USEFUL WEB SITES 

GOVERNMENT LINKS

U.S. DEPARTMENT OF AGRICULTURE www.usda.gov 

 Agricultural Research Service www.ars.usda.gov 

 Forest Service www.fs.fed.us 

 National Agricultural Library www.nal.usda.gov 

 National Agricultural Statistics Service www.nass.usda.gov 

U.S. DEPARTMENT OF ENERGY www.energy.gov 

 Energy Efficiency and Renewable Energy www.eere.energy.gov 

 Biomass Program www.eere.energy.gov/biomass 

 Alternative Fuels Data Center www.afdc.nrel.gov 

 Clean Cities www.ccities.doe.gov 

 Fuel Economy www.fueleconomy.gov 

 Biomass Energy Data Book cta.ornl.gov/bedb 

 Buildings Energy Data Book www.btscoredatabook.net 

 Power Technologies Data Book www.nrel.gov/analysis/power_databook 

 Transportation Energy Data Book cta.ornl.gov/data 

 Energy Information Administration www.eia.doe.gov 

OAK RIDGE NATIONAL LABORATORY www.ornl.gov 

 Center for Transportation Analysis cta.ornl.gov 

FIRSTGOV www.firstgov.gov 

FEDERAL GOVERNMENT – FEDSTATS www.fedstats.gov 

U.S. BUREAU OF LABOR STATISTICS www.bls.gov 

U.S. CENSUS BUREAU www.census.gov 

U.S. DEPARTMENT OF COMMERCE www.commerce.gov 

 Bureau of Economic Analysis www.bea.gov 

U.S. ENVIRONMENTAL PROTECTION AGENCY www.epa.gov 

NON GOVERNMENT LINKS

American Corn Growers Association www.acga.org 

American Soybean Association soygrowers.com 

National Biodiesel Board www.biodiesel.org 

National Oilseed Processors Association www.nopa.org 

National Ethanol Vehicle Coalition www.e85fuel.com 

Pellet Fuels Institute pelletheat.org 

Renewable Fuels Association www.ethanolrfa.org 
ORNL/TM-2006/571 

BIOMASS ENERGY DATA BOOK: 

EDITION 1

Lynn Wright 

Consultant 

Oak Ridge, Tennessee 

Bob Boundy 

Roltek 

Clinton, Tennessee 

Bob Perlack 

Stacy Davis 

Bo Saulsbury 

Oak Ridge National Laboratory 

Oak Ridge, Tennessee 

September 2006 

Prepared for the 

Office of Planning, Budget and Analysis 

Energy Efficiency and Renewable Energy 

U.S. Department of Energy 

Prepared by the 

Oak Ridge National Laboratory 

Oak Ridge, Tennessee 37831-6073 

managed by 

UT-BATTELLE, LLC 

for the 

U.S. DEPARTMENT OF ENERGY 

under Contract No. DE-AC05-00OR22725 
 

DOCUMENT AVAILABILITY 

Reports produced after January 1, 1996, are generally available free via the U.S. 

Department of Energy (DOE) Information Bridge: 

Web site: http://www.osti.gov/bridge

Reports produced before January 1, 1996, may be purchased by members of the public 

from the following source: 

National Technical Information Service 

5285 Port Royal Road 

Springfield, VA 22161 

Telephone: 703-605-6000 (1-800-553-6847) 

TDD: 703-487-4639 

Fax: 703-605-6900 

E-mail: info@ntis.fedworld.gov 

Web site: http://www.ntis.gov/support/ordernowabout.htm

Reports are available to DOE employees, DOE contractors, Energy Technology Data 

Exchange (ETDE) representatives, and International Nuclear Information System (INIS) 

representatives from the following source: 

Office of Scientific and Technical Information 

P.O. Box 62 

Oak Ridge, TN 37831 

Telephone: 865-576-8401 

Fax: 865-576-5728 

E-mail: reports@adonis.osti.gov

Web site: http://www.osti.gov/contact.html

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 warranty, express or implied, or 

assumes any legal liability or responsibility for the accuracy, completeness, or 

usefulness of any information, apparatus, product, or process disclosed, or 

represents that its use would not infringe privately owned rights. Reference herein 

to any specific commercial product, process, or service by trade name, trademark, 

manufacturer, or otherwise, does not necessarily constitute or imply its 

endorsement, recommendation, or favoring by the United States Government or 

any agency thereof. The views and opinions of authors expressed herein do not 

necessarily state or reflect those of the United States Government or any agency 

thereof. 
Users of the Biomass Energy Data Book are encouraged to comment on errors, omissions, emphases, 

and organization of this report to one of the persons listed below. Information on an existing table should 

be referred to Ms. Stacy Davis, Oak Ridge National Laboratory. 

Stacy C. Davis 

Oak Ridge National Laboratory 

National Transportation Research Center 

2360 Cherahala Boulevard 

Knoxville, Tennessee 37932 

Telephone: (865) 946-1256 

FAX: (865) 946-1314 

E-mail: DAVISSC@ornl.gov

Web Site Location: cta.ornl.gov

Tien Nguyen

Office of Planning, Budget and Analysis 

Department of Energy, EE-3B 

Forrestal Building, Room 5F-034 

1000 Independence Avenue, S.W. 

Washington, D.C. 20585 

Telephone: (202) 586-7387 

FAX: (202) 586-1637 

E-mail: Tien.Nguyen@EE.DOE.GOV

Web Site Location: 

http://www.eere.energy.gov/vehiclesandfuels/

The Biomass Energy Data Book 

can be found on the web at: 

cta.ornl.gov/bedb

 vii

Biomass Energy Data Book: Edition 1 

TABLE OF CONTENTS 

ACKNOWLEDGEMENTS ...........................................................................................................................xv 

ACRONYMS..............................................................................................................................................xvii 

PREFACE...................................................................................................................................................xix 

ABSTRACT ................................................................................................................................................xxi 

1. INTRODUCTION TO BIOMASS.............................................................................................................1

Overview of Historic/Current Biomass Consumption by Source and Sector 

 Biomass Overview 

 Table 1.1 Energy Production by Source, 1973—2005........................................................................2 

 

 Table 1.2 Energy Consumption by Source, 1973—2005....................................................................3 

 Table 1.3 Renewable Energy Consumption by Source, 1973—2005.................................................4 

 Table 1.4 Estimated Renewable Energy Consumption for Industrial and Transportation 

 Sectors, 1973—2005...........................................................................................................5 

 Table 1.5 Estimated Renewable Energy Consumption for Residential and Commercial 

 Sectors, 1973—2005...........................................................................................................6 

 Figure 1.1 Summary of Biomass Energy Consumption, 2005 .............................................................7 

Overview of Biomass Resources 

 Table 1.6 Industrial Biomass Energy Consumption and Electricity Net Generation by Industry 

 and Energy Sources, 2003..................................................................................................8

 Table 1.7 Total Residue Produced on Agricultural Lands, 2001.........................................................9 

Figure 1.2 Major Uses of Land in the United States, 2002.................................................................10 

 Figure 1.3 Geographic Locations of Major Crops, 2004.....................................................................12 

 Future Energy Crop Supply Potential—Cellulosic Biomass 

2. BIOFUELS ............................................................................................................................................17 

Brief Overview 

Taxes and Incentives 

 Table 2.1 Major Federal Biofuel Tax Incentives ................................................................................18 

 Table 2.2 Selected Non-Tax Federal Biofuel Incentives ...................................................................19 

 
viii 

Biomass Energy Data Book: Edition 1 

Ethanol Overview 

 

Table 2.3 Specifications Contained in ASTM D 4806 Standard Specification for Denatured 

 Fuel Ethanol for Blending with Gasoline ...........................................................................21 

 Table 2.4 Fuel Property Comparison for Ethanol, Gasoline and No. 2 Diesel..................................22 

 Ethanol Production 

 Table 2.5 World Ethanol Production by Country, 2005 .....................................................................23 

 Table 2.6 Fuel Ethanol Imports by Country.......................................................................................24 

 Table 2.7 Historic Fuel Ethanol Production .......................................................................................25 

 Table 2.8 Ethanol Production Statistics, 1999—2006.......................................................................26 

 Table 2.9 Ethanol Production by Feedstock, 2006............................................................................27 

 Table 2.10 Ethanol Production by Plant Energy Source, 2006 ...........................................................28 

 Figure 2.1 Ethanol Production Facilities Current and Planned, 2005.................................................29 

Figure 2.2 The Ethanol Production Process – Wet Milling .................................................................30 

 Figure 2.3 The Ethanol Production Process – Dry Milling..................................................................31 

 Figure 2.4 The Production of Ethanol from Cellulosic Biomass .........................................................32 

 Ethanol Consumption 

 Table 2.11 Ethanol-Blended Fuel Use by State, 2004 ........................................................................34 

 Economics 

 Table 2.12 Gasoline and Ethanol: Comparison of Current and Potential Production Costs 

 in North America................................................................................................................35 

 Table 2.13 Undenatured Ethanol Cash Operating Expenses and Net Feedstock Costs for 

 Dry-milling Process by Plant Size, 2002 ...........................................................................36 

 Table 2.14 Economic Contribution of the Ethanol Industry, 2004 .......................................................37 

Figure 2.5 Ethanol Net Energy Balances and Greenhouse Gas Emissions ......................................38 

 Figure 2.6 Comparisons of Energy Inputs and GHG Emissions for Three Ethanol Scenarios 

 and Gasoline .....................................................................................................................39

Figure 2.7 Comparative Results between Ethanol and Gasoline Based on an Evaluation by the 

 GREET Model ...................................................................................................................40 

 Table 2.15 Comparison of Ethanol Energy Balance with and Without Inclusion of Coproduct 

 Energy Credits...................................................................................................................43 

 Table 2.16 State Ethanol Incentives, 2005..........................................................................................44 
 ix

Biomass Energy Data Book: Edition 1 

Biodiesel 

 Brief Overview 

 Biodiesel Production 

 Table 2.17 World Biodiesel Capacity, 2002 ........................................................................................46 

 Table 2.18 Active Biodiesel Production Facilities, 2005......................................................................47 

 Table 2.19 Proposed Biodiesel Production Facilities, 2005 ................................................................48 

Figure 2.8 Active and Proposed Biodiesel Production Facilities, 2005 ..............................................49 

 Figure 2.9 Estimated U.S. Biodiesel Production, 1999—2005...........................................................50

 Table 2.20 Composition of Various Oils and Fats Used for Biodiesel.................................................51 

Figure 2.10 Typical Proportions of Chemicals Used to Make Biodiesel...............................................52 

 Table 2.21 Specification for Biodiesel (B100) .....................................................................................53 

 

 Figure 2.11 Commercial Biodiesel Production Methods.......................................................................54 

Biodiesel Consumption 

 Table 2.22 Average Biodiesel (B100 and B20) Emissions Compared to Conventional Diesel...........55 

Economics 

 Table 2.23 Estimated Impacts from Increased Use of Biodiesel.........................................................56 

BioOil Overview 

 Figure 2.12 A Fast Pyrolysis Process for Making BioOil ......................................................................58

 Table 2.24 BioOil Characteristics ........................................................................................................59 

 Table 2.25 BioOil Composition ............................................................................................................60 

 Table 2.26 BioOil Fuel Comparisons...................................................................................................61 

3. BIOPOWER ..........................................................................................................................................63 

 Brief Overview

 Table 3.1 Biomass Power Technology in Commercial/Demonstration Phase 

 during 2000—2006 ............................................................................................................64 

 Table 3.2 Biomass Power Technology Fuel Specifications and Capacity Range.............................65 

 Table 3.3 New Renewable Capacity Supplying Green Power Markets, 2004 ..................................66 

 Table 3.4 New Renewable Capacity Supported through Utility Green Pricing Programs, 2004.......67 

 Table 3.5 Utility Green Pricing Programs Using Biomass and Biomass Based Resources .............68 

 
x 

Biomass Energy Data Book: Edition 1 

Table 3.6 Competitive Electricity Markets Retail Green Power Product Offerings, 

 October 2005.....................................................................................................................70 

 Table 3.7 Renewable Energy Certificate Product Offerings, October 2005......................................72 

 Table 3.8 Current Biomass Power Plants .........................................................................................73 

 Table 3.9 Current Landfill Gas Power Plants ....................................................................................75 

 Table 3.10 Total Net Generation of Electricity by State from Wood and Wood Waste, 2002.............78 

 Table 3.11 Net Generation and Fuel Consumption at Power Plants Consuming Coal and 

 Biomass by State and Plant Name, 2003..........................................................................79 

 Fossil Fuel Displacement by Biopower 

 Table 3.12 Coal Displacement Calculation, 2006 ...............................................................................81 

 Table 3.13 Renewable Energy Impacts Calculation, 2006..................................................................82 

 Table 3.14 Number of Home Electricity Needs Met Calculation, 2006 ...............................................83 

Biopower Regulations, Incentives and Taxes 

 Table 3.15 Major Federal Biomass Power Incentives .........................................................................84 

Figure 3.1 States with Renewable Portfolio Standard........................................................................85 

 Table 3.16 State Renewable Portfolio Standards and Purchase Requirements ................................86 

 Table 3.17 State Renewable Energy Goals (Nonbinding)...................................................................89 

4. BIOREFINERIES ..................................................................................................................................91 

 Brief Overview 

 Table 4.1 Biorefinery Platforms .........................................................................................................92 

 Table 4.2 U.S. Department of Energy Sugar Platform Biorefinery Projects......................................93 

5. FEEDSTOCKS......................................................................................................................................95 

 Primary Biomass Feedstocks 

 Grains 

 Table 5.1 Corn Baseline Projections, 2004—2015 ...........................................................................96 

Figure 5.1 Corn Used for Ethanol Production, 1985—2005...............................................................97 

 Figure 5.2 Corn Usage by Segment, 2005 .........................................................................................98

 Table 5.2 Corn: Area, Yield, Production, and Value, 1996—2005....................................................99 

 Table 5.3 Corn: Area, Yield, and Production, by State, 2003—2005..............................................100 

Figure 5.3 Corn for Grain, Harvested Acres, 2002 ...........................................................................101 
 xi

Biomass Energy Data Book: Edition 1 

 Figure 5.4 Corn Acres, Planted and Harvested, 1984—2005 ..........................................................102 

 Figure 5.5 Corn Yield, 1975—2005 ..................................................................................................103

 Table 5.4 Corn: Supply and Disappearance, 1996—2005..............................................................105 

 Table 5.5 Corn for Grain: Marketing Year Average Price and Value, by State...............................106 

 Table 5.6 Corn Production Costs and Returns per Planted Acre, Excluding Government 

 Payments, 2002—2003...................................................................................................107 

 Table 5.7 Corn Production Costs and Returns per Planted Acre, Excluding Government 

 Payments, 1996—2003...................................................................................................109 

Figure 5.6 Sorghum for Grain, Harvested Acres, 2002 ....................................................................110 

 Table 5.8 Sorghum: Area, Yield, Production, and Value, 1996—2005 ..........................................111 

 Table 5.9 Sorghum: Area, Yield, and Production, by State, 2003—2005......................................112 

 Table 5.10 Sorghum: Supply and Disappearance, 1996—2005......................................................113 

 Table 5.11 Sorghum Production Costs and Returns per Planted Acre, Excluding Government 

 Payments, 2002—2003...................................................................................................114 

 Table 5.12 Sorghum Production Costs and Returns per Planted Acre, Excluding 

 Government Payments, 1995—2003 ..............................................................................115 

 Oilseeds 

 Table 5.13 Soybeans and Products Baseline, 2004—2015..............................................................116 

 Table 5.14 Soybeans: Area, Yield, Production, and Value, 1996—2005.........................................117 

 Table 5.15 Soybeans: Supply and Disappearance, 1995—2004 ....................................................118 

 Table 5.16 Soybeans: Area, Yield, and Production, by State, 2003—2005.....................................119 

Figure 5.7 Soybeans for Beans, Harvested Acres, 2002 .................................................................120 

 Table 5.17 Soybean Production Costs and Returns per Planted Acre, Excluding Government 

 Payments, 2002—2003...................................................................................................121 

 Secondary Biomass Feedstocks 

 Mill Wastes 

 Table 5.18 Residues from Primary Forest Product Mills...................................................................124 

 Figure 5.8 Unused Mill Residues by County ....................................................................................125 

 Pellet Fuels 

 Table 5.19 Pellet Fuel Shipments from Pellet Fuel Manufacturers ...................................................126 

 Table 5.20 Pellet Appliance Shipments from Manufacturers ............................................................126 
xii 

Biomass Energy Data Book: Edition 1 

Tertiary Biomass Feedstocks 

 Urban Residues 

Figure 5.9 Total Construction and Demolition Residues ..................................................................128 

 Table 5.21 Residues from Construction and Demolition by State.....................................................129 

 Figure 5.10 Total Municipal Solid Waste Wood Residues..................................................................130 

 Table 5.22 Residues from Municipal Solid Waste Landfills by State ................................................131 

Landfill Gas 

 Table 5.23 Landfill Gas Projects and Candidate Landfills by State, January 2006 ..........................132 

 Feedstock Characteristics 

APPENDIX A: CONVERSIONS...............................................................................................................133 

APPENDIX B: BIOMASS CHARACTERISTICS.....................................................................................145 

APPENDIX C: ASSUMPTIONS...............................................................................................................151 

GLOSSARY...............................................................................................................................................155 
 xiii

Biomass Energy Data Book: Edition 1 

ACKNOWLEDGEMENTS 

 

The authors would like to express their gratitude to the many individuals who assisted in the preparation 

of this document. First, we would like to thank the U.S. Department of Energy’s Energy Efficiency and 

Renewable Energy (EERE) staff in the Office of Planning, Budget and Analysis, and the Biomass 

Program for their support of the first edition of the Biomass Energy Data Book project. Our team of 

thorough reviewers include Tien Nguyen and Phil Patterson of the EERE Office of Planning, Budget and 

Analysis, Zia Haq of the EERE Biomass Program, and David Andress of David Andress and Associates. 

