (lb) National Eastern Western ERCOT Alaska Hawaii 

CO2e 1.37E+00 1.43E+00 1.07E+00 1.38E+00 1.26E+00 1.48E+00 

CO2 1.36E+00 1.42E+00 1.06E+00 1.37E+00 1.25E+00 1.47E+00 

CH4 1.45E-05 1.43E-05 1.26E-05 2.01E-05 2.01E-05 1.87E-05 

N2O 3.25E-05 3.39E-05 2.62E-05 3.27E-05 2.46E-05 1.44E-05 

NOX 2.03E-03 2.21E-03 1.45E-03 1.53E-03 1.24E-03 2.29E-03 

SOX 5.25E-03 5.98E-03 3.27E-03 2.78E-03 1.77E-03 6.03E-03 

CO 2.82E-04 2.59E-04 2.95E-04 4.69E-04 6.24E-04 3.22E-04 

TNMOC 4.71E-05 4.64E-05 4.37E-05 6.11E-05 7.21E-05 5.62E-05 

Lead 1.14E-07 1.23E-07 8.00E-08 1.12E-07 5.21E-08 1.12E-07 

Mercury 2.70E-08 2.98E-08 1.65E-08 2.32E-08 3.28E-08 1.56E-07 

PM10 6.96E-05 6.98E-05 5.42E-05 1.00E-04 8.13E-05 1.21E-04 

Solid Waste 5.20E-02 5.40E-02 3.43E-02 7.07E-02 1.55E-02 1.28E-02 

Table B-4 Combustion Emission Factors for Generated Electricity 

(kg of pollutant per kWh of electricity) 

Emission (kg) National Eastern Western ERCOT Alaska Hawaii 

CO2e 6.20E-01 6.50E-01 4.86E-01 6.24E-01 5.72E-01 6.69E-01 

CO2 6.15E-01 6.46E-01 4.82E-01 6.19E-01 5.69E-01 6.67E-01 

CH4 6.58E-06 6.50E-06 5.69E-06 9.11E-06 9.11E-06 8.48E-06 

N2O 1.47E-05 1.54E-05 1.19E-05 1.48E-05 1.12E-05 6.53E-06 

NOX 9.19E-04 1.00E-03 6.59E-04 6.93E-04 5.64E-04 1.04E-03 

SOX 2.38E-03 2.71E-03 1.48E-03 1.26E-03 8.04E-04 2.74E-03 

CO 1.28E-04 1.17E-04 1.34E-04 2.13E-04 2.83E-04 1.46E-04 

TNMOC 2.14E-05 2.10E-05 1.98E-05 2.77E-05 3.27E-05 2.55E-05 

Lead 5.19E-08 5.56E-08 3.63E-08 5.07E-08 2.36E-08 5.10E-08 

Mercury 1.22E-08 1.35E-08 7.50E-09 1.05E-08 1.49E-08 7.09E-08 

PM10 3.16E-05 3.16E-05 2.46E-05 4.55E-05 3.69E-05 5.50E-05 

Solid Waste 2.36E-02 2.45E-02 1.56E-02 3.21E-02 7.03E-03 5.81E-03 

21 

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22 

Table B-5 Precombustion Emission Factors for Generated Electricity 

(lb of pollutant per kWh of electricity) 

Emission (lb) National Eastern Western ERCOT Alaska Hawaii 

CO2e 1.54E-01 1.52E-01 1.38E-01 2.09E-01 2.50E-01 2.77E-01 

CO2 7.63E-02 7.63E-02 6.32E-02 1.04E-01 1.22E-01 2.14E-01 

CH4 3.36E-03 3.26E-03 3.23E-03 4.55E-03 5.54E-03 2.70E-03 

N2O 1.46E-06 1.47E-06 1.25E-06 1.90E-06 2.40E-06 3.94E-06 

NOX 4.80E-04 5.24E-04 3.45E-04 3.68E-04 4.81E-04 1.68E-03 

SOX 2.36E-03 1.85E-03 3.02E-03 5.57E-03 8.17E-03 2.27E-03 

CO 4.50E-04 5.20E-04 2.09E-04 3.12E-04 1.19E-03 6.50E-03 

TNMOC 1.78E-05 1.98E-05 1.58E-05 2.97E-06 2.25E-06 4.92E-05 

Lead 4.44E-09 4.22E-09 2.54E-09 1.04E-08 3.74E-09 8.93E-09 

Mercury 8.13E-10 8.50E-10 6.16E-10 8.96E-10 7.86E-10 1.53E-09 

PM10 1.37E-05 1.47E-05 1.03E-05 1.19E-05 1.51E-05 4.33E-05 

Solid Waste 1.21E-01 1.33E-01 9.37E-02 7.26E-02 5.44E-02 5.55E-02 

Table B-6 Precombustion Emission Factors for Generated Electricity 

(kg of pollutant per kWh of electricity) 