 We would like to thank Alex Farrell of the University of California, Berkeley, for allowing us to publish 

material from his article in Science. We would also like to thank Jamie Payne of Oak Ridge National 

Laboratory (ORNL), who designed the cover. Finally, this book would not have been possible without the 

dedication of Debbie Bain (ORNL), who masterfully prepared the manuscript. 
xiv 

Biomass Energy Data Book: Edition 1 
 xv

Biomass Energy Data Book: Edition 1 

ACRONYMS 

AEO Annual Energy Outlook 

ASABE American Society of Agricultural and Biological Engineers

Btu British thermal units 

CO2 Carbon dioxide 

CRP Conservation Reserve Program 

d.b.h. Diameter at breast height 

DOE Department of Energy 

EERE Office of Energy Efficiency and Renewable Energy 

EIA Energy Information Administration 

EPA Environmental Protection Agency 

EPAct Energy Policy Act 

ERS Economic Research Service 

FTE Fuel Treatment Evaluator 

FY Fiscal Year 

GHG Greenhouse Gas 

GPRA Government Performance Results Act 

GW Gigawatt 

IEA International Energy Agency 

LFG Landfill Gas 

MJ Megajoule 

MMBtu Million British thermal units 

MW Megawatt 

MSW Municipal Solid Waste 

NASS National Agricultural Statistics Service 

NEMS National Energy Modeling System 

NREL National Renewable Energy Laboratory 

NRCS National Resources Conservation Service 

ORNL Oak Ridge National Laboratory 

RPS Renewable Portfolio Standard 

SRIC Short Rotation Intensive Culture 

TBD To Be Determined 

TVA Tennessee Valley Authority 

USDA United States Department of Agriculture 
xvi 

Biomass Energy Data Book: Edition 1 
 xvii

Biomass Energy Data Book: Edition 1 

PREFACE 

The Department of Energy, through the Office of Planning, Budget, and Analysis in the Office of Energy 

Efficiency and Renewable Energy, has contracted with Oak Ridge National Laboratory to prepare this 

Biomass Energy Data Book. The purpose of this data book is to draw together, under one cover, biomass 

data from diverse sources to produce a comprehensive document that supports anyone with an interest 

or stake in the biomass industry. Given the increasing demand for energy, policymakers and analysts 

need to be well-informed about current biomass energy production activity and the potential contribution 

biomass resources and technologies can make toward meeting the nation’s energy demands. This is the 

first edition of the Biomass Energy Data Book and it is currently only available online in electronic format. 

This first edition focuses on biomass conversion technologies and commercially utilized biomass 

resources.

Biomass energy technologies used in the United States include an extremely diverse array of 

technologies - from wood or pellet stoves used in homes to large, sophisticated biorefineries producing 

multiple products. For some types of biomass energy production, there are no annual inventories or 

surveys on which to base statistical data. For some technology areas there are industry advocacy groups 

that track and publish annual statistics on energy production capacity, though not necessarily actual 

production or utilization. The Department of Energy’s Energy Information Administration (EIA) produces 

annual estimates of biomass energy utilization and those estimates are included in this data book. 

Information from industry groups are also provided to give additional detail. An effort has been made to 

identify the best sources of information on capacity, production and utilization of many of the types of 

biomass energy being produced in this country. It is certain, however, that not all biomass energy 

contributions have been identified. The information may not be available, or may be proprietary.

It is even more difficult to track the diverse array of biomass resources being used as feedstocks for 

biomass energy production. Since most of the biomass resources currently being used for energy or 

bioproducts are residuals from industrial, agricultural or forestry activities, there is no way to 

systematically inventory biomass feedstock collection and use and report it in standard units. All biomass 

resource availability and utilization information available in the literature are estimates, not inventories of 

actual collection and utilization. Biomass utilization information is derived from biomass energy production 

data, but relies on assumptions about energy content and conversion efficiencies for each biomass type 

and conversion technology. Biomass availability data relies on understanding how much of a given 

biomass type (e.g., corn grain) is produced, alternate demands for that biomass type, economic 

profitability associated with each of those alternate demands, environmental impacts of collection of the 

biomass, and other factors such as incentives. This book presents some of the information needed for 

deriving those estimates, as well as providing biomass resource estimates that have been estimated by 

either ORNL staff or other scientists. For estimates derived from ORNL analysis, the methodology has 

been documented in Appendix C and additional references have been provided. In all cases it should be 

recognized that estimates are not precise and different assumptions will change the results. 
xviii 

Biomass Energy Data Book: Edition 1 
 xix

Biomass Energy Data Book: Edition 1 

ABSTRACT 

The Biomass Energy Data Book is a statistical compendium prepared and published by Oak Ridge 

National Laboratory (ORNL) under contract with the Office of Planning, Budget, and Analysis in the 

Energy Efficiency and Renewable Energy (EERE) program of the Department of Energy (DOE). Designed 

for use as a convenient reference, the book represents an assembly and display of statistics and 

information that characterize the biomass industry, from the production of biomass feedstocks to their end 

use.

This is the first edition of the Biomass Energy Data Book and is currently only available online in 

electronic format. There are five main sections to this book. The first section is an introduction which 

provides an overview of biomass resources and consumption. Following the introduction to biomass, is a 

section on biofuels which covers ethanol, biodiesel and BioOil. The biopower section focuses on the use 

of biomass for electrical power generation and heating. The fourth section is on the developing area of 

biorefineries, and the fifth section covers feedstocks that are produced and used in the biomass industry. 

The sources used represent the latest available data. There are also three appendices which include 

measures of conversions, biomass characteristics and assumptions for selected tables and figures. A 

glossary of terms and a list of acronyms are also included for the reader’s convenience.
xx 

Biomass Energy Data Book: Edition 1 
 1

Biomass Energy Data Book: Edition 1 

1. INTRODUCTION TO BIOMASS 

BIOMASS OVERVIEW

Biomass is material that comes from plants. Plants use the light energy from the sun to convert water and 

carbon dioxide to sugars that can be stored, through a process called photosynthesis. Some plants, like 

sugar cane and sugar beets, store the energy as simple sugars. These are mostly used for food. Other 

plants store the energy as more complex sugars, called starches. These plants include grains like corn 

and are also used for food. 

Another type of plant matter, called cellulosic biomass, is made up of very complex sugar polymers 

(complex polysaccharides), and is not generally used as a food source. This type of biomass will be the 

future feedstock for bioethanol production. Specific feedstocks being tested include agricultural and 

forestry residues, organic urban wastes, food processing and other industrial wastes, and energy crops. 

For more detailed information on current and future biomass resources in the United States see the 

feedstock section. 

In 2005, biomass production contributed 2.7 quadrillion Btu of energy to the 69.1 quadrillion Btu of energy 

produced in the United States or about 4% of total energy production. Since a substantial portion of U.S. 

energy is imported, the more commonly quoted figure is that biomass contributed 2.7 quadrillion Btu of 

energy to the 99.8 quadrillion Btu of energy consumed in the United States or about 3%. At present, wood 

resources contribute most to the biomass resources consumed in the United States and most of that is 

used in the generation of electricity and industrial process heat and steam. The industrial sector (primarily 

the wood products industry) used about 1.4 quadrillion Btu in 2005. The residential and commercial 

sectors consume .04 quadrillion Btu of biomass; however, this figure may understate consumption in 

these sectors due to unreported consumption, such as home heating by wood collected on private 

property. The use of biomass fuels such as ethanol and biodiesel by the transportation sector is small but 

rising rapidly. 

There are many types of biomass resources currently used and potentially available. This includes 

everything from primary sources of crops and residues harvested/collected directly from the land, to 

secondary sources such as sawmill residuals, to tertiary sources of post-consumer residuals that often 

end up in landfills. Biomass resources also include the gases that result from anaerobic digestion of 

animal manures or organic materials in landfills. The estimated availability of agricultural and forestry 

biomass in 2001 was recently reported in a document entitled “Biomass as Feedstock For a Bioenergy 

and Bioproducts Industry: The Technical Feasibility of a Billion-Ton Annual Supply;” prepared by Oak 

Ridge National Laboratory staff (for the Department of Energy) together with scientists from the U.S. 

Department of Agriculture (USDA), Agricultural Research Service and USDA Forest Service. The ultimate 

limit for the amount of biomass that can be sustainably produced on agricultural land in the United States 

depends on land availability. The areas of the country with adequate rainfall and soil quality for production 

and harvest of energy crops are roughly the same areas where major crops are currently produced in the 

United States. Changes in the way that land is managed will be necessary for increasing biomass 

resource availability in the U.S.

For additional overview information, visit the U.S. Department of Energy, Office of Energy Efficiency and 

Renewable Energy's Biomass Program at: http://www1.eere.energy.gov/biomass/index.html. 
2 

Biomass Energy Data Book: Edition 1 

In 2005 biomass accounted for about 45% of the renewable energy production in the United States. 

Table 1.1 

Energy Production by Source, 1973—2005 

(Quadrillion Btu)

Coal

Natural 

Gas (Dry)

Crude 

Oilb

Natural 

Gas 

Plant 

Liquids Total

Nuclear 

Electric 

Power

Hydroelectric 

Powerc Biomassd

Geothermal Solar Wind Total

1973 13.99 22.19 19.49 2.57 58.24 0.91 2.86 1.53 0.04 NA NA 4.43 63.58

1974 14.07 21.21 18.57 2.47 56.33 1.27 3.18 1.54 0.05 NA NA 4.77 62.37

1975 14.99 19.64 17.73 2.37 54.73 1.90 3.15 1.50 0.07 NA NA 4.72 61.36

1976 15.65 19.48 17.26 2.33 54.72 2.11 2.98 1.71 0.08 NA NA 4.77 61.60

1977 15.75 19.57 17.45 2.33 55.10 2.70 2.33 1.84 0.08 NA NA 4.25 62.05

1978 14.91 19.49 18.43 2.25 55.07 3.02 2.94 2.04 0.06 NA NA 5.04 63.14

1979 17.54 20.08 18.10 2.29 58.01 2.78 2.93 2.15 0.08 NA NA 5.17 65.95

1980 18.60 19.91 18.25 2.25 59.01 2.74 2.90 2.48 0.11 NA NA 5.49 67.24

1981 18.38 19.70 18.15 2.31 58.53 3.01 2.76 2.59 0.12 NA NA 5.47 67.01

1982 18.64 18.32 18.31 2.19 57.46 3.13 3.27 2.62 0.10 NA NA 5.99 66.57

1983 17.25 16.59 18.39 2.18 54.42 3.20 3.53 2.83 0.13 NA 0.00 6.49 64.11

1984 19.72 18.01 18.85 2.27 58.85 3.55 3.39 2.88 0.16 0.00 0.00 6.43 68.83

1985 19.33 16.98 18.99 2.24 57.54 4.08 2.97 2.86 0.20 0.00 0.00 6.03 67.65

1986 19.51 16.54 18.38 2.15 56.58 4.38 3.07 2.84 0.22 0.00 0.00 6.13 67.09

1987 20.14 17.14 17.67 2.22 57.17 4.75 2.63 2.82 0.23 0.00 0.00 5.69 67.61

1988 20.74 17.60 17.28 2.26 57.87 5.59 2.33 2.94 0.22 0.00 0.00 5.49 68.95

1989 21.35 17.85 16.12 2.16 57.47 5.60 2.84 3.06 0.32 0.06 0.02 6.29 69.36

1990 22.46 18.33 15.57 2.17 58.53 6.10 3.05 2.66 0.34 0.06 0.03 6.13 70.77

1991 21.59 18.23 15.70 2.31 57.83 6.42 3.02 2.70 0.35 0.06 0.03 6.16 70.41

1992 21.63 18.38 15.22 2.36 57.59 6.48 2.62 2.85 0.35 0.06 0.03 5.91 69.98

1993 20.25 18.58 14.49 2.41 55.74 6.41 2.89 2.80 0.36 0.07 0.03 6.16 68.30

1994 22.11 19.35 14.10 2.39 57.95 6.69 2.68 2.94 0.34 0.07 0.04 6.06 70.71

1995 22.03 19.08 13.89 2.44 57.44 7.08 3.21 3.07 0.29 0.07 0.03 6.67 71.18

1996 22.68 19.34 13.72 2.53 58.28 7.09 3.59 3.13 0.32 0.07 0.03 7.14 72.50

1997 23.21 19.39 13.66 2.50 58.76 6.60 3.64 3.01 0.32 0.07 0.03 7.08 72.43

1998 23.94 19.61 13.24 2.42 59.20 7.07 3.30 2.83 0.33 0.07 0.03 6.56 72.83

1999 23.19 19.34 12.45 2.53 57.51 7.61 3.27 2.89 0.33 0.07 0.05 6.60 71.71

2000 22.62 19.66 12.36 2.61 57.25 7.86 2.81 2.91 0.32 0.07 0.06 6.16 71.27

2001 23.49 20.20 12.28 2.55 58.52 8.03 2.24 2.64 0.31 0.07 0.07 5.33 71.88

2002 22.62 19.44 12.16 2.56 56.78 8.14 2.69 2.65 0.33 0.06 0.11 5.84 70.76

2003 21.97 19.69 12.03 2.35 56.03 7.96 2.82 2.74 0.34 0.06 0.11 6.08 70.07

2004 22.71 19.26 11.50 2.47 55.95 8.22 2.69 2.88 0.35 0.06 0.14 6.12 70.29

2005 23.15 18.66 10.84 2.32 54.97 8.13 2.71 2.73 0.36 0.06 0.15 6.01 69.11

Fossil Fuels Renewable Energya

Year Total

Source: 

Energy Information Administration, Monthly Energy Review, March 2006. Table 1.2, 

www.eia.doe.gov/emeu/mer/overview.html

Note: NA = Not available. 