Emission (kg) National Eastern Western ERCOT Alaska Hawaii 

CO2e 6.99E-02 6.88E-02 6.25E-02 9.47E-02 1.13E-01 1.26E-01 

CO2 3.46E-02 3.46E-02 2.87E-02 4.70E-02 5.53E-02 9.71E-02 

CH4 1.52E-03 1.48E-03 1.46E-03 2.06E-03 2.51E-03 1.23E-03 

N2O 6.64E-07 6.65E-07 5.66E-07 8.60E-07 1.09E-06 1.79E-06 

NOX 2.18E-04 2.38E-04 1.56E-04 1.67E-04 2.18E-04 7.60E-04 

SOX 1.07E-03 8.38E-04 1.37E-03 2.53E-03 3.71E-03 1.03E-03 

CO 2.04E-04 2.36E-04 9.49E-05 1.42E-04 5.42E-04 2.95E-03 

TNMOC 8.05E-06 9.00E-06 7.17E-06 1.35E-06 1.02E-06 2.23E-05 

Lead 2.01E-09 1.91E-09 1.15E-09 4.74E-09 1.70E-09 4.05E-09 

Mercury 3.69E-10 3.85E-10 2.79E-10 4.06E-10 3.56E-10 6.92E-10 

PM10 6.23E-06 6.68E-06 4.68E-06 5.41E-06 6.84E-06 1.97E-05 

Solid Waste 5.49E-02 6.02E-02 4.25E-02 3.29E-02 2.47E-02 2.52E-02 

Data on the electricity generation by state are shown in Tables B-7 through B-12. The state data for 

electricity generation and the fuel used for electricity generation are derived from 2004 EIA Forms 906 

and 920 (EIA 2006). The state level data should be used with caution, because several states import 

electricity from neighboring states, Canada, or Mexico, and the source energy for the imported electricity 

is not always known. Thirteen states (including the District of Columbia) imported more than 15% of 

their electricity in 2000. Table B-7 shows the net imported electricity in GWh (+ for imports and – for 

exports) and as a percent of the consumed electricity for net importers of electricity and as a percent of 

the generated electricity for net exporters of electricity. The state net import and export data are from 

year 2000 data reported in eGRID (EPA 2002). 

The percent of electricity generation by fuel type for each state is shown in Table B-8. The source energy 

factors are in Table B-9 and the emission factors are shown in Tables B-10 and B-11. The ozone season 

is from May to September, and the NOX emissions for this season are shown Table B-12. The ozone 

season NOX emissions do not include precombustion emissions because these emissions do not occur at 

the power plant, and we are typically only concerned about ozone formation near the power plant. These 

numbers are for electricity generated within the states and do not include the electricity imported into the 

state. 

This report is available at no cost from the National Renewable Energy Laboratory (NREL) at www.nrel.gov/publications
Table B-7 Net Imported Electricity by State for 2000 (EPA 2002) 

AK AL AR AZ CA CO CT DC DE FL G

Net Imported Electricity (GWh) (neg. for exported) 

0 -28,838 1,988 -20,072 66,974 3,127 -301 10,526 5,960 23,606 8

Net Imported (+ % of consumption) or Net Exported (− % of generation) 

0.0% -23.2% 4.8% -22.5% 26.1% 7.2% -0.9% 98.8% 52.7% 12.0% 7

ID IL IN KS KY LA MA MD ME MI M

Net Imported Electricity (GWh) (neg. for exported) 

11,891 -25,084 -17,822 -4,350 -5,231 -350 16,479 15,408 384 10,835 13

Net Imported (+ % of consumption) or Net Exported (− % of generation) 

52.0% -14.1% -13.9% -9.7% -5.6% -0.4% 31.8% 25.3% 3.2% 10.3% 22

MT NC ND NE NH NJ NM NV NY OH O

Net Imported Electricity (GWh) (neg. for exported) 

-

11,784 9,883 -18,764 -1,864 -3,349 17,454 -12,292 -4,807 17,665 31,362 -

Net Imported (+ % of consumption) or Net Exported (− % of generation) 

-

40.9% 8.2% -60.0% -6.4% -22.4% 24.9% -36.2% -13.5% 12.4% 18.9% -0

RI SC SD TN TX UT VA VT WA WI W

Net Imported Electricity (GWh) (neg. for exported) 

1,951 -6,486 -394 9,097 -143 -10,236 30,141 -20 -1,067 11,758 -56

Net Imported (+ % of consumption) or Net Exported (− % of generation) 

26.7% -7.0% -4.1% 9.5% 0.0% -28.0% 30.2% -0.3% -1.0% 18.0% -60

23 

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Table B-8 Percent Electricity Generation by Energy Type by State for 2004 (not counting imported el

Energy Type AK AL AR AZ CA CO CT DC DE FL GA 

Bit. Coal (%) 0.0 40.3 0.2 17.6 1.1 26.0 4.9 0.0 60.5 29.7 4Sub. Coal (%) 9.9 14.2 48.6 20.4 0.0 48.6 8.2 0.0 0.0 0.0 1Lignite Coal (%) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Natural Gas (%) 55.5 11.8 9.7 27.0 52.5 22.4 24.8 0.0 25.6 35.1 Pet. Fuels (%) 11.5 0.2 1.0 0.0 1.2 0.0 5.3 100.0 13.9 17.1 Other Fossil (%) 0.0 0.0 0.2 1.3 0.1 0.0 0.5 0.0 0.0 1.0 Nuclear (%) 0.0 23.0 29.8 26.8 15.1 0.0 50.7 0.0 0.0 14.3 2Hydro (%) 23.0 7.7 7.1 6.7 17.5 2.5 1.4 0.0 0.0 0.1 Ren. Fuel s (%) 0.1 2.7 3.4 0.0 3.2 0.1 4.1 0.0 0.0 2.7 Geothermal (%) 0.0 0.0 0.0 0.0 6.7 0.0 0.0 0.0 0.0 0.0 Wind (%) 0.0 0.0 0.0 0.0 2.2 0.5 0.0 0.0 0.0 0.0 Solar (PV) (%) 0.0 0.0 0.0 0.0 0.3 0.0 0.0 0.0 0.0 0.0 Fossil Fuel (%) 76.9 66.5 59.8 66.4 54.9 97.0 43.7 100.0 100.0 82.9 6Renewable (%)