_______________________ 

a

 End-use consumption and electricity net generation. 

b

 Includes lease condensate. 

c

 Conventional hydroelectric power. 

d

 Wood, waste, and alcohol fuels (ethanol blended into motor gasoline). 
 3

Biomass Energy Data Book: Edition 1 

Table 1.2 

Energy Consumption by Source, 1973—2005 

(Quadrillion Btu)

Coal

Natural 

Gasb

Petroleumc,d Totale

Nuclear 

Electric 

Power

Hydroelectric 

Powerf Biomassd,g

Geothermal Solar Wind Total

1973 12.97 22.51 34.84 70.32 0.91 2.86 1.53 0.04 NA NA 4.43 75.71

1974 12.66 21.73 33.45 67.91 1.27 3.18 1.54 0.05 NA NA 4.77 73.99

1975 12.66 19.95 32.73 65.35 1.90 3.15 1.50 0.07 NA NA 4.72 72.00

1976 13.58 20.35 35.17 69.10 2.11 2.98 1.71 0.08 NA NA 4.77 76.01

1977 13.92 19.93 37.12 70.99 2.70 2.33 1.84 0.08 NA NA 4.25 78.00

1978 13.77 20.00 37.97 71.86 3.02 2.94 2.04 0.06 NA NA 5.04 79.99

1979 15.04 20.67 37.12 72.89 2.78 2.93 2.15 0.08 NA NA 5.17 80.90

1980 15.42 20.39 34.20 69.98 2.74 2.90 2.48 0.11 NA NA 5.49 78.29

1981 15.91 19.93 31.93 67.75 3.01 2.76 2.59 0.12 NA NA 5.47 76.34

1982 15.32 18.51 30.23 64.04 3.13 3.27 2.62 0.10 NA NA 5.99 73.25

1983 15.89 17.36 30.05 63.29 3.20 3.53 2.83 0.13 NA 0.00 6.49 73.10

1984 17.07 18.51 31.05 66.62 3.55 3.39 2.88 0.16 0.00 0.00 6.43 76.74

1985 17.48 17.83 30.92 66.22 4.08 2.97 2.86 0.20 0.00 0.00 6.03 76.47

1986 17.26 16.71 32.20 66.15 4.38 3.07 2.84 0.22 0.00 0.00 6.13 76.78

1987 18.01 17.74 32.87 68.63 4.75 2.63 2.82 0.23 0.00 0.00 5.69 79.23

1988 18.85 18.55 34.22 71.66 5.59 2.33 2.94 0.22 0.00 0.00 5.49 82.84

1989 19.07 19.71 34.21 73.02 5.60 2.84 3.06 0.32 0.06 0.02 6.29 84.96

1990 19.17 19.73 33.55 72.46 6.10 3.05 2.66 0.34 0.06 0.03 6.13 84.70

1991 18.99 20.15 32.85 72.00 6.42 3.02 2.70 0.35 0.06 0.03 6.16 84.64

1992 19.12 20.84 33.53 73.52 6.48 2.62 2.85 0.35 0.06 0.03 5.91 85.99

1993 19.84 21.35 33.84 75.05 6.41 2.89 2.80 0.36 0.07 0.03 6.16 87.62

1994 19.91 21.84 34.67 76.48 6.69 2.68 2.94 0.34 0.07 0.04 6.06 89.28

1995 20.09 22.78 34.55 77.49 7.08 3.21 3.07 0.29 0.07 0.03 6.67 91.25

1996 21.00 23.20 35.76 79.98 7.09 3.59 3.13 0.32 0.07 0.03 7.14 94.26

1997 21.45 23.33 36.27 81.09 6.60 3.64 3.01 0.32 0.07 0.03 7.08 94.77

1998 21.66 22.94 36.93 81.59 7.07 3.30 2.83 0.33 0.07 0.03 6.56 95.19

1999 21.62 23.01 37.96 82.65 7.61 3.27 2.89 0.33 0.07 0.05 6.60 96.84

2000 22.58 23.92 38.40 84.96 7.86 2.81 2.91 0.32 0.07 0.06 6.16 98.96

2001 21.91 22.91 38.33 83.18 8.03 2.24 2.64 0.31 0.07 0.07 5.33 96.47

2002 21.90 23.63 38.40 83.99 8.14 2.69 2.65 0.33 0.06 0.11 5.84 97.88

2003 22.32 22.97 39.05 84.39 7.96 2.82 2.74 0.34 0.06 0.11 6.08 98.21

2004 22.47 23.04 40.59 86.23 8.22 2.69 2.88 0.35 0.06 0.14 6.12 100.32

2005 22.89 22.57 40.44 85.95 8.13 2.71 2.73 0.36 0.06 0.15 6.01 99.84

Fossil Fuels Renewable Energya

Totald,h Year

Source: 

Energy Information Administration, Monthly Energy Review March 2006. Table 1.3, 

www.eia.doe.gov/emeu/mer/overview.html 

Note: NA = Not available. 

_______________________ 

a

 End-use consumption and electricity net generation. 

b

 Natural gas, plus a small amount of supplemental gaseous fuels that cannot be identified separately. 

c

 Petroleum products supplied, including natural gas plant liquids and crude oil burned as fuel. Beginning in 

1993, also includes ethanol blended into other gasoline. d

 Beginning in 1993, ethanol blended into motor gasoline is included in both "Petroleum and "biomass," but is 

counted only once in total consumption. e

 Includes coal coke net imports. 

f

 Conventional hydroelectric power. 

g

 Wood, waste, and alcohol fuels (ethanol blended into motor gasoline). 

h

 Includes coal coke net imports and electricity net imports, which are not separately displayed. 
4 

Biomass Energy Data Book: Edition 1 

Except for corn and soybeans, all biomass resources being used in 2005 for energy are some type of 

residue or waste. Corn grain is used for ethanol and soybeans are used for biodiesel fuel. 

Table 1.3 

Renewable Energy Consumption by Source, 1973—2005 

(Trillion Btu) 

Woodb Wastec Alcohol Fuelsd Total

1973 2,861.45 1,527.01 2.06 NA 1,529.07 42.61 NA NA 4,433.12

1974 3,176.58 1,537.76 1.90 NA 1,539.66 53.16 NA NA 4,769.40

1975 3,154.61 1,496.93 1.81 NA 1,498.73 70.15 NA NA 4,723.49

1976 2,976.27 1,711.48 1.89 NA 1,713.37 78.15 NA NA 4,767.79

1977 2,333.25 1,836.52 1.81 NA 1,838.33 77.42 NA NA 4,249.00

1978 2,936.98 2,036.15 1.46 NA 2,037.61 64.35 NA NA 5,038.94

1979 2,930.69 2,149.85 2.05 NA 2,151.91 83.79 NA NA 5,166.38

1980 2,900.14 2,482.86 1.64 NA 2,484.50 109.78 NA NA 5,494.42

1981 2,757.97 2,494.56 88.00 7.00 2,589.56 123.04 NA NA 5,470.57

1982 3,265.56 2,477.05 119.00 19.00 2,615.05 104.75 NA NA 5,985.35

1983 3,527.26 2,639.27 157.00 35.00 2,831.27 129.34 NA 0.03 6,487.90

1984 3,385.81 2,628.82 208.00 43.00 2,879.82 164.90 0.06 0.07 6,430.65

1985 2,970.19 2,575.77 236.32 52.00 2,864.08 198.28 0.11 0.06 6,032.73

1986 3,071.18 2,518.13 262.86 60.00 2,841.00 219.18 0.15 0.04 6,131.54

1987 2,634.51 2,465.16 289.00 69.00 2,823.16 229.12 0.11 0.04 5,686.93

1988 2,334.27 2,551.66 315.33 70.00 2,936.99 217.29 0.09 0.01 5,488.65

1989 2,837.26 2,637.10 354.36 71.00 3,062.46 317.16 55.29 22.03 6,294.21

1990 3,046.39 2,190.58 408.08 63.00 2,661.66 335.80 59.72 29.01 6,132.57

1991 3,015.94 2,189.70 439.72 73.00 2,702.41 346.25 62.69 30.80 6,158.09

1992 2,617.44 2,290.45 473.20 83.00 2,846.65 349.31 63.89 29.86 5,907.15

1993 2,891.61 2,226.86 479.34 96.99 2,803.18 363.72 66.46 30.99 6,155.96

1994 2,683.46 2,315.17 515.32 108.61 2,939.11 338.11 68.55 35.56 6,064.78

1995 3,205.31 2,419.60 531.48 116.50 3,067.57 293.89 69.86 32.63 6,669.26

1996 3,589.66 2,466.79 576.99 83.56 3,127.34 315.53 70.83 33.44 7,136.80

1997 3,640.46 2,349.50 550.60 105.81 3,005.92 324.96 70.24 33.58 7,075.15

1998 3,297.05 2,175.42 542.30 116.92 2,834.64 328.30 69.79 30.85 6,560.63

1999 3,267.58 2,223.73 540.16 121.57 2,885.45 330.92 68.79 45.89 6,598.63

2000 2,811.12 2,256.75 510.80 139.32 2,906.88 316.80 66.39 57.06 6,158.23

2001 2,241.86 1,979.50 513.54 146.67 2,639.72 311.26 65.45 69.62 5,327.91

2002 2,689.02 1,898.77 575.55 174.69 2,649.01 328.31 64.39 105.33 5,836.06

2003 2,824.53 1,929.37 571.35 238.13 2,738.84 339.14 63.62 114.57 6,080.71

2004 2,690.08 2,015.07 564.78 299.31 2,879.16 349.16 63.20 141.75 6,123.35

2005 2,714.66 1,825.52 563.91 339.77 2,729.20 355.75 62.98 149.49 6,012.08

Hydro-electric 

Powera

Geothermale Solarf Windg Total

Biomass

Year

Source: 

Energy Information Administration, Monthly Energy Review March 2006, Table 10.1., 

www.eia.doe.gov/emeu/mer/renew.html

Note: NA = Not available. 

_______________________ 

a

 Conventional hydroelectric power. 

b

 Wood, black liquor, and other wood waste. 

c

 Municipal solid waste, landfill gas, sludge waste, tires, agricultural byproducts, and other 

biomass. 

d

 Ethanol blended into motor gasoline. 

e

 Geothermal electricity net generation, heat pump, and direct use energy. 

f

 Solar thermal and photovoltaic electricity net generation, and solar thermal direct use 

energy. 

g

 Wind electricity net generation. 
 5

Biomass Energy Data Book: Edition 1 

Ethanol provided 1.2% of the transportation fuels consumed in the United States in 2005 and biomass 

provided 0.15% of primary industrial energy consumed in the United States The forest products industry 

consumes 85% of all wood residues (including black liquor) currently used for energy in the United 

States, generating over half of their own energy. 

Table 1.4 

Estimated Renewable Energy Consumption for Industrial and Transportation Sectors, 1973–2005 

(Trillion Btu) 

Source:

Source: Energy Information Administration, Monthly Energy Review, March 2006, Table 10.2b 

www.eia.doe.gov/emeu/mer/renew.html

Note: NA = Not available. 

_______________________ a

 Industrial sector fuel use, including that at industrial combined-heat-and-power (CHP) and industrial 

electricity plants. b

 Conventional hydroelectric power. 

c

 Wood, black liquor, and other wood waste. 

d

 Municipal solid waste, landfill gas, sludge waste, tires, agricultural byproducts, and other biomass. e Geothermal heat pump and direct use energy. 

f

 Ethanol blended into motor gasoline.

Transportation Sector

Biomass

Woodc Wasted Total Alcohol Fuelsf

1973 34.77 1,164.85 NA 1,164.85 NA 1,199.63 NA

1974 33.20 1,159.07 NA 1,159.07 NA 1,192.28 NA

1975 32.32 1,063.27 NA 1,063.27 NA 1,095.59 NA

1976 33.37 1,219.88 NA 1,219.88 NA 1,253.25 NA

1977 32.60 1,281.25 NA 1,281.25 NA 1,313.85 NA

1978 31.56 1,400.42 NA 1,400.42 NA 1,431.99 NA

1979 34.09 1,404.86 NA 1,404.86 NA 1,438.96 NA

1980 32.84 1,600.00 NA 1,600.00 NA 1,632.84 NA

1981 33.04 1,602.00 86.72 1,688.72 NA 1,721.76 7.00

1982 33.05 1,516.00 117.69 1,633.69 NA 1,666.74 19.00

1983 33.26 1,690.00 155.29 1,845.29 NA 1,878.54 35.00

1984 33.00 1,679.00 203.57 1,882.57 NA 1,915.57 43.00

1985 33.02 1,645.00 229.64 1,874.64 NA 1,907.66 52.00

1986 33.02 1,610.00 255.70 1,865.70 NA 1,898.72 60.00

1987 32.94 1,576.00 281.77 1,857.77 NA 1,890.71 69.00

1988 32.64 1,625.00 307.71 1,932.71 NA 1,965.34 70.00

1989 28.40 1,583.57 200.41 1,783.97 1.80 1,814.17 71.00

1990 30.95 1,441.91 192.32 1,634.24 1.90 1,667.09 63.00

1991 29.68 1,409.85 184.68 1,594.52 2.10 1,626.30 73.00

1992 30.51 1,461.23 178.51 1,639.74 2.20 1,672.45 83.00

1993 29.59 1,483.17 181.16 1,664.33 2.40 1,696.32 96.99

1994 62.19 1,579.74 199.25 1,778.98 2.80 1,843.97 108.61

1995 54.70 1,652.08 195.03 1,847.11 3.00 1,904.80 116.50

1996 60.77 1,683.50 223.55 1,907.05 2.90 1,970.72 83.56

1997 58.06 1,730.62 184.02 1,914.63 3.10 1,975.79 105.81

1998 54.54 1,603.44 180.35 1,783.79 3.00 1,841.33 116.92

1999 48.66 1,619.52 171.04 1,790.56 4.10 1,843.32 121.57

2000 42.18 1,635.93 145.11 1,781.04 4.40 1,827.62 139.32

2001 32.50 1,442.61 150.28 1,592.89 4.76 1,630.15 146.67

2002 38.91 1,396.44 168.12 1,564.56 4.79 1,608.25 174.69

2003 43.24 1,363.32 169.63 1,532.94 4.55 1,580.73 238.13

2004 32.56 1,476.12 164.85 1,640.97 4.79 1,678.31 299.31

2005 31.79 1,284.14 154.80 1,438.93 4.79 1,475.51 339.77

Total

Industrial Sectora

Year

Hydroelectric 

Powerb

Biomass

Geothermale
6 

Biomass Energy Data Book: Edition 1 

In 2005, biomass accounted for about 82% of the renewable energy used in the residential sector and 

about 84% of the renewable energy used in the commercial sector. 

Table 1.5 

Estimated Renewable Energy Consumption for Residential and Commercial Sectors, 1973–2005 

(Trillion Btu) 

Biomass

Woodb

Hydroelectric Woodb Waste Total

Geothermalc

1973 354.10 NA NA 354.10 NA 6.71 NA 6.71 NA 6.71

1974 370.95 NA NA 370.95 NA 7.02 NA 7.02 NA 7.02

1975 425.41 NA NA 425.41 NA 8.07 NA 8.07 NA 8.07

1976 481.63 NA NA 481.63 NA 9.10 NA 9.10 NA 9.10

1977 541.78 NA NA 541.78 NA 10.29 NA 10.29 NA 10.29

1978 621.85 NA NA 621.85 NA 11.83 NA 11.83 NA 11.83

1979 728.08 NA NA 728.08 NA 13.81 NA 13.81 NA 13.81

1980 859.00 NA NA 859.00 NA 21.00 NA 21.00 NA 21.00

1981 869.00 NA NA 869.00 NA 21.00 NA 21.00 NA 21.00

1982 937.00 NA NA 937.00 NA 22.00 NA 22.00 NA 22.00

1983 925.00 NA NA 925.00 NA 22.00 NA 22.00 NA 22.00

1984 923.00 NA NA 923.00 NA 22.00 NA 22.00 NA 22.00

1985 899.00 NA NA 899.00 NA 24.00 NA 24.00 NA 24.00

1986 876.00 NA NA 876.00 NA 27.00 NA 27.00 NA 27.00

1987 852.00 NA NA 852.00 NA 29.00 NA 29.00 NA 29.00

1988 885.00 NA NA 885.00 NA 32.00 NA 32.00 NA 32.00

1989 918.00 5.00 52.68 975.68 0.69 35.96 22.00 57.96 2.50 61.14

1990 581.00 5.50 55.90 642.40 1.43 39.15 27.77 66.91 2.80 71.14

1991 613.00 5.90 57.77 676.67 1.37 41.05 26.49 67.54 3.00 71.91

1992 645.00 6.40 59.75 711.15 1.27 44.01 32.45 76.46 3.20 80.92

1993 548.00 6.80 61.69 616.49 1.03 45.86 33.39 79.25 3.40 83.68

1994 537.00 6.20 63.53 606.73 0.96 46.10 34.52 80.63 4.20 85.78

1995 596.00 6.60 64.73 667.33 1.22 46.11 40.20 86.30 4.50 92.02

1996 595.00 7.00 65.44 667.44 1.30 50.43 53.03 103.46 5.30 110.06

1997 433.00 7.50 65.02 505.52 1.23 48.90 57.61 106.50 5.70 113.43

1998 387.14 7.70 64.66 459.50 1.23 48.13 54.16 102.30 7.10 110.62

1999 413.87 8.50 63.73 486.10 1.17 52.31 53.92 106.22 6.70 114.10

2000 433.35 8.60 61.36 503.30 1.02 53.16 47.26 100.41 7.60 109.03

2001 370.00 9.45 59.85 439.30 0.69 40.49 39.22 79.71 8.27 88.67

2002 313.00 10.20 58.75 381.95 0.13 39.15 41.96 81.11 8.75 89.99

2003 359.00 16.96 58.15 434.11 0.74 39.76 47.48 87.24 14.48 102.46

2004 332.34 17.85 57.44 407.63 1.05 41.42 55.47 96.88 15.24 113.18

2005 332.34 17.85 57.44 407.63 0.82 41.43 45.67 87.10 15.24 103.16

Residential Sector Commercial Sectora

Biomass

Year Total

Geothermalc Solard Total

Source: 

Energy Information Administration, Monthly Energy Review March 6, 2006, Table 10.2a, 

www.eia.doe.gov/emeu/mer/renew.html

Note: NA = Not available. 