(non Hydro) 0.1 2.7 3.4 0.0 12.4 0.5 4.1 0.0 0.0 2.7 

Energy Type ID IL IN KS KY LA MA MD ME MI MN 

Bit. Coal (%) 0.4 10.5 66.3 1.4 88.1 0.0 21.5 56.1 1.9 18.5 Sub. Coal (%) 0.5 38.7 28.2 72.5 3.0 19.3 0.0 0.0 0.0 39.2 6Lignite Coal (%) 0.0 0.0 0.0 0.0 0.0 4.8 0.0 0.0 0.0 0.0 Natural Gas (%) 15.7 1.9 4.4 1.8 0.6 49.9 44.2 3.1 51.4 12.7 Pet. Fuels (%) 0.0 0.4 0.4 1.8 3.8 3.9 15.8 6.3 6.9 0.8 Other Fossil (%) 0.2 0.1 0.4 0.0 0.0 0.8 0.0 0.0 2.1 0.1 Nuclear (%) 0.0 48.0 0.0 21.7 0.0 17.4 12.1 28.0 0.0 25.1 2Hydro (%) 77.9 0.1 0.3 0.0 4.0 1.1 2.1 4.8 18.0 1.3 Ren. Fuel s (%) 5.3 0.4 0.1 0.0 0.4 2.8 4.3 1.6 19.7 2.3 Geothermal (%) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Wind (%) 0.0 0.0 0.0 0.8 0.0 0.0 0.0 0.0 0.0 0.0 Solar (PV) (%) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Fossil Fuel (%) 16.8 51.5 99.5 77.5 95.6 78.7 81.5 65.5 62.3 71.3 6Renewable (%)

(non Hydro) 5.3 0.4 0.1 0.8 0.4 2.8 4.3 1.6 19.7 2.3 

24 

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Table B-8 (page 2) Percent Electricity Generation by Energy Type by State for 2004 (not counting importe

Energy Type MT NC ND NE NH NJ NM NV NY OH OK 

Bit. Coal (%) 1.1 59.8 0.0 0.0 17.1 18.3 0.1 48.5 13.8 79.4 Sub. Coal (%) 62.5 0.0 1.9 63.9 0.0 0.0 88.8 0.0 2.6 7.1 5Lignite Coal (%) 1.2 0.0 91.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Natural Gas (%) 0.2 2.0 0.2 0.9 22.6 28.7 9.1 43.5 19.8 1.1 3Pet. Fuels (%) 1.6 0.5 0.1 0.1 8.2 2.5 0.1 0.3 15.3 0.9 Other Fossil (%) 0.0 0.2 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Nuclear (%) 0.0 31.7 0.0 32.0 42.6 48.1 0.0 0.0 29.1 10.8 Hydro (%) 33.1 4.4 5.2 2.9 5.5 0.1 0.4 4.3 17.4 0.5 Ren. Fuel s (%) 0.2 1.4 0.0 0.1 4.0 2.3 0.0 0.0 1.9 0.3 Geothermal (%) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 3.4 0.0 0.0 Wind (%) 0.0 0.0 0.7 0.1 0.0 0.0 1.6 0.0 0.1 0.0 Solar (PV) (%) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Fossil Fuel (%) 66.7 62.5 94.1 64.9 47.9 49.5 98.0 92.3 51.6 88.5 9Renewable (%)

(non Hydro) 0.2 1.4 0.7 0.2 4.0 2.3 1.6 3.4 2.0 0.3 

Energy Type RI SC SD TN TX UT VA VT WA WI WV 

Bit. Coal (%) 0.0 39.2 0.0 47.0 0.0 95.8 44.4 0.0 0.0 10.2 9Sub. Coal (%) 0.0 0.0 48.2 12.3 24.5 0.0 0.0 0.0 10.2 59.5 Lignite Coal (%) 0.0 0.0 0.0 0.0 13.6 0.0 0.0 0.0 0.0 0.0 Natural Gas (%) 96.8 3.9 1.5 0.3 49.4 2.4 8.1 0.1 8.6 4.0 Pet. Fuels (%) 1.0 0.9 0.3 0.2 0.4 0.1 6.5 0.3 0.1 1.2 Other Fossil (%) 0.0 0.1 0.0 0.0 0.2 0.0 0.0 0.0 0.0 0.1 Nuclear (%) 0.0 51.6 0.0 29.0 10.4 0.0 35.2 70.5 8.8 19.7 Hydro (%) 0.1 2.5 47.9 10.7 0.3 1.2 2.0 21.7 70.1 3.3 Ren. Fuel s (%) 2.1 1.8 0.0 0.6 0.3 0.0 3.7 7.2 1.6 1.9 Geothermal (%) 0.0 0.0 0.0 0.0 0.0 0.5 0.0 0.0 0.0 0.0 Wind (%) 0.0 0.0 2.1 0.0 0.8 0.0 0.0 0.2 0.7 0.2 Solar (PV) (%) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Fossil Fuel (%) 97.8 44.1 50.0 59.7 88.2 98.3 59.0 0.4 18.8 75.0 9Renewable (%)