_______________________ a

 Commercial sector fuel use, including that at commercial combined-heat-and-power (CHP) and commercial 

electricity-only plants. b

 Wood, black liquor, and other wood waste. 

c

 Geothermal heat pump and direct use energy. 

d

 Solar thermal direct use energy and photovoltaic electricity generation. Small amounts of commercial sector 

are included in the residential sector. 
 7

Biomass Energy Data Book: Edition 1 

Biomass is the single largest source of renewable energy in the United States, recently surpassing 

hydroelectric power. In 2005, biomass contributed 2.8% of the total U.S. energy consumption of nearly 

100 quadrillion Btu (EIA, 2006). Wood, wood waste, and black liquor from pulp mills is the single largest 

source accounting for more than two-thirds of total biomass energy consumption. Wastes (which include 

municipal solid waste, landfill gas, sludge waste, tires, agricultural by-products, and other secondary and 

tertiary sources of biomass) accounts for about 20% of total biomass consumption. The remaining share 

is alcohol fuel derived principally from corn grain. 

Figure 1.1 

Summary of Biomass Energy Consumption, 2005 

Source:

Energy Information Administration, Monthly Energy Review, August 2006. 

http://www.eia.doe.gov/emeu/mer/contents.html 
8 

Biomass Energy Data Book: Edition 1 

Total industrial biomass energy consumption was approximately 1,533 trillion Btu in 2003. The bulk of industrial 

biomass energy consumption is derived from forestlands. More than one-half of this total is black liquor – a pulping 

mill by-product containing unutilized wood fiber and chemicals. Black liquor is combusted in recovery boilers to 

recover valuable chemicals and to produce heat and power. Wood and wood wastes generated in primary wood 

processing mills account for another third of total industrial biomass energy consumption. The data contained in this 

table are from a survey of manufacturers that is conducted every four years by the EIA. 

Table 1.6 

Industrial Biomass Energy Consumption and Electricity Net Generation by Industry 

and Energy Sources, 2003

Total Total 1,532.947 378.706 1,154.242 29,001

Agriculture, Forestry, and Mining Total 9.010 2.720 6.290 167

Agricultural Byproducts/Crops 9.010 2.720 6.290 167

Manufacturing Total 1,444.208 375.986 1,068.222 28,834

 Food and Kindred Industry Products Total 41.318 5.176 36.142 104

Agricultural Byproducts/Crops 37.153 4.073 33.079 28

Other Biomass Gases 0.278 0.217 0.062 8

Other Biomass Liquids 0.067 0.067 - 5

Tires 0.379 0.179 0.201 14

Wood/Wood Waste Solids 3.441 0.641 2.801 49

 Lumber Total 216.442 16.364 200.078 1,499

Sludge Waste 0.058 0.019 0.039 3

Wood/Wood Waste Liquids 0.248 0.080 0.168 12

Wood/Wood Waste Solids 216.137 16.265 199.872 1,483

 Paper and Allied Products Total 1,150.781 352.138 798.643 27,039

Agricultural Byproducts/Crops 1.131 0.092 1.040 7

Black Liquor 814.120 239.340 574.780 18,311

Landfill Gas 0.310 0.063 0.247 7

Municipal Solid Waste 2.274 0.427 1.848 53

Other Biomass Liquids 0.071 0.034 0.037 2

Other Biomass Solids 0.741 0.586 0.155 59

Sludge Waste 10.136 3.536 6.600 251

Tires 7.540 2.627 4.913 253

Wood/Wood Waste Liquids 21.019 4.697 16.322 416

Wood/Wood Waste Solids 293.439 100.738 192.701 7,679

 Chemicals and Allied Products Total 3.870 0.745 3.125 43

Landfill Gas 0.214 0.041 0.173 4

Municipal Solid Waste 1.398 0.122 1.276 12

Other Biomass Liquids 0.073 0.014 0.059 0

Other Biomass Solids 0.004 0.001 0.003 0

Sludge Waste 0.300 0.072 0.228 9

Wood/Wood Waste Solids 1.881 0.496 1.385 18

 Othera Total 31.797 1.564 30.233 149

Nonspecifiedb Total 79.730 - 79.730 -

Landfill Gas 74.730 - 74.730 -

Municipal Solid Waste 5.000 - 5.000 -

Biomass Energy Consumption (Trillon Btus)

Industry Energy Source Total For Electricity

For Useful 

Thermal 

Output

Net 

Generation 

(Million 

Sources: 

Energy Information Administration, Form EIA-906, "Power Plant Report," Government Advisory Associates, Resource 

Recovery Yearbook and Methane Recovery Yearbook; and analysis conducted by the Energy Information 

Administration, Office of Coal, Nuclear, Electric and Alternate Fuels. 

Notes: Totals may not equal sum of components due to independent rounding. 

____________________ a

 Other includes Apparel; Petroleum Refining; Rubber and Misc. Plastic Products; Transportation Equipment; 

Stone, Clay, Glass, and Concrete Products; Furniture and Fixtures; and related industries. b

 Primary purpose of business is not specified. 

 - = Not Applicable. 
 9

Biomass Energy Data Book: Edition 1 

Approximately 492 million dry tons of biomass residues are produced from agricultural lands in the United 

States. Nearly half of this total residue production is from corn. The amount of this residue that can be 

collected depends on numerous factors affecting soil sustainability, such as water and wind erosion, as 

well as the efficiency of the collection equipment. 

Table 1.7 

Total Residue Produced on Agricultural Lands, 2001 

Crop

Acres 

harvested 

or reserved

Product 

Yield

Fiber 

Yield

Residue 

Yield 

Total 

cropland 

plant 

mass

Total 

redsidue 

produced

million acres

Corn Grain 68.8 3.3 NA 3.3 450.0 225.0

Sorghum 8.6 1.4 NA 1.4 24.8 12.4

Barley 4.3 1.2 NA 1.8 12.8 7.7

Oats 1.9 0.8 NA 1.7 4.8 3.2

Wheat-winter 31.3 1.1 NA 1.9 95.4 60.1

Wheat-spring 17.5 0.9 NA 1.2 35.5 20.1

Soybeans 73.0 1.1 NA 1.6 193.0 115.8

Rice 3.3 2.9 NA 4.3 23.7 14.2

Cotton lint 13.8 0.3 NA 1.0 17.7 13.3

Alfalfa 23.8 3.0 NA 0.0 70.6 0.0

Other hay 39.7 1.7 NA 0.0 67.4 0.0

Silage corn 6.1 6.6 NA 0.0 40.8 0.0

Silage sorghum 0.3 4.4 NA 0.0 1.5 0.0

Other Crops 20.1 1.0 NA 1.0 20.1 20.1

Crop failure 10.0 0.5 NA 0.0 5.0 0.0

Summer fallow 21.0 0.0 NA 0.0 0.0 0.0

Grasses (CRP) 25.4 2.0 NA 0.0 50.8 0.0

Trees (CRP) 2.2 2.0 NA 0.0 4.4 0.0

Environment (CRP) 6.4 2.0 NA 0.0 12.7 0.0

UNAccounted 3.0 0.0 NA 0.0 0.0 0.0

Pasture 67.5 1.5 NA 0.0 101.3 0.0

Wood fiber 0.1 0.0 6.0 2.0 0.8 0.2

Perennials 0.0 0.0 0.0 0.0 0.0 0.0

Totals 448.1 1233.1 492.1

dry tons/acre/year million dry tons/year

Source: 

Table from page 55 of: Perlack, R.D., Wright, L.L., Turhollow, A.F., Graham, R.L., Stokes, B.J., and 

Erbach, DC. 2005. Biomass as Feedstock for a Bioenergy and Bioproducts Industry: The Technical 

Feasibility of a Billion-Ton Annual Supply. http://www.eere.energy.gov/biomass/publications.html. 

(Scroll down to feedstocks.) 

Note: Some totals may differ slightly from the original source due to rounding differences. 

NA = Not available. 

Based on 2001 Agricultural Statistics, these data were used to provide the baseline supply for the 

document noted in the source. 
10 

Biomass Energy Data Book: Edition 1 

The United States has a total land area in all 50 states of 2.263 billion acres. Based on the 2002 land use 

inventory, 20% of that land was categorized as cropland and 29% as forest-use land, thus about 49% of 

U.S. land is a potential source of biomass residuals or biomass crops for bioenergy. Grassland pasture 

and range land is, for the most part, too dry to provide much biomass resources. Miscellaneous, special 

use land and urban land may be a source of post-consumer biomass residuals, but are not areas where 

biomass crops could be produced on a large scale. 

Figure 1.2 

Major Uses of Land in the United States, 2002 

 

U.S. land use categories differ slightly depending on who is reporting the results. The numbers below 

published in 2006, but based on a 2002 land inventory, were generated by the Economic Research 

Service (ERS) of USDA. They have been producing similar estimates since 1945. Other USDA 

organizations, the Natural Resources Conservation Service (NRCS) and the Forest Service (FS) place 

land into somewhat different categories. URL’s for NRCS and FS estimates are given below. The NRCS 

divides the land into additional sub-categories (such as a “Federal land” category), and only gives values 

for the lower 48 states. The Forest Service documents only deal with forest land, but include a larger 

area of the U.S. in that category (747 million acres based on 1997 inventory data). However, ERS in a 

2002 publication on land use stated that 105 million acres in the special uses category overlaps with 

forestland. If that area is added to the ERS forestland category then it nearly matches the NRCS forest 

land use estimate. Definitions of the ERS land use categories follow. NRCS and FS land use references 

can be found at: www.nrcs.usda.gov/technical/nri02/landuse.pdf and by searching for publications by Alig 

at: www.treesearch.fs.fed.us/pubs. 

Source: 

Lubowski, R.N., Vesterby, M., Bucholtz, S., Baez, A., Roberts, M.J. 2006. “Major Uses of Land in the 

United States, 2002” USDA Economic Research Service, Economic Information Bulletin Number 

14, May 2006. www.ers.usda.gov/publications/eib14. 
 11

Biomass Energy Data Book: Edition 1 

Figure 1.2 (Continued) 

Major Uses of Land in the United States, 2002 

Notes: Cropland: All land in the crop rotation, including cropland used for crops, land with crop failure, 

summer fallow, idle cropland (including Conservation Reserve Program land), and cropland used only for 

pasture. Cropland in Alaska and Hawaii total less than 0.4 million acres. 

Grassland pasture and range: Permanent grassland and other nonforested pasture and range. 

Forest-use land: Total forest land as classified by the U.S. Forest Service includes grazed forest land 

(134 million acres) as well as other forest land (517 million acres). It does not include land in the special 

uses category that is forested. This category includes a small amount of rural residential area within 

forested areas. 

Special Uses: This land includes recreation and wildlife areas, national defense areas, and land used for 

rural highways, roads and railroad rights-of-way, and rural airports. It also includes 11 million acres for 

farmsteads and farm roads. 

Miscellaneous land: This includes tundra, deserts, bare rock areas, snow and ice fields, swamps, 

marshes, and other unclassified areas generally of low agricultural value. 

Urban land: Urban lands are newly separated from special use lands in the 2006 Major Land Uses report 

prepared by ERS. Urban areas are based on Census Bureau definitions which identify “urban clusters” 

based primarily on population density, not political boundaries. 
12 

Biomass Energy Data Book: Edition 1 

Current commodity crop locations are good indicators of where biomass resources can be cultivated. 

Figure 1.3 

Geographic Locations of Major Crops, 2004 
 13

Biomass Energy Data Book: Edition 1 

Figure 1.3 (Continued) 

Geographic Locations of Major Crops, 2004 

Source: 

U.S. Department of Agriculture, National Agricultural Statistics Service. 

http://www.usda.gov/nass/aggraphs/cropmap.htm. 
14 

Biomass Energy Data Book: Edition 1 

FUTURE ENERGY CROP SUPPLY POTENTIAL—CELLULOSIC BIOMASS 

"Woodchips, Stalks, and Switchgrass" - Cellulosic Biomass:

A Discussion of Future Energy Crop Supply Potential

President Bush spoke in his January 31, 2006, State of the Union address of producing biofuels by 2012 

using "woodchips, stalks and switchgrass" as the source of cellulosic biomass. These represent both 

existing and potential biomass resources. 

The "woodchips and stalks" represent resources that are currently available from forestry and agriculture, 

though very underutilized. One of the largest unexploited categories is wood that needs to be removed 

from forests to reduce the risk of forest fires. Well over 8 billion dry tons of biomass has been identified by 

the U.S. Forest Service as needing fuel treatment removal. The amount of this biomass potentially 

available for bioenergy uses is estimated to be about 60 million dry tons annually. This estimate takes into 

consideration factors affecting forest access, residue recovery and the desirability of using some of the 

recoverable biomass for conventional wood products. The fraction that could be available for bioenergy 

and bioproducts is less than 1% of the total size of the fuel treatment biomass resource. Factors affecting 

the rate at which this source of material will become available include public opinion toward this type of 

removal, as well as delivered costs and the extent to which technology is developed for utilizing small 

diameter wood for products other than bioenergy. The other large underutilized forest sources of 

woodchips are logging residues and urban wood residues. In both cases, the relatively high costs of 

removal, handling, and transportation has not compared favorably to their relatively low value as an 

energy resource. Also, the compost market could compete for urban wood resources. From the 

agricultural sector, the major cellulosic resources are corn "stalks" and wheat straw. Both are left in the 

field after the grain is harvested in much of the U.S. While a portion of this residue does have a value in 

maintaining soil quality and crop productivity, in some higher yield areas of the U.S. there is an excess of 

residue produced that could be beneficially removed. It is important to use this resource in a way that is 

environmentally and economically sound and that supplies the needs of biorefineries in terms of cost, 

quality and consistency.

Switchgrass is a thin-stemmed, warm season, perennial grass that has shown high potential as a highyielding crop that can be grown in most areas of the nation that are also suitable for crop production. 

There are, in fact, many perennial crops (grass and tree species) that show high potential for production 

of cost-competitive cellulosic biomass. The “best” crop for a given area can only be determined by local 

soil and climate conditions and the desired end-use. Thus “switchgrass” can be viewed as a surrogate for 

many “perennial energy crops” when doing biomass supply analysis. Other perennial energy crops that 

might be preferred in some situations include other thin-stemmed grasses, such as Reed Canary grass or 

Big Bluestem grass, or thick-stemmed grasses with rhizomes, such as Miscanthus, Energy cane, or 

Arundo (all may sometimes be marketed as E-Grass); trees grown as single stem row crops, such as 

poplars, eucalyptus, silver maple, sweetgum and sycamore, or trees grown as multiple stem row crops 

such as willow or poplar coppice. Some annual crops are also being evaluated as dedicated energy crops 

including corn, sorghum, and kenaf (a woody annual crop), because of very high yields. The perennial 

crops will normally show better environmental performance due to lower chemical requirements and 

better erosion control. Cost of production of energy crops is very sensitive to yield, thus development of 

better energy crops involves traditional genetic selection and/or molecular genetics. It is also extremely 

important to select appropriate sites and optimize agronomic or silvicultural management techniques to 

eliminate weed competition and assure that adequate nutrients and water are available (but without overfertilizing or irrigating).
 15

Biomass Energy Data Book: Edition 1 

Crop residues and high yield dedicated energy crops will not become cellulosic biomass supplies unless 

efficient, integrated biomass supply systems are developed. This means first of all, fully integrating crop 

production, harvesting and collection, storage, preprocessing, and transportation for each crop type and 

end use scenario. A roadmap developed jointly by researchers, producers, and users in 2003 spells out 

the R&D needs for assuring that cellulosic biomass can be supplied in a way that meets the cost, quality 

and consistency requirements of biorefineries (or biopower or biofuels production facilities).

Source: U.S. Department of Energy, 2003. Roadmap for Agricultural Biomass Feedstock Supply in the 

United States. Available at: http://www1.eere.energy.gov/biomass/document_database.html (search for 

Roadmap).
16 

Biomass Energy Data Book: Edition 1 
 17

Biomass Energy Data Book: Edition 1 

2. BIOFUELS 

BRIEF OVERVIEW 

A variety of fuels can be produced from biomass resources including liquid fuels, such as ethanol, 

methanol, biodiesel, Fischer-Tropsch diesel, and gaseous fuels, such as hydrogen and methane. Biofuels 

are primarily used to fuel vehicles, but can also fuel engines or fuel cells for electricity generation. 

FUELS 

Ethanol 

Ethanol is made by converting the carbohydrate from biomass into sugar, which is then converted into 

ethanol in a fermentation process similar to brewing beer. Ethanol is the most widely used biofuel today 

with current capacity of 4.3 billion gallons per year based on starch crops, such as corn. Ethanol 

produced from cellulosic biomass is currently the subject of extensive research, development and 

demonstration efforts. 

Biodiesel 

Biodiesel is produced through a process in which organically derived oils are combined with alcohol 

(ethanol or methanol) in the presence of a catalyst to form ethyl or methyl ester. The biomass-derived 

ethyl or methyl esters can be blended with conventional diesel fuel or used as a neat fuel (100% 

biodiesel). Biodiesel can be made from any vegetable oil, animal fats, waste vegetable oils, or microalgae 

oils. Soybeans and Canola (rapeseed) oils are the most common vegetable oils used today. 

BioOil 

A totally different process than that used for biodiesel production can be used to convert biomass into a 

type of fuel similar to diesel which is known as BioOil. The process, called fast or flash pyrolysis, occurs 

when heating compact solid fuels at temperatures between 350 and 500 degrees Celcius for a very short 

period of time (less than 2 seconds). While there are several fast pyrolysis technologies under 

development, there are only two commercial fast pyrolysis technologies as of 2006. The BioOils currently 

produced are suitable for use in boilers for electricity generation. Additional research and development is 

needed to produce BioOil of sufficient quality for transportation applications. 

Biofuels from Synthesis Gas 

Biomass can be gasified to produce a synthesis gas composed primarily of hydrogen and carbon 

monoxide, also called syngas or biosyngas. Syngas produced today is used directly to generate heat and 

power but several types of biofuels may be derived from syngas. Hydrogen can be recovered from this 

syngas, or it can be catalytically converted to methanol. The gas can also be run through a biological 

reactor to produce ethanol or can also be converted using Fischer-Tropsch catalyst into a liquid stream 

with properties similar to diesel fuel, called Fischer-Tropsch diesel. However, all of these fuels can also be 

produced from natural gas using a similar process. Data on biofuels from synthesis gas are not currently 

included in the Biomass Data Book. 

Source: U.S. Department of Energy, Energy Efficiency and Renewable Energy, 

http://www.eere.energy.gov/RE/bio_fuels.html
18 

Biomass Energy Data Book: Edition 1 

Federal tax incentives for alcohol fuels were first established in 1978 for 10% blended gasoline (gasohol) 

creating an effective Federal subsidy for ethanol of $0.40/gallon. Various subsequent acts have raised or 

lowered, modified, and extended the subsidy. Tax incentives for biodiesel were first initiated in 2004 with 

the American Jobs Creation Act. In addition to the tax subsidies, there is the Renewable Portfolio 

Standard for biofuels and several other types of incentives. 

Table 2.1 

Major Federal Biofuel Tax Incentives 

Title Code or Lawa Fuel Type Incentive Qualifying Period Limitsc

Volumetric Ethanol 

Excise Tax Credit 

(VEETC)

Public Law 108-

357b

ethanol of 190 proof or

greater from biomass 

(e.g. corn grain, 

cellulosics)

$0.51 per pure gal of 

ethanol used or blended.

January 2005 – 

December 2010

Available to blenders/ 

retailers

Volumetric Excise 

Tax Credit for 

Biodiesel

EPACT 2005 c 

§1344, Title XIII, 

Subtitle D

Agri-biodiesel (e.g. 

from soybeans or 

other oil seeds)

$1.00 per pure gal of agribiodiesel used or blended 

Expires December 31, 

2008

Available to blenders/ 

retailers

Volumetric Excise 

Tax Credit for 

Biodiesel

EPACT 2005 

§1344, Title XIII, 

Subtitle D

Waste-grease 

biodiesel

$0.50 per pure gal of 

waste-grease biodiesel 

used or blended

Expires December 31, 

2008

Available to blenders/ 

retailers

Volumetric Excise 

Tax Credit for 

Biodiesel

EPACT 2005 

§1344, Title XIII, 

Subtitle D

Renewable diesel – 

made from biomass by

thermal 

deploymerization 

process

$1.00 per gal of diesel 

fuel used or blended

Expires December 31, 

2008

Available to blenders/ 

retailers

Small Ethanol 

Producer Credit

EPACT 2005 

§1347, Title XIII, 

Subtitle D

Ethanol from biomass 

(e.g. corn grain, 

cellulosics)

$0.10 per gallon ethanol 

or biodiesel produced up 

to 30 million gallons

Expires December 31, 

2008

< 60 million gallon 

production capacity 

Cap at $1.5 million per 

yr per producer Can 

offset the alternative 

minimum tax

Small Biodiesel 

Producer Credit

EPACT 2005 

§1345, Title XIII, 

Subtitle D

Agri-biodiesel $0.10 per gallon ethanol 

or biodiesel produced up 

to 15 million gallons

Expires December 31, 

2008

Same as above

Income Tax Credit for 

E85 and B20 

Infrastructure

EPACT 2005 

§1342, Title XIII, 

Subtitle D

Ethanol or biodiesel Permits taxpayers to claim

a 30% credit for cost of 

installing clean-fuel 

vehicle refueling property 

at business or residence

January 2006 – 

December 2007

$30,000 limit on tax 

credit

Source: 

Renewable Fuels Association, http://www.ethanolrfa.org/policy/regulations/federal/standard/ 

____________________ 

a

 Most recent Internal Revenue Service code or public law affecting the status of the incentive. In 

several cases, the most recent action is a modification of prior actions. b

 Public Law 108-357 was the American Jobs Creation Act of 2004. 

c

 EPACT 2005 is the Energy Policy Act of 2005. See brief summary of all biofuel related provisions 

in the final version of the Energy Policy Act at: 

http://www.ethanolrfa.org/policy/regulations/federal/standard/ 
 19

Biomass Energy Data Book: Edition 1 

Table 2.2 

Selected Non-Tax Federal Biofuel Incentives 

Source: 

The Energy Policy Act of 2005 and the Farm Security and Rural Investment Act of 2002. 

http://thomas.loc.gov/cgi-bin/thomas. 

http://www.ers.usda.gov/Features/FarmBill/. 

_______________________ 

a

 The Energy Policy Act of 2005 contains many sections that could help in facilitating the 

development of biofuels or biomass power and/or that request new studies to assist in developing further 

policy. For a description of 42 of the relevant sections see the September-October 2005 newsletter 

published by General Bioenergy, Inc. (www.bioenergyupdate.com) under newsletter Archives. Not 

included in this summary are sections pertaining to alternative-fueled vehicles. 

Federal Action Title Goal Notes and More information

brief summary of RFS provisions:

http://www.ethanolrfa.org/policy/regulations/federal/standard/

summary of RFS and other biofuels incentives:

http://www.ethanol.org/rfs.html 

EPA regulations relevant to RFS:

http://www.epa.gov/oms/renewablefuels/

EPACT 2005 Title II, §941 Effective biomass R,D&D Modifies the Biomass Research and Development Act of 2000.

Broadens scope from industrial products to fuels and biobased 

products. Includes development and demonstration as 

relevant activities. It spells out research priorities and 

distribution of funds. 50% of the funds are to go to 

demonstration projects with 20% or greater cost-share. 

EPACT 2005 Title II, §942 Production 

Incentive for Cellulosic 

Biofuels

Cost competitive 

cellulosic biomass by 

2015 

One gallon of cellulosic ethanol and ethanol produced in 

facilities using animal waste to displace fossil fuel use qualifies 

as 2.5 gallons towards satisfying the RFS

EPACT 2005 Title II, §943 

Procurement of 

Biobased Products

Federal agencies to 

showcase biobased 

products

Expands Biobased Procurement Program to Federal 

government contractors, and establishes program of public 

education regarding federal use of biobased products

EPACT 2005 Title XV, §1511 Incentive for commercial 

cellulosic ethanol

Directs Department of Energy to provide loan guarantees for 

not more than 4 commercial demonstrations, to include one 

using cereal straw and one using MSW as feedstocks. Must 

have capacity of 30 million gallons or more. 

Farm Security and 

Rural Investment 

Act of 2002

Commodity Credit 

Corporation Bioenergy 

Program

Increase ethanol 

production

The USDA Farm Service Agency has for several years 

encouraged new biofuel production capacity by making cash 

payments to bioethanol and biodiesel producers for new 

production. The program is scheduled to end in September 

2006. 

EPACT 2005 a Title II, §203 Renewable 

Fuels Standard (RFS)

4.0 billion gallons ethanol 

in 2006; 7.5 billion gallons

of ethanol by 2012
20 

Biomass Energy Data Book: Edition 1 

ETHANOL OVERVIEW

There are two types of ethanol produced in the United States – fermentation ethanol and synthetic 

ethanol. Fermentation ethanol (or bioethanol) is produced from corn or other biomass feedstocks and is 

by far the most common type of ethanol produced, accounting for more than 90% of all ethanol 

production. Fermentation ethanol is mainly produced for fuel, though a small share is used by the 

beverage industry and the industrial industry. Synthetic ethanol is produced from ethylene, a petroleum 

by-product, and is used mainly in industrial applications. A small amount of synthetic ethanol is exported 

to other countries.

Ethanol is the most widely used biofuel today. In 2005, more than 3.6 billion gallons were added to 

gasoline in the United States to improve vehicle performance and reduce air pollution. Ethanol is currently 

produced using a process similar to brewing beer where starch crops are converted into sugars, the 

sugars are fermented into ethanol, and the ethanol is then distilled into its final form. 

Ethanol is used to increase octane and improve the emissions quality of gasoline. In many areas of the 

United States today, ethanol is blended with gasoline to form an E10 blend (10% ethanol and 90% 

gasoline), but it can be used in higher concentrations, such as E85, or in its pure form E100. All 

automobile manufacturers that do business in the United States approve the use of E10 in gasoline 

engines; however, only flex fuel vehicles (FFVs) are designed to use E85. Pure ethanol or E100 is used 

in Brazil but is not currently compatible with vehicles manufactured for the U.S. market. Manufacturer 

approval of ethanol blends is found in vehicle owners' manuals under references to refueling or gasoline.

Bioethanol from cellulosic biomass materials (such as agricultural residues, trees, and grasses) is made 

by first using pretreatment and hydrolysis processes to extract sugars, followed by fermentation of the 

sugars. Although producing bioethanol from cellulosic biomass is currently more costly than producing 

bioethanol from starch crops, the U.S. Government has launched a Biofuels Initiative with the objective of 

quickly reducing the cost of cellulosic bioethanol. Researchers are working to improve the efficiency and 

economics of the cellulosic bioethanol production process. When cellulosic bioethanol becomes 

commercially available, it will be used exactly as the bioethanol currently made from corn grain.

Source: DOE Energy Efficiency and Renewable Energy, 

http://www1.eere.energy.gov/biomass/abcs_biofuels.html and 

http://www1.eere.energy.gov/biomass/bioethanol
 21

Biomass Energy Data Book: Edition 1 

Below are the primary quality specifications for denatured fuel ethanol for blending with gasoline meeting 

Federal requirements. The state of California has additional restrictions that apply in addition to the 

performance requirements in ASTM D 4806. 

Table 2.3 

Specifications Contained in ASTM D 4806 Standard Specification for Denatured Fuel Ethanol 

for Blending with Gasoline 

Property Specification ASTM Test Method

Ethanol volume %, min 92.1 D 5501 

Methanol, volume %. max 0.5 

Solvent-washed gum, mg/100 ml max 5 D 381 

Water content, volume %, max 1 E 203 

Denaturant content, volume %, min 1.96 

 volume %, max 4.76 

Inorganic Chloride content, mass ppm (mg/L) max 40 D 512 

Copper content, mg/kg, max 0.1 D1688 

Acidity (as acetic acid CH3COOH), mass percent 0.007 D1613 

 (mg/L), max 

pHe 6.5-9.0 D 6423 

Appearance 

Visibly free of suspended or precipitated 

contaminants (clear & bright)

Source: 

Renewable Fuels Association, Industry Guidelines, Specifications, and Procedures. 

http://www.ethanolrfa.org/industry/resources/guidelines/. 
22 

Biomass Energy Data Book: Edition 1 

Table 2.4 

Fuel Property Comparison for Ethanol, Gasoline and No. 2 Diesel 

Property Ethanol Gasoline No. 2 Diesel

 Chemical Formula C2H5OH C4 to C12 C3 to C25 

 Molecular Weight 46.07 100–105 

 Carbon 52.2 85–88 84–87 

 Hydrogen 13.1 12–15 33–16 

 Oxygen 34.7 0 0

 Specific gravity, 60° F/60° F 0.796 0.72–0.78 0.81–0.89 

 Density, lb/gal @ 60° F 6.61 6.0–6.5 6.7–7.4 

 Boiling temperature, °F 172 80–437 370–650 

 Reid vapor pressure, psi 2.3 8–15 0.2

 Research octane no. 108 90–100 -- 

 Motor octane no. 92 81–90 -- 

 (R + M)/2 100 86–94 N/A 

 Cetane no.(1) -- 5–20 40–55 

 Fuel in water, volume % 100 Negligible Negligible 

 Water in fuel, volume % 100 Negligible Negligible 

 Freezing point, °F -173.2 -40 -40–30b 

 Centipoise @ 60° F 1.19 0.37–0.44a 2.6–4.1 

 Flash point, closed cup, °F 55 -45 165

 Autoignition temperature, °F 793 495 

 Lower 4.3 1.4 1

 Higher 19 7.6 6

 Btu/gal @ 60° F 2,378  

 Btu/lb @ 60° F 396 	 

 Btu/lb air for stoichiometric mixture @ 60° F 44  


 Higher (liquid fuel-liquid water) Btu/lb 12,800 18,800–20,400 19,200–20000 

 Lower (liquid fuel-water vapor) Btu/lb 11,500 18,000–19,000 18,000–19,000 

 Higher (liquid fuel-liquid water) Btu/gal 84,100 124,800 138,700

 Lower (liquid fuel-water vapor) Btu/gal @ 60° F 76,000a 115,000 128,400

 Mixture in vapor state, Btu/cubic foot @ 68° F 92.9 95.2 96.9c 

 Fuel in liquid state, Btu/lb or air 1,280 1,290 – 

 Specific heat, Btu/lb °F 0.57 0.48 0.43

 Stoichiometric air/fuel, weight 9 14.7a 14.7

 Volume % fuel in vaporized stoichiometric mixture 6.5 2 – 

Source: 

U.S. Department of Energy, Office of Energy Effiency and Renewable Energy, Alternative Fuels Data 

Center. http://www.eere.energy.gov/afdc/altfuel/fuel_properties.html. 