(non Hydro) 2.1 1.8 2.1 0.6 1.1 0.5 3.7 7.4 2.3 2.0 

25 

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Table B-9 Source Energy Factors for Delivered Electricity by State for 2004 

(kWh of source energy consumed per kWh of delivered electricity) 

AK AL AR AZ CA CO CT DC DE FL GA HI IA 

Without Precombustion Fossil Fuel 3.004 2.103 1.909 2.039 1.631 3.082 1.208 6.790 3.580 2.468 2.189 3.094 2.982 0Nonrenewable 3.004 2.876 2.907 2.931 2.147 3.082 2.908 6.790 3.580 2.948 3.081 3.094 3.364 0Total 3.268 3.155 3.074 3.004 2.951 3.117 3.160 6.790 3.580 3.103 3.231 3.462 3.427 1With Precombustion Fossil Fuel 3.290 2.228 2.049 2.181 1.766 3.264 1.311 7.835 3.842 2.663 2.305 3.509 3.184 0Nonrenewable 3.308 3.016 3.068 3.089 2.291 3.283 3.028 7.938 3.862 3.161 3.215 3.551 3.593 0Total 3.572 3.296 3.235 3.163 3.095 3.318 3.281 7.938 3.862 3.317 3.364 3.920 3.656 1

KY LA MA MD ME MI MN MO MS MT NC ND NE 

Without Precombustion Fossil Fuel 3.202 2.452 2.352 2.161 1.662 2.297 2.362 2.966 2.384 2.389 1.984 3.337 2.207 1Nonrenewable 3.202 3.035 2.771 3.100 1.662 3.162 3.214 3.266 3.170 2.389 3.048 3.337 3.280 2Total 3.277 3.128 3.029 3.248 2.693 3.285 3.348 3.288 3.273 2.776 3.172 3.402 3.317 3With Precombustion Total Fossil Fuel 2.952 3.351 2.658 2.556 2.335 1.817 2.433 2.521 3.166 2.568 2.565 2.074 3.640 2Total Nonrenewable 3.705 3.367 3.259 2.993 3.294 1.829 3.314 3.396 3.492 3.374 2.586 3.153 3.678 3Total 3.714 3.442 3.352 3.250 3.442 2.860 3.437 3.530 3.513 3.476 2.973 3.276 3.743 3

NY OH OK OR PA RI SC SD TN TX UT VA VT 

Without Precombustion Fossil Fuel 1.723 2.871 3.023 0.839 2.002 2.414 1.420 1.772 1.933 2.957 3.197 1.993 0.018 0Nonrenewable 2.710 3.232 3.023 0.839 3.211 2.414 3.173 1.772 2.916 3.325 3.197 3.196 2.383 0Total 3.011 3.245 3.095 1.597 3.292 2.495 3.258 2.320 3.056 3.357 3.251 3.439 3.031 1With Precombustion Fossil Fuel 1.879 3.012 3.234 0.908 2.110 2.625 1.486 1.898 2.026 3.210 3.354 2.111 0.021 0Nonrenewable 2.885 3.390 3.254 0.913 3.336 2.635 3.255 1.913 3.025 3.600 3.370 3.333 2.400 0Total 3.185 3.403 3.326 1.671 3.417 2.716 3.340 2.461 3.165 3.632 3.424 3.576 3.048 1

26 

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Table B-10 Total Emission Factors for Delivered Electricity by State (lb of pollutant per kWh of elec

Pollutant (lb) AK AL AR AZ CA CO CT DC DE FL G

CO2e 1.71E+00 1.58E+00 1.57E+00 1.67E+00 7.75E-01 2.23E+00 7.29E-01 4.26E+00 2.43E+00 1.49E+00 1.62CO2 1.55E+00 1.50E+00 1.48E+00 1.56E+00 6.88E-01 2.10E+00 6.76E-01 4.11E+00 2.28E+00 1.40E+00 1.54CH4 6.28E-03 3.23E-03 3.47E-03 4.02E-03 3.60E-03 4.96E-03 2.14E-03 6.27E-03 5.94E-03 3.74E-03 2.9N2O 3.05E-05 3.55E-05 4.16E-05 3.69E-05 1.39E-05 5.36E-05 1.48E-05 2.89E-05 4.56E-05 2.63E-05 3.7NOX 1.95E-03 2.78E-03 2.65E-03 2.64E-03 5.88E-04 3.68E-03 1.10E-03 9.94E-03 3.92E-03 2.46E-03 2.9SOX 1.12E-02 8.24E-03 5.13E-03 8.86E-03 6.42E-03 9.64E-03 4.23E-03 2.15E-02 1.53E-02 9.44E-03 7.7CO 2.05E-03 5.33E-04 6.44E-04 6.16E-04 5.36E-04 7.78E-04 7.89E-04 1.96E-02 1.85E-03 1.80E-03 5.2TNMOC 8.40E-05 8.18E-05 9.48E-05 5.34E-05 8.89E-05 6.72E-05 8.71E-05 1.28E-04 7.93E-05 8.88E-05 7.6Lead 6.30E-08 1.22E-07 1.48E-07 1.19E-07 6.95E-09 1.87E-07 4.00E-08 2.71E-07 1.42E-07 8.22E-08 1.3Mercury 3.80E-08 2.50E-08 3.15E-08 2.41E-08 2.86E-09 3.75E-08 1.81E-08 4.44E-07 4.91E-08 4.29E-08 2.8PM10 1.09E-04 7.82E-05 9.07E-05 8.36E-05 4.71E-05 1.16E-04 4.78E-05 4.25E-04 1.27E-04 8.91E-05 7.9Solid Waste 7.89E-02 1.88E-01 2.27E-01 1.84E-01 1.25E-02 2.88E-01 5.39E-02 7.07E-02 2.03E-01 1.05E-01 2.1

Pollutant (lb) ID IL IN KS KY LA MA MD ME MI M

CO2e 2.43E-01 1.41E+00 2.87E+00 2.23E+00 2.45E+00 1.59E+00 1.39E+00 1.82E+00 2.26E+00 1.65E+00 1.84CO2 2.18E-01 1.33E+00 2.71E+00 2.11E+00 2.34E+00 1.47E+00 1.30E+00 1.71E+00 2.12E+00 1.56E+00 1.74CH4 1.03E-03 2.77E-03 5.93E-03 4.56E-03 3.88E-03 5.02E-03 3.94E-03 4.02E-03 5.43E-03 3.57E-03 3.8N2O 5.43E-06 3.63E-05 6.37E-05 5.96E-05 5.21E-05 3.42E-05 2.38E-05 3.54E-05 4.73E-05 4.07E-05 5.0NOX 2.81E-04 2.46E-03 4.94E-03 3.83E-03 4.71E-03 2.00E-03 2.16E-03 3.10E-03 3.91E-03 2.80E-03 3.1SOX 1.92E-03 4.76E-03 1.49E-02 6.24E-03 1.34E-02 9.05E-03 9.18E-03 1.11E-02 1.42E-02 6.74E-03 5.2CO 1.53E-04 4.85E-04 9.42E-04 9.19E-04 7.25E-04 9.84E-04 1.91E-03 1.19E-03 1.46E-03 6.38E-04 6.6TNMOC 8.67E-05 4.33E-05 8.08E-05 6.26E-05 5.95E-05 1.05E-04 1.14E-04 7.74E-05 3.51E-04 8.03E-05 8.2Lead 4.30E-09 1.36E-07 2.21E-07 2.26E-07 1.98E-07 9.63E-08 6.56E-08 1.16E-07 1.33E-07 1.43E-07 1.8Mercury 1.09E-09 2.79E-08 4.48E-08 4.88E-08 4.13E-08 2.40E-08 4.15E-08 3.56E-08 3.98E-08 3.02E-08 3.8PM10 1.80E-05 7.54E-05 1.38E-04 1.26E-04 1.08E-04 1.01E-04 8.89E-05 9.25E-05 1.31E-04 8.91E-05 1.0Solid Waste 7.33E-03 2.09E-01 3.42E-01 3.45E-01 3.03E-01 1.31E-01 7.80E-02 1.69E-01 1.95E-01 2.20E-01 2.8

27 

This report is available at no cost from the National Renewable Energy Laboratory (NREL) at www.nrel.gov/p
Table B-10 (page 2) Total Emission Factors for Delivered Electricity by State (lb of pollutant per kWh of 

Pollutant (lb) MT NC ND NE NH NJ NM NV NY OH O

CO2e 1.99E+00 1.47E+00 2.68E+00 1.81E+00 8.60E-01 9.31E-01 2.43E+00 1.88E+00 1.03E+00 2.20E+00 2.08CO2 1.87E+00 1.41E+00 2.61E+00 1.71E+00 8.05E-01 8.61E-01 2.29E+00 1.76E+00 9.61E-01 2.10E+00 1.93CH4 4.17E-03 2.37E-03 2.41E-03 3.70E-03 2.19E-03 2.79E-03 5.38E-03 4.81E-03 2.59E-03 3.71E-03 5.6N2O 5.29E-05 3.11E-05 5.92E-05 4.94E-05 1.53E-05 1.76E-05 6.50E-05 3.75E-05 1.68E-05 4.73E-05 5.0NOX 3.33E-03 2.83E-03 3.71E-03 3.09E-03 1.44E-03 1.32E-03 4.00E-03 2.89E-03 1.72E-03 4.14E-03 3.0SOX 5.88E-03 8.26E-03 1.00E-02 4.79E-03 5.47E-03 6.34E-03 7.30E-03 1.21E-02 6.23E-03 1.19E-02 8.8CO 7.40E-04 4.31E-04 1.07E-03 6.09E-04 1.13E-03 6.69E-04 8.66E-04 7.39E-04 1.75E-03 6.38E-04 8.6TNMOC 6.02E-05 5.25E-05 5.34E-05 5.23E-05 8.62E-05 6.92E-05 7.27E-05 6.23E-05 6.38E-05 5.41E-05 8.0Lead 1.99E-07 1.16E-07 4.23E-07 1.87E-07 4.57E-08 4.27E-08 2.37E-07 1.09E-07 5.59E-08 1.76E-07 1.6Mercury 4.08E-08 2.40E-08 7.52E-08 3.73E-08 2.60E-08 1.44E-08 4.75E-08 2.27E-08 3.99E-08 3.59E-08 3.2PM10 1.14E-04 6.55E-05 3.03E-04 1.01E-04 5.47E-05 5.14E-05 1.36E-04 8.97E-05 6.87E-05 9.87E-05 1.1Solid Waste 3.01E-01 1.78E-01 3.33E-01 2.88E-01 5.65E-02 6.23E-02 3.65E-01 1.68E-01 6.18E-02 2.71E-01 2.4