____________________ 

a

 Calculated. 

b

 Pour Point, ASTM D97. 

c

 Based on Cetane. 
 23

Biomass Energy Data Book: Edition 1 

The U.S. and Brazil produced about 70 percent of the world’s ethanol in 2005. The table below includes 

all types of ethanol, not just fuel ethanol. 

Table 2.5 

World Ethanol Production by Country, 2005 

(Millions of gallons, all grades) 

Country 2005

U.S. 4,264

Brazil 4,227

China 1,004

India 449

France 240

Russia 198

Germany 114

South Africa 103

Spain 93

U.K. 92

Thailand 79

Ukraine 65

Canada 61

Poland 58

Indonesia 45

Argentina 44

Italy 40

Australia 33

Saudi Arabia 32

Japan 30

Sweden 29

Pakistan 24

Philippines 22

South Korea 17

Guatemala 17

Ecuador 14

Cuba 12

Mexico 12

Nicaragua 7

Zimbabwe 5

Kenya 4

Mauritius 3

Swaziland 3

Others 710

Total 12,150

Source: 

 Renewable Fuels Association, Industry Statistics, 

 http://www.ethanolrfa.org/industry/statistics/#E 

Note: Some countries listed in the table titled: "U.S. Fuel Ethanol 

Imports by Country" do not appear in this table because they process 

ethanol (dehydration) rather than produce it from feedstock. 
24 

Biomass Energy Data Book: Edition 1 

The United States imports a small percentage of ethanol from countries within relatively close geographic 

proximity. 

Table 2.6 

Fuel Ethanol Imports by Country 

(Millions of gallons) 

Source: 

Renewable Fuel Association, http://www.ethanolrfa.org/industry/statistics/

Note: Some countries listed in this table do not appear in the table titled: 

"World Ethanol Production by Country" because they process ethanol 

(dehydration) rather than produce it from feedstock. 

Country 2002 2003 2004

Brazil 0 0 90.3

Costa Rica 12 14.7 25.4

El Salvadore 4.5 6.9 5.7

Jamaica 29 39.3 36.6

Total 45.5 60.9 159.9
 25

Biomass Energy Data Book: Edition 1 

Fuel ethanol production has been on the rise in the United States since 1980, though production has 

increased dramatically since 2001. 

Table 2.7 

Historic Fuel Ethanol Production 

Year Millions of Gallons

1980 175

1981 215

1982 350

1983 375

1984 430

1985 610

1986 710

1987 830

1988 845

1989 870

1990 900

1991 950

1992 1,100

1993 1,200

1994 1,350

1995 1,400

1996 1,100

1997 1,300

1998 1,400

1999 1,470

2000 1,630

2001 1,770

2002 2,130

2003 2,800

2004 3,400

2005 3,900

Source: 

1998-2005: Energy Information Administration, Monthly Oxygenate Report 

http://www.eia.doe.gov/oil_gas/petroleum/data_publications/monthly_oxygenat

e_telephone_report/motr.html; 1908-1997: Renewable Fuels Association, 

http://www.ethanolrfa.org/industry/outlook/index.php, "From Niche to Nation: 

Ethanol Industry Outlook 2006." 
26 

Biomass Energy Data Book: Edition 1 

Between 1999 and 2006, the number of ethanol plants in the United States nearly doubled, accompanied 

by a rapid rise in production capacity. Additional information on specific plant locations and up-to-date 

statistics can be obtained at the Renewable Fuels Association, www.ethanolrfa.org/industry/statistics/ 

Table 2.8 

Ethanol Production Statistics, 1999-2006 

(as of January of each year)

Year 1999 2000 2001 2002 2003 2004 2005 2006

Total Ethanol Plants 50 54 56 61 68 72 81 95

Ethanol Production 

Capacity (million 

gallons per year) 1,701.7 1,748.7 1,921.9 2,347.3 2,706.8 3,100.8 3,643.7 4,336.4

Plants Under 

Construction 5 6 6 13 11 15 16 31

Capacity Under 

Construction (million 

gallons per year) 77.0 91.5 64.7 390.7 483.0 598.0 754.0 1,778.0

Farmer Owned Plants 14 18 21 25 28 33 40 46

Farmer Owned 

Capacity (million 

gallons per year) 293.3 340.3 473.0 645.6 796.6 1,041.1 1,388.6 1,677.1

Percent of Total 

Capacity that is Farmer 

Owned 17% 19% 25% 28% 29% 34% 38% 39%

Farmer Owned Plants 

Under Construction 5 3 3 10 8 12 10 4

Farmer Owned 

Capacity Under 

Construction (million 

gallons per year) 77 60 60 335 318 447 450 187

Percent of Total Under 

Construction Capacity 100% 66% 71% 86% 66% 75% 60% 11%

States with Ethanol 

Plants 17 17 18 19 20 19 18 20

Source: 

Renewable Fuels Association, Table titled: "Ethanol Industry Overview,” 

www.ethanolrfa.org/industry/statistics/
 27

Biomass Energy Data Book: Edition 1 

Although ethanol can be made from a wide variety of feedstocks, the vast majority of ethanol is made 

from corn. Future cellulosic production methods using grasses and woody plant material may eventually 

account for a sizeable share, but in the near term, corn remains the dominant feedstock. 

Table 2.9 

Ethanol Production by Feedstock, 2006 

Plant Feedstock

Capacity (million 

galllons/year) % of Capacity No. of Plants % of Plants

Corna 4,516 92.7% 85 83.3%

Corn/Milo 162 3.3% 5 4.9%

Corn/Wheat 90 1.8% 2 2.0%

Corn/Barley 40 0.8% 1 1.0%

Milo/Wheat 40 0.8% 1 1.0%

Waste Beverageb 16 0.3% 5 4.9%

Cheese Whey 8 0.2% 2 2.0%

Sugars & Starches 2 0.0% 1 1.0%

Total 4,872 100.0% 102 100.0%

Source: 

Environmental Protection Agency, Office of Transportation and Air Quality "Renewable Fuel Standard 

Program - Draft Regulatory Impact Analysis" September 2006, EPA420-D-06-008. 

 ____________________ 

 a

 Includes seed corn. 

 b

 Includes brewery waste 

 
28 

Biomass Energy Data Book: Edition 1 

The great majority of ethanol production facilities operating in the United States use natural gas as their 

energy source. 

Table 2.10 

Ethanol Production by Plant Energy Source, 2006 

Energy Source

Capacity 

MMGal/year % of Capacity No. of Plants % of Plants

Natural Gasa 4671 95.9% 98 96.1%

Coal 102 2.1% 2 2.0%

Coal & Biomass 50 1.0% 1 1.0%

Syrup 49 1.0% 1 1.0%

Total 4872 100.0% 102 100.0%

Source: 

Environmental Protection Agency, Office of Transportation and Air Quality, 

"Renewable Fuel Standard Program - Draft Regulatory Impact Analysis," 

September 2006, EPA420-D-06-008. 

____________________ 

a

 Includes a natural gas facility which is considering transitioning to coal.
 29

Biomass Energy Data Book: Edition 1 

The majority of ethanol production facilities are concentrated where corn is grown. For an up-to-date 

listing of all production facilities, visit the Renewable Fuels Association, http://www.ethanolrfa.org/. 

Figure 2.1 

Ethanol Production Facilities Current and Planned, 2005

Source: 

Renewable Fuels Association, www.ethanolrfa.org/. 
30 

Biomass Energy Data Book: Edition 1 

The production of ethanol or ethyl alcohol from starch or sugar-based feedstocks is among man’s earliest 

ventures into value-added processing. While the basic steps remain the same, the process has been 

considerably refined in recent years, leading to a very efficient process. There are two production 

processes: wet milling and dry milling. The main difference between the two is in the initial treatment of 

the grain. 

Figure 2.2 

The Ethanol Production Process - Wet Milling

In wet milling, the grain is soaked or "steeped" in water and dilute sulfurous acid for 24 to 48 hours. This 

steeping facilitates the separation of the grain into its many component parts. 

After steeping, the corn slurry is processed through a series of grinders to separate the corn germ. The 

corn oil from the germ is either extracted on-site or sold to crushers who extract the corn oil. The 

remaining fiber, gluten and starch components are further segregated using centrifugal, screen and 

hydroclonic separators. 

The steeping liquor is concentrated in an evaporator. This concentrated product, heavy steep water, is 

co-dried with the fiber component and is then sold as corn gluten feed to the livestock industry. Heavy 

steep water is also sold by itself as a feed ingredient and is used as a component in Ice Ban, an 

environmentally friendly alternative to salt for removing ice from roads. 

The gluten component (protein) is filtered and dried to produce the corn gluten meal co-product. This 

product is highly sought after as a feed ingredient in poultry broiler operations. 

The starch and any remaining water from the mash can then be processed in one of three ways: 

fermented into ethanol, dried and sold as dried or modified corn starch, or processed into corn syrup. The 

fermentation process for ethanol is very similar to the dry mill process. 

Source: 

Renewable Fuels Association, http://www.ethanolrfa.org/resource/made/
 31

Biomass Energy Data Book: Edition 1 

Figure 2.3 

The Ethanol Production Process - Dry Milling 

In dry milling, the entire corn kernel or other starchy grain is first ground into flour, which is referred to in 

the industry as "meal" and processed without separating out the various component parts of the grain. 

The meal is slurried with water to form a "mash." Enzymes are added to the mash to convert the starch to 

dextrose, a simple sugar. Ammonia is added for pH control and as a nutrient to the yeast. 

The mash is processed in a high-temperature cooker to reduce bacteria levels ahead of fermentation. 

The mash is cooled and transferred to fermenters where yeast is added and the conversion of sugar to 

ethanol and carbon dioxide (CO2) begins. 

The fermentation process generally takes about 40 to 50 hours. During this part of the process, the mash 

is agitated and kept cool to facilitate the activity of the yeast. After fermentation, the resulting "beer" is 

transferred to distillation columns where the ethanol is separated from the remaining "stillage." The 

ethanol is concentrated to 190 proof using conventional distillation and is then dehydrated to 

approximately 200 proof in a molecular sieve system. 

The anhydrous ethanol is blended with about 5% denaturant (such as natural gasoline) to render it 

undrinkable and thus not subject to beverage alcohol tax. It is then ready for shipment to gasoline 

terminals or retailers. 

The stillage is sent through a centrifuge that separates the coarse grain from the solubles. The solubles 

are then concentrated to about 30% solids by evaporation, resulting in Condensed Distillers Solubles 

(CDS) or "syrup." The coarse grain and the syrup are dried together to produce dried distillers grains with 

solubles (DDGS), a high quality, nutritious livestock feed. The CO2 released during fermentation is 

captured and sold for use in carbonating soft drinks and the manufacture of dry ice. 

Source: 

Renewable Fuels Association, http://www.ethanolrfa.org/resource/made/ 
32 

Biomass Energy Data Book: Edition 1 

This process flow diagram shows the basic steps in production of ethanol from cellulosic biomass. While 

cellulosic ethanol is not yet commercial in the U.S., it has been demonstrated by several groups and 

commercial facilities are being planned in North America. Note that there are a variety of options for 

pretreatment and other steps in the process and that some specific technologies combine two or all three 

of the hydrolysis and fermentation steps within the shaded box. Chart courtesy of the National Renewable 

Energy Laboratory. 

Figure 2.4 

The Production of Ethanol from Cellulosic Biomass 

• Hydrolysis is the chemical reaction that converts the complex polysaccharides in the raw 

feedstock to simple sugars. In the biomass-to-bioethanol process, acids and enzymes are used to 

catalyze this reaction. 

• Fermentation is a series of chemical reactions that convert sugars to ethanol. The fermentation 

reaction is caused by yeast or bacteria, which feed on the sugars. Ethanol and carbon dioxide are 

produced as the sugar is consumed. 

• Process Description. The basic processes for converting sugar and starch crops are well-known 

and used commercially today. While these types of plants generally have a greater value as food 

sources than as fuel sources there are some exceptions to this. For example, Brazil uses its huge 

crops of sugar cane to produce fuel for its transportation needs. The current U.S. fuel ethanol 

industry is based primarily on the starch in the kernels of feed corn, America’s largest agricultural 

crop. 

• Biomass Handling. Biomass goes through a size-reduction step to make it easier to handle and 

to make the ethanol production process more efficient. For example, agricultural residues go 

through a grinding process and wood goes through a chipping process to achieve a uniform 

particle size. 

• Biomass Pretreatment. In this step, the hemicellulose fraction of the biomass is broken down 

into simple sugars. A chemical reaction called hydrolysis occurs when dilute sulfuric acid is mixed 

with the biomass feedstock. In this hydrolysis reaction, the complex chains of sugars that make 

up the hemicellulose are broken, releasing simple sugars. The complex hemicellulose sugars are 

converted to a mix of soluble five-carbon sugars, xylose and arabinose, and soluble six-carbon 

sugars, mannose and galactose. A small portion of the cellulose is also converted to glucose in 

this step. 
 33

Biomass Energy Data Book: Edition 1 

Figure 2.4 (Continued) 

The Production of Ethanol from Cellulosic Biomass 

• Enzyme Production. The cellulase enzymes that are used to hydrolyze the cellulose fraction of 

the biomass are grown in this step. Alternatively the enzymes might be purchased from 

commercial enzyme companies. 

• Cellulose Hydrolysis. In this step, the remaining cellulose is hydrolyzed to glucose. In this 

enzymatic hydrolysis reaction, cellulase enzymes are used to break the chains of sugars that 

make up the cellulose, releasing glucose. Cellulose hydrolysis is also called cellulose 

saccharification because it produces sugars. 

• Glucose Fermentation. The glucose is converted to ethanol, through a process called 

fermentation. Fermentation is a series of chemical reactions that convert sugars to ethanol. The 

fermentation reaction is caused by yeast or bacteria, which feed on the sugars. As the sugars are 

consumed, ethanol and carbon dioxide are produced. 

• Pentose Fermentation. The hemicellulose fraction of biomass is rich in five-carbon sugars, 

which are also called pentoses. Xylose is the most prevalent pentose released by the 

hemicellulose hydrolysis reaction. In this step, xylose is fermented using Zymomonas mobilis or 

other genetically engineered bacteria. 

• Ethanol Recovery. The fermentation product from the glucose and pentose fermentation is 

called ethanol broth. In this step the ethanol is separated from the other components in the broth. 

A final dehydration step removes any remaining water from the ethanol. 

• Lignin Utilization. Lignin and other byproducts of the biomass-to-ethanol process can be used to 

produce the electricity required for the ethanol production process. Burning lignin actually creates 

more energy than needed and selling electricity may help the process economics. 

Converting cellulosic biomass to ethanol is currently too expensive to be used on a commercial scale. 

Researchers are working to improve the efficiency and economics of the ethanol production process by 

focusing their efforts on the two most challenging steps: 

• Cellulose Hydrolysis. The crystalline structure of cellulose makes it difficult to hydrolyze to 

simple sugars, ready for fermentation. Researchers are developing enzymes that work together 

to efficiently break down cellulose. 

• Pentose Fermentation. While there are a variety of yeast and bacteria that will ferment sixcarbon sugars, most cannot easily ferment five-carbon sugars, which limits ethanol production 

from cellulosic biomass. Researchers are using genetic engineering to design microorganisms 

that can efficiently ferment both five- and six-carbon sugars to ethanol at the same time. 