Pollutant (lb) RI SC SD TN TX UT VA VT WA WI W

CO2e 1.18E+00 1.00E+00 1.45E+00 1.46E+00 1.99E+00 2.62E+00 1.40E+00 1.88E-02 4.11E-01 2.03E+00 2.4CO2 1.04E+00 9.57E-01 1.36E+00 1.40E+00 1.85E+00 2.51E+00 1.33E+00 1.78E-02 3.82E-01 1.92E+00 2.3CH4 5.65E-03 1.72E-03 3.02E-03 2.43E-03 5.80E-03 4.21E-03 2.52E-03 2.25E-05 1.13E-03 4.13E-03 3.8N2O 2.04E-05 2.12E-05 3.91E-05 3.28E-05 4.37E-05 5.53E-05 2.81E-05 1.70E-06 1.05E-05 5.32E-05 5.0NOX 7.91E-04 1.90E-03 2.45E-03 2.77E-03 2.42E-03 5.00E-03 2.67E-03 1.38E-04 6.13E-04 3.51E-03 4.6SOX 9.90E-03 5.73E-03 3.97E-03 7.32E-03 1.05E-02 1.47E-02 8.04E-03 1.13E-04 1.70E-03 6.60E-03 1.3CO 8.52E-04 3.22E-04 5.26E-04 4.14E-04 9.77E-04 6.89E-04 9.74E-04 5.90E-05 1.80E-04 7.13E-04 6.5TNMOC 9.92E-05 4.89E-05 4.12E-05 4.17E-05 8.22E-05 5.78E-05 8.77E-05 1.02E-04 3.74E-05 8.26E-05 5.2Lead 6.87E-09 7.66E-08 1.47E-07 1.24E-07 1.49E-07 2.08E-07 1.02E-07 6.33E-10 3.21E-08 1.97E-07 1.9Mercury 4.09E-09 1.62E-08 3.01E-08 2.50E-08 2.96E-08 4.15E-08 3.24E-08 1.03E-09 6.62E-09 4.01E-08 3.8PM10 7.02E-05 4.61E-05 8.12E-05 6.75E-05 1.37E-04 1.14E-04 7.25E-05 7.67E-06 2.46E-05 1.11E-04 1.0Solid Waste 1.31E-02 1.17E-01 2.26E-01 1.91E-01 1.82E-01 3.20E-01 1.47E-01 2.83E-04 4.96E-02 3.03E-01 2.9

28 

This report is available at no cost from the National Renewable Energy Laboratory (NREL) at www.nrel.gov/p
Table B-11 Total Emission Factors for Delivered Electricity by State (kg of pollutant per kWh of ele

Pollutant (kg) AK AL AR AZ CA CO CT DC DE FL G

CO2e 7.74E-01 7.17E-01 7.13E-01 7.57E-01 3.51E-01 1.01E+00 3.31E-01 1.93E+00 1.10E+00 6.78E-01 7.3CO2 7.05E-01 6.79E-01 6.71E-01 7.10E-01 3.12E-01 9.52E-01 3.06E-01 1.86E+00 1.03E+00 6.35E-01 6.9CH4 2.85E-03 1.46E-03 1.57E-03 1.82E-03 1.63E-03 2.25E-03 9.72E-04 2.84E-03 2.69E-03 1.70E-03 1.3N2O 1.38E-05 1.61E-05 1.88E-05 1.68E-05 6.32E-06 2.43E-05 6.73E-06 1.31E-05 2.07E-05 1.19E-05 1.7NOX 8.83E-04 1.26E-03 1.20E-03 1.20E-03 2.67E-04 1.67E-03 4.97E-04 4.51E-03 1.78E-03 1.12E-03 1.3SOX 5.09E-03 3.74E-03 2.33E-03 4.02E-03 2.91E-03 4.37E-03 1.92E-03 9.74E-03 6.95E-03 4.28E-03 3.5CO 9.31E-04 2.42E-04 2.92E-04 2.79E-04 2.43E-04 3.53E-04 3.58E-04 8.91E-03 8.38E-04 8.19E-04 2.3TNMOC 3.81E-05 3.71E-05 4.30E-05 2.42E-05 4.03E-05 3.05E-05 3.95E-05 5.81E-05 3.60E-05 4.03E-05 3.4Lead 2.86E-08 5.53E-08 6.73E-08 5.38E-08 3.15E-09 8.46E-08 1.82E-08 1.23E-07 6.44E-08 3.73E-08 6.2Mercury 1.72E-08 1.13E-08 1.43E-08 1.09E-08 1.30E-09 1.70E-08 8.19E-09 2.01E-07 2.23E-08 1.95E-08 1.2PM10 4.94E-05 3.55E-05 4.11E-05 3.79E-05 2.14E-05 5.24E-05 2.17E-05 1.93E-04 5.75E-05 4.04E-05 3.6Solid Waste 3.58E-02 8.53E-02 1.03E-01 8.34E-02 5.67E-03 1.31E-01 2.45E-02 3.21E-02 9.21E-02 4.75E-02 9.5

Pollutant (kg) ID IL IN KS KY LA MA MD ME MI M

CO2e 1.10E-01 6.38E-01 1.30E+00 1.01E+00 1.11E+00 7.23E-01 6.32E-01 8.24E-01 1.02E+00 7.49E-01 8.3CO2 9.89E-02 6.04E-01 1.23E+00 9.55E-01 1.06E+00 6.66E-01 5.88E-01 7.77E-01 9.60E-01 7.06E-01 7.8CH4 4.67E-04 1.26E-03 2.69E-03 2.07E-03 1.76E-03 2.28E-03 1.79E-03 1.82E-03 2.46E-03 1.62E-03 1.7N2O 2.46E-06 1.65E-05 2.89E-05 2.71E-05 2.36E-05 1.55E-05 1.08E-05 1.60E-05 2.14E-05 1.85E-05 2.2NOX 1.27E-04 1.12E-03 2.24E-03 1.74E-03 2.14E-03 9.06E-04 9.79E-04 1.41E-03 1.77E-03 1.27E-03 1.4SOX 8.69E-04 2.16E-03 6.74E-03 2.83E-03 6.08E-03 4.10E-03 4.17E-03 5.04E-03 6.46E-03 3.06E-03 2.3CO 6.95E-05 2.20E-04 4.27E-04 4.17E-04 3.29E-04 4.46E-04 8.67E-04 5.40E-04 6.61E-04 2.89E-04 3.0TNMOC 3.93E-05 1.96E-05 3.67E-05 2.84E-05 2.70E-05 4.75E-05 5.16E-05 3.51E-05 1.59E-04 3.64E-05 3.7Lead 1.95E-09 6.18E-08 1.00E-07 1.03E-07 8.97E-08 4.37E-08 2.97E-08 5.27E-08 6.01E-08 6.50E-08 8.4Mercury 4.93E-10 1.27E-08 2.03E-08 2.21E-08 1.87E-08 1.09E-08 1.88E-08 1.61E-08 1.81E-08 1.37E-08 1.7PM10 8.18E-06 3.42E-05 6.26E-05 5.70E-05 4.91E-05 4.57E-05 4.03E-05 4.19E-05 5.94E-05 4.04E-05 4.7Solid Waste 3.33E-03 9.49E-02 1.55E-01 1.56E-01 1.37E-01 5.92E-02 3.54E-02 7.68E-02 8.84E-02 9.98E-02 1.3

29 

This report is available at no cost from the National Renewable Energy Laboratory (NREL) at www.nrel.gov/p
Table B-11 (page 2) Total Emission Factors for Delivered Electricity by State (kg of pollutant per kWh o

Pollutant (kg) MT NC ND NE NH NJ NM NV NY OH O

CO2e 9.01E-01 6.67E-01 1.22E+00 8.20E-01 3.90E-01 4.22E-01 1.10E+00 8.54E-01 4.65E-01 9.98E-01 9.4CO2 8.50E-01 6.38E-01 1.18E+00 7.75E-01 3.65E-01 3.91E-01 1.04E+00 7.99E-01 4.36E-01 9.53E-01 8.7CH4 1.89E-03 1.08E-03 1.09E-03 1.68E-03 9.96E-04 1.27E-03 2.44E-03 2.18E-03 1.18E-03 1.68E-03 2.5N2O 2.40E-05 1.41E-05 2.69E-05 2.24E-05 6.94E-06 8.00E-06 2.95E-05 1.70E-05 7.62E-06 2.15E-05 2.3NOX 1.51E-03 1.28E-03 1.68E-03 1.40E-03 6.53E-04 5.97E-04 1.81E-03 1.31E-03 7.81E-04 1.88E-03 1.3SOX 2.67E-03 3.75E-03 4.54E-03 2.17E-03 2.48E-03 2.88E-03 3.31E-03 5.50E-03 2.82E-03 5.41E-03 4.0CO 3.36E-04 1.95E-04 4.84E-04 2.76E-04 5.11E-04 3.04E-04 3.93E-04 3.35E-04 7.93E-04 2.89E-04 3.9TNMOC 2.73E-05 2.38E-05 2.42E-05 2.37E-05 3.91E-05 3.14E-05 3.30E-05 2.83E-05 2.89E-05 2.46E-05 3.6Lead 9.03E-08 5.26E-08 1.92E-07 8.47E-08 2.07E-08 1.94E-08 1.07E-07 4.92E-08 2.53E-08 7.99E-08 7.2Mercury 1.85E-08 1.09E-08 3.41E-08 1.69E-08 1.18E-08 6.53E-09 2.15E-08 1.03E-08 1.81E-08 1.63E-08 1.4PM10 5.15E-05 2.97E-05 1.38E-04 4.59E-05 2.48E-05 2.33E-05 6.18E-05 4.07E-05 3.11E-05 4.48E-05 5.2Solid Waste 1.37E-01 8.06E-02 1.51E-01 1.30E-01 2.56E-02 2.83E-02 1.66E-01 7.64E-02 2.80E-02 1.23E-01 1.1