Source: 

Renewable Fuels Association, http://www.ethanolrfa.org/resource/made/ and the Department of Energy, 

Energy Efficiency and Renewable Energy, 

http://www1.eere.energy.gov/biomass/abcs_biofuels.html 
34 

Biomass Energy Data Book: Edition 1 

Table 2.11 

Ethanol-Blended Fuel Use by State, 2004 

State

Alabama 313,837

Alaska 3,209

Arizona — 

Arkansas — 

California 15,779,408

Colorado 840,135

Connecticut 1,590,629

Delaware — 

Dist. of Col. — 

Florida 552

Georgia — 

Hawaii — 

Idaho — 

Illinois 4,215,207

Indiana 1,480,385

Iowa 1,167,313

Kansas 43,295

Kentucky 302,696

Louisiana 1,793

Maine — 

Maryland 3,033

Massachusetts — 

Michigan — 

Minnesota 2,766,931

Mississippi — 

Missouri 1,220,178

Montana 18,898

Nebraska 371,983

Nevada 466,421

New Hampshire — 

New Jersey — 

New Mexico 64,975

New York — 

North Carolina 1,795

North Dakota 105,022

Ohio 1,916,299

Oklahoma — 

Oregon — 

Pennsylvania — 

Rhode Island — 

South Carolina — 

South Dakota 239,001

Tennessee — 

Texas 332,940

Utah — 

Vermont — 

Virginia 32

Washington 4,785

West Virginia 12,660

Wisconsin 1,085,639

Wyoming — 

U.S. Total 34,349,052

Thousands of gallons

Source: 

Renewable Fuels Association, 

http://www.ethanolrfa.org/industry/outlook/index.php, 

"From Niche to Nation: Ethanol Industry Outlook 2006." 
 35

Biomass Energy Data Book: Edition 1 

While the current production cost for gasoline is significantly less than for ethanol, gasoline production 

cost is projected to increase over time. Production cost for ethanol is projected to decrease over time. 

Table 2.12 

Gasoline and Ethanol: Comparison of Current and Potential 

Production Costs in North America 

(U.S. dollars per gasoline-equivalent liter) 

2002 2010 Post-2010

Gasoline $0.21 $0.23 $0.25

Ethanol from corn $0.43 $0.40 $0.37

Ethanol from cellulose (poplar) $0.53 $0.43 $0.27

Source: 

International Energy Agency, Biofuels for Transport, Table 4.6 

Note: Gasoline gate cost based on $24/barrel oil in 2002, $30/barrel in 2020; corn ethanol from IEA, with 

about 1% per year cost reduction in future; cellulosic costs from IEA based on NREL estimates. 
36 

Biomass Energy Data Book: Edition 1 

Twenty-one ethanol dry mill processing plants contributed to the survey results reported here. The costs 

reported are 2002 dollars. 

Table 2.13 

Undenatured Ethanol Cash Operating Expenses and Net Feedstock Costs for 

Dry-milling Process by Plant Size, 2002 

Source: 

Shapouri, H. and Gallagher, P. 2005. USDA’s Ethanol Cost of Production Survey. U.S. Department of 

Agriculture, Agricultural Economic Report Number 841. July 2005. 

Note: 

 bu – bushels 

 gal – gallons 

 dol – dollars 

Feedstock Unit All Dry Mills Small Large

Corn 1,000 bu 193,185 103,213 89,972

Sorghum 1,000 bu 10,409 NA 10,409

Other 1,000 ton 44.9 NA 44.9

Alcohol production: 

Fuel 1,000 gal 548,684 275,900 272,784

Industrial 1,000 gal 1,000 1,000 

Total 1,000 gal 549,684 276,900 272,784

Ethanol yield Gal/bu 2.6623 2.6828 2.649

Feedstock costs Dol/gal 0.8030 0.7965 0.8095

Byproducts credits: 

Distiller’s dried grains Dol/gal 0.2520 0.2433 0.261

Carbon dioxide Dol/gal 0.0060 0.0038 0.008

Net feedstock costs Dol/gal 0.5450 0.5494 0.5405

Cash operating expenses: 

Electricity Dol/gal 0.0374 0.04 0.0349

Fuels Dol/gal 0.1355 0.1607 0.1099

Waste management Dol/gal 0.0059 0.0077 0.0041

Water Dol/gal 0.0030 0.0044 0.0015

Enzymes Dol/gal 0.0366 0.0377 0.0365

Yeast Dol/gal 0.0043 0.0039 0.0046

Chemicals Dol/gal 0.0229 0.0231 0.0228

Denaturant Dol/gal 0.0348 0.0356 0.0339

Maintenance Dol/gal 0.0396 0.0319 0.0474

Labor Dol/gal 0.0544 0.0609 0.0478

Administrative costs Dol/gal 0.0341 0.0357 0.0325

Other Dol/gal 0.0039 0.0035 0.0043

Total Dol/gal 0.4124 0.4451 0.3802

0.9207

Total cash costs and net 

feedstock costs Dol/gal 0.9574 0.9945
 37

Biomass Energy Data Book: Edition 1 

The ethanol industry spent nearly $5.3 billion in 2004 to produce ethanol. Most of this spending was for 

corn grain, followed by new plant construction. These expenditures created an estimated $15.3 billion in 

additional output in the U.S. economy, increased household earnings by nearly $3.9 billion, and created 

over 143,000 jobs. 

Table 2.14 

Economic Contribution of the Ethanol Industry, 2004 

2004

Expenditure Output Earnings Employment 

(Mil $) (Mil $) (Mil $) (Jobs) 

Corn $3,175.90 $8,759.50 $2,054.50 89,263

Chemicals $279.50 $844.10 $201.00 4,967

Electricity $276.50 $645.80 $142.80 3,546

Natural Gas $311.50 $1,034.30 $179.90 4,607

Water $26.60 $78.90 $21.00 608

Labor $46.30 $129.20 $42.50 1,243

Maintenance $166.70 $528.70 $167.00 5,262

Insurance $94.10 $270.60 $94.30 3,046

Overhead $205.10 $688.70 $264.10 8,988

Subtotal $4,582.20 $12,979.80 $3,166.90 121,530

Construction $700.00 $2,351.00 $712.20 21,826

Total $5,282.20 $15,330.70 $3,879.10 143,356

2004 Impact 

Source: 

John M. Urbanchuk, Director, LECG LLC, 1255 Drummers Lane, Suite 320, Wayne, PA 19087, 

www.lecg.com
38 

Biomass Energy Data Book: Edition 1 

Figure 2.5 

Ethanol Net Energy Balances and Greenhouse Gas Emissions 

The net energy balance and greenhouse gas emissions associated with ethanol production have been 

analyzed by multiple groups in the past 5 years. Some analysts have shown negative energy input to 

output balances while others have shown neutral to positive balances. Greenhouse gas emission 

estimates have also varied accordingly. Some differences can be explained by use of older versus new 

data, by inclusion or exclusion of co-products and by use of different system boundaries. Alexander 

Farrell and others in the Energy and Resources Group at the University of California, Berkeley, recently 

developed a Biofuel Analysis MetaModel (EBAMM) as a new analyses tool. The group first replicated the 

results of six published studies with EBAMM then adjusted all six analyses to (a) add coproduct credit 

where needed, (b) apply a consistent system boundary, (c) account for different energy types, and (d) 

calculate policy relevant metrics. 

The results shown below in figures A & B show the original and adjusted values for the six studies, 

EBAMM generated values for 3 cases including CO2 intensive ethanol, ethanol today, and cellulosic 

ethanol, and a gasoline comparison. Adjusting system boundaries reduces scatter in the results. All 

studies show that ethanol made from conventionally grown corn can have greenhouse gas emissions that 

are slightly more or less than gasoline per unit of energy but that conventional corn ethanol requires much 

less petroleum inputs. The model suggests that ethanol produced from cellulosic materials reduces both 

GHG’s and petroleum inputs substantially. 

Source: 

A.E. Farrell, R.J. Plevin, B.T. Turner, A.D. Jones, M. O’Hare, D.M. kammen, 2006. Ethanol Can 

Contribute To Energy and Environmental Goals. Science, Vol. 311, January 27, 2006. 

Additional references: 

T. Patzek. Crit. Rev. Plant Science, 23, 519 (2004) 

D. Pimentel, T. Patzek, Nat. Resource Res. 14, 65(2005) 

M.E.D. de Olivera, B.E. Vaughn, E.J. Rykiel, Bioscience, 55, 593(2005) 

H. Shappouri, A. McAloon, ”The 2001 Net Energy Balance of Corn Ethanol,” (U.S. Department of 

Agriculture, Washington, DC, 2004). 

M. Graboski, “Fossil Energy Use in the Manufacture of Corn Ethanol,” (National Corn Growers 

Association, Washington, DC, 2002). www.ncga.com/ethanol/main

M. Wang, “Development and Use of GREET 1.6 Fuel-Cycle Model for Transportation Fuels and Vehicle 

Technologies,” (Tech. Rep. ANL/ESD/TM-163, Argonne National laboratory, Argonne, IL, 2001). 

http://www.transportation.anl.gov/pdfs/TA/153.pdf
 39

Biomass Energy Data Book: Edition 1 

Figure 2.6 

Comparisons of Energy Inputs and GHG Emissions for Three Ethanol Scenarios and Gasoline 

The graphic above was developed by the Energy and Resources group at the University of California, 

Berkeley using their Biofuel Analysis MetaModel. It is comparing the intensity of primary energy inputs 

(MJ) per MJ of fuel produced (ethanol or gasoline) and of net greenhouse gas emissions (kg CO2 –

equivalent) per MJ. For gasoline both petroleum feedstock and petroleum energy inputs are included. 

“Other” includes nuclear and hydroelectric generation. The Ethanol Today case includes typical values 

for the current U.S. corn ethanol industry. The CO2 intensive case assumes the ethanol is produced in a 

lignite-fired biorefinery located far from where the corn is grown. The Cellulosic case assumes ethanol is 

produced from switchgrassgrown locally. Cellulosic ethanol is expected to have an extremely low 

intensity for all fossil fuels and a very slightly negative coal intensity due to electricity sales that would 

displace coal. 

Source: 

A.E. Farrell, R.J. Plevin, B.T. Turner, A.D. Jones, M. O’Hare, D.M. Kammen, 2006. Ethanol Can 

Contribute To Energy and Environmental Goals. Science, Vol 311, January 27, 2006, 

www.science.org
40 

Biomass Energy Data Book: Edition 1 

Figure 2.5 includes a data point from M. Wang based on use of the GREET (Greenhouse gases, 

Regulated Emissions, and Energy Use in Transportation) model. This page provides more information 

about this public domain model that is available at: 

http://www.transportation.anl.gov/software/GREET/index.html 

Figure 2.7 

Comparative Results between Ethanol and Gasoline Based on an Evaluation by the GREET Model 
 41

Biomass Energy Data Book: Edition 1 

Figure 2.7 (Continued) 

Comparative Results between Ethanol and Gasoline Based on an Evaluation by the GREET Model 

Sources: 

Figures: Michael Wang "The Debate on Energy and Greenhouse Gas Emissions Impacts of Fuel 

Ethanol", Energy Systems Division Seminar Argonne National Laboratory August 3, 2005. Text: 

Argonne National Laboratory, Transportation Technology R&D Center, 

 http://www.transportation.anl.gov/software/GREET/index.html. 
42 

Biomass Energy Data Book: Edition 1 

Figure 2.7 (Continued) 

Comparative Results between Ethanol and Gasoline Based on an Evaluation by the GREET Model 

The GREET model was developed by Argonne National Laboratory under the sponsorship of the U.S. 

Department of Energy’s Office of Energy Efficiency and Renewable Energy in order to fully evaluate 

energy and emission impacts of advanced vehicle technologies and new transportation fuels. The first 

version of this public domain model was released in 1996. Since then, Argonne has continued to update 

and expand the model with GREET 1.7 version now available. The model allows researchers and 

analysts to evaluate various vehicle and fuel combinations on a full fuel-cycle basis that includes wells to 

wheels and the vehicle cycle through material recovery and vehicle disposal. 

For a given vehicle and fuel system, GREET separately calculates the following: 

• Consumption of total energy (energy in non-renewable and renewable sources) and fossil fuels 

(petroleum, natural gas, and coal). 

• Emissions of CO2-equivalent greenhouse gases – primarily carbon dioxide, methane, and nitrous 

oxide. 

• Emissions of five criteria pollutants: volatile organic oxide, particulate matter with size smaller than 

10 micron (PM10), and sulfur oxides. 

GREET includes more than 30 fuel-cycle pathway groups and the following vehicle technologies: 

• Conventional spark-ignition engines 

• Direct injection, compression ignition engines 

• Grid-connected hybrid electric vehicles 

• Grid-independent hybrid electric vehicles 

• Battery-powered electric vehicles 

• Fuel-cell vehicles 
 43

Biomass Energy Data Book: Edition 1 

Table 2.15 

Comparison of Ethanol Energy Balance with and Without Inclusion 

of Coproduct Energy Credits

Tables A and B, from a paper by H. Shapouri and A. McAloon, show the effects of partitioning the energy 

inputs to coproducts as well as to the ethanol produced at wet and dry mills. 

Table A summarizes the input energy requirements, by phase of ethanol production on a Btu per gallon 

basis (LHV) for 2001, without byproduct credits. Energy estimates are provided for both dry- and wetmilling as well as industry average. In each case, corn ethanol has a positive energy balance, even 

before subtracting the energy allocated to byproducts. 

Table B presents the final net energy balance of corn ethanol adjusted for byproducts. The net energy 

balance estimate for corn ethanol produced from wet-milling is 27,729 Btu per gallon, the net energy 

balance estimate for dry-milling is 33,196 Btu per gallon, and the weighted average is 30,528 Btu per 

gallon. The energy ratio is 1.57 and 1.77 for wet- and dry-milling, respectively, and the weighted average 

energy ratio is 1.67. 

Production Process Dry Wet Production Process Dry Wet

 Corn production 18,875 18,551 18,713 Corn production 12,457 12,244 12,350

 Corn transport 2,138 2,101 2,120 Corn transport 1,411 1,387 1,399

 Ethanol conversion 47,116 52,349 49,733 Ethanol conversion 27,799 33,503 30,586

 ethanol distribution 1,487 1,487 1,487 ethanol distribution 1,467 1,467 1,467

 Total energy used 69,616 74,488 72,052 Total energy used 43,134 48,601 45,802

 Net energy value 6,714 1,842 4,278 Net energy value 33,196 27,729 30,528

 Energy ratio 1.10 1.02 1.06 Energy ratio 1.77 1.57 1.67

Table A Table B

Weighted 

average

Milling Process Weighted 

average

Milling process

Energy Use and Net Energy Value Per Gallon Without 

Coproduct Energy Credits, 2001

Energy Use and Net Energy Value Per Gallon with 

Coproduct Energy Credits, 2001

Btu per gallon Btu per gallon

Source: 

H. Shappouri, A. McAloon, ”The 2001 Net Energy Balance of Corn Ethanol,” (U.S. Department of 

Agriculture, Washington, DC, 2004). 
44 

Biomass Energy Data Book: Edition 1 

These states offer extra incentives for ethanol production or consumption (gasohol or E85). Details on 

these incentives can be found at www.eere.energy.gov/cleancities/vbg/ progs/laws.cgi

Table 2.16 

State Ethanol Incentives, 2005 

State Producer incentives State tax incentives Other incentives

Illinois

Iowa

Kansas

Maine

Maryland

Minnesota

Mississippi

Missouri

Nebraska

New Jersey

New Mexico

Pennsylvania

 Source: 

U.S. Department of Energy, Vehicle Buyer’s Guide for Consumers, State and Federal Laws and 

Incentives, www.eere.energy.gov/cleancities/vbg/progs/laws.cgi
 45

Biomass Energy Data Book: Edition 1 

BIODIESEL 

Biodiesel Overview

Biodiesel is a clean burning alternative fuel produced from domestic, renewable resources. The fuel is a 

mixture of fatty acid alkyl esters made from vegetable oils, animal fats or recycled greases. Where 

available, biodiesel can be used in compression-ignition (diesel) engines in its pure form with little or no 

modifications. Biodiesel is simple to use, biodegradable, nontoxic, and essentially free of sulfur and 

aromatics. It is usually used as a petroleum diesel additive to reduce levels of particulates, carbon 

monoxide, hydrocarbons and air toxics from diesel-powered vehicles. When used as an additive, the 

resulting diesel fuel may be called B5, B10 or B20, representing the percentage of the biodiesel that is 

blended with petroleum diesel. 

 

In the United States, most biodiesel is made from soybean oil or recycled cooking oils. Animal fats, other 

vegetable oils, and other recycled oils can also be used to produce biodiesel, depending on their costs 

and availability. In the future, blends of all kinds of fats and oils may be used to produce biodiesel. 

Biodiesel is made through a chemical process called transesterification whereby the glycerin is separated 

from the fat or vegetable oil. The process leaves behind two products -- methyl esters (the chemical name 

for biodiesel) and glycerin (a valuable byproduct usually sold to be used in soaps and other products). 