Pollutant (kg) RI SC SD TN TX UT VA VT WA WI W

CO2e 5.34E-01 4.55E-01 6.56E-01 6.64E-01 9.04E-01 1.19E+00 6.35E-01 8.53E-03 1.87E-01 9.19E-01 1.09CO2 4.72E-01 4.34E-01 6.19E-01 6.34E-01 8.37E-01 1.14E+00 6.05E-01 8.07E-03 1.73E-01 8.69E-01 1.05CH4 2.56E-03 7.81E-04 1.37E-03 1.10E-03 2.63E-03 1.91E-03 1.14E-03 1.02E-05 5.12E-04 1.87E-03 1.7N2O 9.23E-06 9.64E-06 1.78E-05 1.49E-05 1.98E-05 2.51E-05 1.27E-05 7.70E-07 4.75E-06 2.41E-05 2.3NOX 3.59E-04 8.62E-04 1.11E-03 1.25E-03 1.10E-03 2.27E-03 1.21E-03 6.27E-05 2.78E-04 1.59E-03 2.1SOX 4.49E-03 2.60E-03 1.80E-03 3.32E-03 4.77E-03 6.67E-03 3.65E-03 5.14E-05 7.73E-04 2.99E-03 6.1CO 3.86E-04 1.46E-04 2.39E-04 1.88E-04 4.43E-04 3.13E-04 4.42E-04 2.68E-05 8.16E-05 3.23E-04 2.9TNMOC 4.50E-05 2.22E-05 1.87E-05 1.89E-05 3.73E-05 2.62E-05 3.98E-05 4.62E-05 1.70E-05 3.74E-05 2.3Lead 3.12E-09 3.48E-08 6.67E-08 5.62E-08 6.76E-08 9.42E-08 4.63E-08 2.87E-10 1.45E-08 8.93E-08 8.7Mercury 1.85E-09 7.36E-09 1.36E-08 1.14E-08 1.34E-08 1.88E-08 1.47E-08 4.66E-10 3.00E-09 1.82E-08 1.7PM10 3.18E-05 2.09E-05 3.69E-05 3.06E-05 6.19E-05 5.15E-05 3.29E-05 3.48E-06 1.12E-05 5.05E-05 4.7Solid Waste 5.92E-03 5.32E-02 1.02E-01 8.64E-02 8.25E-02 1.45E-01 6.67E-02 1.28E-04 2.25E-02 1.37E-01 1.3

30 

This report is available at no cost from the National Renewable Energy Laboratory (NREL) at www.nrel.gov/p
Table B-12 Ozone Season NOX Emissions by State for 2004 

(mass of NOX per kWh of delivered electricity without precombustion emissions) 

AK AL AR AZ CA CO CT DC DE FL GA HI IA ID 

lb/kWh 4.69E-3 2.54E-3 2.73E-3 2.66E-3 4.35E-4 3.19E-3 1.41E-3 5.59E-3 3.05E-3 2.90E-3 1.69E-3 4.86E-3 4.61E-3 1.15Ekg/kWh 2.13E-3 1.15E-3 1.24E-3 1.21E-3 1.97E-4 1.45E-3 6.38E-4 2.54E-3 1.39E-3 1.31E-3 7.66E-4 2.21E-3 2.09E-3 5.22E

KY LA MA MD ME MI MN MO MS MT NC ND NE NH 

lb/kWh 2.24E-3 2.38E-3 1.44E-3 2.76E-3 9.82E-4 2.82E-3 5.09E-3 2.75E-3 4.27E-3 5.59E-3 2.28E-3 5.60E-3 4.69E-3 1.74Ekg/kWh 1.01E-3 1.08E-3 6.55E-4 1.25E-3 4.45E-4 1.28E-3 2.31E-3 1.25E-3 1.94E-3 2.54E-3 1.03E-3 2.54E-3 2.13E-3 7.89E

NY OH OK OR PA RI SC SD TN TX UT VA VT WA 

lb/kWh 2.62E-3 2.91E-3 4.93E-4 2.07E-3 3.27E-4 2.52E-3 4.18E-3 2.07E-3 1.43E-3 4.14E-3 2.69E-3 6.83E-4 4.76E-4 3.69Ekg/kWh 1.19E-3 1.32E-3 2.24E-4 9.38E-4 1.48E-4 1.14E-3 1.90E-3 9.37E-4 6.48E-4 1.88E-3 1.22E-3 3.10E-4 2.16E-4 1.67E

31 

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Source Energy and Emission Factors for Energy Use in Buildings 

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Standard Form 298 (Rev. 8/98) 

Prescribed by ANSI Std. Z39.18

This report is available at no cost from the National Renewable Energy Laboratory (NREL) at www.nrel.gov/publications