Fuel-grade biodiesel must be produced to strict industry specifications (ASTM D6751) in order to insure 

proper performance. Biodiesel is the only alternative fuel to have fully completed the health effects testing 

requirements of the 1990 Clean Air Act Amendments. Biodiesel that meets ASTM D6751 and is legally 

registered with the Environmental Protection Agency is a legal motor fuel for sale and distribution. Raw 

vegetable oil cannot meet biodiesel fuel specifications; therefore, it is not registered with the EPA and it is 

not a legal motor fuel. 

Source: 

U.S. Department of Energy, Energy Efficiency and Renewable Energy, 

http://www.eere.energy.gov/RE/bio_fuels.html and the National Biodiesel Board, 

http://www.biodiesel.org/resources/biodiesel_basics/default.shtm
46 

Biomass Energy Data Book: Edition 1 

During 2002, Europe, in general, and particularly the EU countries of Germany, France and Italy, were 

the dominant producers of biodiesel worldwide. 

Table 2.17 

World Biodiesel Capacity, 2002 

(million gallons) 

Country Capacitya Typical use

United States 18.49 blends <25%

IEA North America 18.49

Austria 8.45 blends <25%

Belgium 9.51

Denmark 0.79

France 101.97 mainly 5%

Germany 165.11 100% biodiesel; some blends

Italy 63.14 blends <25%

Spain 2.38

Sweeden 4.49 blends <25%

UK 1.59

EU 357.42

Poland 21.13

IEA Europe 378.56

World 397.05

Source: 

International Energy Agency "Biofuels For Transport: An International 

Perspective," page 30, Table 1.1, May 2004. 

Note: Production of biodiesel in 2003 is roughly 65% of capacity. Some 

minor production (e.g. India, Africa) not reported. 

_______________________ 

a Feedstock in the United States is soy; in Europe, rapeseed and 

sunflower. 
 47

Biomass Energy Data Book: Edition 1 

The geographic distribution of biodiesel production facilities is wide ranging, covering all regions of the 

United States. 

Table 2.18 

Active Biodiesel Production Facilities, 2005 

Company City State 

Bean Commercial Grease Belgrade ME 

Soymor Glenville MN 

Channel Chemical Corporation Gulfport MS 

SeQuential Biofuels Salem OR 

American Bio-Fuels LLC Bakersfield CA 

Bio-Energy Systems, LLC Vallejo CA 

Imperial Western Products Coachella CA 

Procter and Gamble Sacramento CA 

Bio Energy of Colorado Denver CO 

Rocky Mountain Biodiesel Industries Berthoud CO 

Purada Processing, LLC Lakeland FL 

Peach State Labs Rome GA 

US Biofuels Inc. Rome GA 

Pacific Biodiesel Kahului HI 

Pacific Biodiesel Honolulu HI 

Ag Processing, Inc Sergeant Bluff IA 

Mid-States Biodiesel Nevada IA 

Soy Solutions Milford IA 

West Central Ralston IA 

Stepan Company Millsdale IL 

Griffin Industries Butler KY 

FUMPA BioFuels Redwood Falls MN 

Minnesota Soybean Processors Brewster MN 

Missouri Better Bean Bunceton MO 

Biodiesel of Mississippi, Inc. Nettleton MS 

Earth Biofuels Meridan MS 

Earthship Biodiesel, LLC Taos NM 

Biodiesel Industries Las Vegas NV 

Biodiesel of Las Vegas Las Vegas NV 

Environmental Alternatives Brooklyn NY 

American Ag Fuels, LLC Defiance OH 

Peter Cremer (TRI-NI) Cincinnati OH 

Green Country Biodiesel, Inc Claremore OK 

Blue Sky Biodiesel Wartburg TN 

Biodiesel Industries of Greater Dallas-Fort Worth Denton TX 

Corsicana Technologies, Inc. Corsicana TX 

Huish Detergents Pasadena TX 

Johann Haltermann, LTD Houston TX 

SMS Envirofuels Poteet TX 

South Texas Blending Laredo TX 

Sun Cotton Biofuels Roaring Springs TX 

Texoga Technologies Oak Ridge TX 

Virginia Biodiesel Refinery New Kent VA 

Seattle Biodiesel, LLC Seattle WA 

Renewable Alternatives Howard WI 

Source: 

National Biodiesel Board, http://www.biodiesel.org/resources/fuelfactsheets/default.shtm, Under 

 Production, "Existing Plants - Production Map & Table." 
48 

Biomass Energy Data Book: Edition 1 

Table 2.19 

Proposed Biodiesel Production Facilities, 2005 

Company City State 

Alabama Biodiesel Corporation Moundville AL 

EarthFirst Americas Mobile AL 

Grecycle Arizona, LLC Tucson AZ 

Baker Commodities Las Angeles CA 

Bay Biodiesel, LLC Martinez CA 

Simple Fuels, LLC Vinton CA 

Blue Sun Biodiesel Alamosa CO 

Mid-Atlantic Biodiesel Clayton DE 

Renewable Energy System Pinellas Park FL 

Biomass Energy Services Brunswick GA 

Baker Commodities Honolulu HI 

Cargill Iowa Falls IA 

Clinton County BioEnergy Clinton IA 

Western Iowa Energy Wall Lake IA 

Chicago Biodiesel Chicago IL 

Integrity Biofuels Morristown IN 

Louis Dreyfus Claypool IN 

Union County Biodiesel Company, LLC Morganfield KY 

Baker Commodities Billerica MA 

Northeast Biodiesel Co. Greenfield MA 

Ag Solutions Gladstone MI 

Michigan Biofuels, LLC Belleville MI 

Green Range Renewable Energy Ironton MN 

Mid America Biofuels Mexico MO 

Missouri Biofuels Bethel MO 

Prairie Pride Butler MO 

Earth Biofuels, Inc. Jackson MS 

Sustainable Systems, LLC Culbertson MT 

Atlantic Bioenergy, LLC Mount Olive NC 

Blue Ridge Biofuels Ashville NC 

Filter Specialty Bioenergy, LLC Autryville NC 

North Dakota Biodiesel, Inc Minot ND 

NextGen Fuel, Inc Fulton NY 

Jatrodiesel Inc. Dayton OH 

Best Energy Solutions, LLC Tulsa OK 

Earth Biofuels, Inc. Durant OK 

SeQuential Biofuels Portland OR 

Agra Biofuels Middletown PA 

BioPreserve Erie PA 

Duff Science Co. Howard PA 

Keystone BioFuels, Inc. Shiremanstown PA 

Three Rivers Biofuels Neville Island PA 

United Biofuels, Inc. York PA 

Agri-Energy, Inc Louisburg TN 

AMPM Environmental Services Moscow TN 

Biodiesel of Mississippi McMinnville TN 

Central Texas Biofuels Giddings TX 

New Fuel Company Dallas TX 

NFE Biofuel & Energy, Inc. Houston TX 

Organic Fuels, LLC Houston TX 

Smithfield Biofuels, LLC Cleburne TX 

Renroh Environmental Company South Boston VA 

Baker Commodities Seattle WA 

Energy Fuel Dynamics, LLC Gillette WY 

Source: 

http://www.biodiesel.org/buyingbiodiesel/producers_marketers/ProducersMap-existingandpotential.pdf 
 49

Biomass Energy Data Book: Edition 1 

Figure 2.8 

Active and Proposed Biodiesel Production Facilities, 2005

Source: 

http://www.biodiesel.org/buyingbiodiesel/producers_marketers/ProducersMap-existingandpotential.pdf 
50 

Biomass Energy Data Book: Edition 1 

Production of biodiesel has grown since 1999, but the most notable growth was in 2005 when production 

tripled to 75 million gallons. 

Figure 2.9 

Estimated U.S. Biodiesel Production, 1999-2005

0.5 2.0

5.0

15.0

20.0

25.0

75.0

0.0

10.0

20.0

30.0

40.0

50.0

60.0

70.0

80.0

1999 2000 2001 2002 2003 2004 2005

Million Gallons

Source: 

National Biodiesel Board, Biodiesel Fact Sheets, Production Capacity, 

http://www.biodiesel.org/resources/fuelfactsheets/default.shtm
 51

Biomass Energy Data Book: Edition 1 

It is extremely important to realize that vegetable oils are mixtures of tryglycerides from various fatty 

acids. The composition of vegetable oils varies with the plant source. The table below indicates the 

percentages of each type of fatty acid that is in common vegetable oils or animal fats. The two numbers 

at the top of each column represents the number of carbon atoms and double bonds (e.g. 16:0 refers to 

the 16 carbon atoms and 0 double bonds found in the long chain of Palmitic acid). See text on Typical 

Proportions of Chemicals Used to Make Biodiesel (Figure 2.10) for a description of several types of 

tryglycerides that are found in vegetable oils. 

Table 2.20 

Composition of Various Oils and Fats Used for Biodiesel 

(Percentage of each type of fatty acid common to each type of feedstock) 

Oil or fat 14:00 16:00 18:00 18:01 18:02 18:03 20:00 22:01

Soybean 6-10 2-5 20-30 50-60 5-11

Corn 1-2 8-12 2-5 19-49 34-52 trace

Peanut 8-9 2-3 50-60 20-30

Olive 9-10 2-3 73-84 10-12 trace

Cottonseed 0-2 20-25 1-2 23-35 40-50 trace

Hi Linoleic 

Safflower

5.9 1.5 8.8 83.8

Hi Oleic 

Safflower

4.8 1.4 74.1 19.7

Hi Oleic 

Rapeseed

4.3 1.3 59.9 21.1 13.2

Hi Erucic 

Rapeseed

3.0 0.8 13.1 14.1 9.7 7.4 50.7

Butter 7-10 24-26 10-13 28-31 1-2.5 .2-.5

Lard 1-2 28-30 12-18 40-50 7-13 0-1

Tallow 3-6 24-32 20-25 37-43 2-3

Linseed Oil 4-7 2-4 25-40 35-40 25-60

2.43 23.24 12.96 44.32 6.97 0.67

16:1=3.

Yellow 

grease 

(typical)

Source: 

Adapted from: J. Van Gerpen, B. Shanks, and R. Pruszko, D. Clements, and G. Knothe, 2004, “Biodiesel 

Production Technology,” National Renewable Energy Laboratory subcontractor report NREL/SR510-36244, chapter 1, page 1. Please see this document for a full discussion. Available on-line in 

DOE’s biomass document database. Search by author or title. 

http://www1.eere.energy.gov/biomass/document_database.html. 
52 

Biomass Energy Data Book: Edition 1 

Figure 2.10 

Typical Proportions of Chemicals Used to Make Biodiesel 

The most cursory look at the literature relating to biodiesel reveals the following relationship for 

production of biodiesel from fats and oils: 100 lbs of oil + 10 lbs of methanol 	




lbs of glycerol - This equation is a simplified form of the following transesterfication reaction: 

R1, R2, and R3 in the above equation are long chains of carbons and hydrogen atoms, sometimes called 

fatty acid chains. There are five types of chains that are common in soybean oil and animal fats shown 

below (others are present in small amounts). 

As indicated, a short-hand designation for these chains is two numbers separated by a colon. The first 

number designates the number of carbon atoms in the chain and the second number designates the 

number of double bonds. Note that the number of carbon atoms includes the carbon that is double 

bonded to the oxygen atom at one end of the fatty acid (called the carboxylic carbon). This is the end that 

the methanol attaches to when methyl ester is produced. 

Source: 

Reproduced from: J. Van Gerpen, B. Shanks, and R. Pruszko, D. Clements, and G. Knothe, 2004. 

Biodiesel Production Technology. National Renewable Energy Laboratory subcontractor report 

NREL/SR-510-36244; Chapter 1, page 1. 

Available on-line in DOE’s biomass document database. Search by author or title. 

http://www1.eere.energy.gov/biomass/document_database.html
 53

Biomass Energy Data Book: Edition 1 

The parameters for B100 fuel are specified through the biodiesel standard, ASTM D 6751. This standard 

identifies the parameters that pure biodiesel (B100) must meet before being used as a pure fuel or being 

blended with petrodiesel. The National Biodiesel Board has adopted ASTM biodiesel specifications. 

Table 2.21 

Specification for Biodiesel (B100) 

Property ASTM Method Limits Units 

Flash Point D93 130 min. Degrees C 

Water & Sediment D2709 0.050 max. % vol. 

Kinematic Viscosity, 40 C D445 1.9 - 6.0 mm2/sec. 

Sulfated Ash D874 0.020 max. % mass 

Sulfur D5453 0.05 max. % mass 

Copper Strip Corrosion D130 No. 3 max. 

Cetane D613 47 min. 

Cloud Point D2500 Report Degrees C 

Carbon Residue 100% sample D4530a 0.050 max. % mass 

Acid Number D664 0.80 max. mg KOH/gm 

Free Glycerin D6584 0.020 max. % mass 

Total Glycerin D6584 0.240 max. % mass 

Phosphorus Content D 4951 0.001 max. % mass

Distillation Temp, Atmospheric 

Equivalent Temperature, 90% 

Recovered D 1160 360 max. Degrees C 

Source: 

National Biodiesel Board, Biodiesel Fact Sheets, Biodiesel Production & Quality Standards. 

Notes: 

1. To meet special operating conditions, modifications of individual limiting requirements may be agreed 

upon between purchaser, seller and manufacturer. 

2. A considerable amount of experience exists in the US with a 20% blend of biodiesel with 80% diesel 

fuel (B20). Although biodiesel (B100) can be used, blends of over 20% biodiesel with diesel fuel 

should be evaluated on a case-by-case basis until further experience is available. 

Alternate source providing explanations for the various specifications can be found at: 

J. Van Gerpen, B. Shanks, and R. Pruszko, D. Clements, and G. Knothe, 2004. Biodiesel Production 

Technology. National Renewable Energy Laboratory subcontractor report NREL/SR-510-36244; 

Chapter 1, page 23. Available on-line in DOE’s biomass document database. Search by author or 

title. http://www1.eere.energy.gov/biomass/document_database.html

_______________________ 

a

 The carbon residue shall be run on the 100% sample. 
54 

Biomass Energy Data Book: Edition 1 

Figure 2.11 

Commercial Biodiesel Production Methods 

The production processes for biodiesel are well known. There are three basic routes to biodiesel 

production from oils and fats: 

 1. Base catalyzed transesterification of the oil. 

 2. Direct acid catalyzed transesterification of the oil. 

 3. Conversion of the oil to its fatty acids and then to biodiesel. 

Most of the biodiesel produced today uses the base catalyzed reaction for several reasons: 

• It is low temperature and pressure. 

• It yields high conversion (98%) with minimal side reactions and reaction time. 

• It is a direct conversion to biodiesel with no intermediate compounds. 

• No exotic materials of construction are needed. 

The chemical reaction for base catalyzed biodiesel production is depicted below. One hundred pounds of 

fat or oil (such as soybean oil) are reacted with 10 pounds of a short chain alcohol in the presence of a 

catalyst to produce 10 pounds of glycerin and 100 pounds of biodiesel. The short chain alcohol, signified 

by ROH (usually methanol, but sometimes ethanol) is charged in excess to assist in quick conversion. 

The catalyst is usually sodium or potassium hydroxide that has already been mixed with the methanol. R’, 

R’’, and R’’’ indicate the fatty acid chains associated with the oil or fat which are largely palmitic, stearic, 

oleic, and linoleic acids for naturally occurring oils and fats. 

Source: 

National Biodiesel Board, Fact Sheet "Biodiesel Production and Quality," 

http://www.biodiesel.org/resources/fuelfactsheets/default.shtm

Note: The term glycerin may include glycerol and related co-products of the glycerol production process.
 55

Biomass Energy Data Book: Edition 1 

The results of a study conducted by the EPA on the emissions produced by biodiesel show that except 

for nitrogen oxides (NOx), regulated and non regulated emissions from both B100 (100% biodiesel) and 

B20 (20% biodiesel) are significantly lower than for conventional petroleum based diesel. 

Table 2.22 

Average Biodiesel (B100 and B20) Emissions Compared to Conventional Diesel 

Emission Type B100 B20 

Regulated 

 Total Unburned Hydrocarbons -67% -20%

 Carbon Monoxide -48% -12%

 Particulate Matter -47% -12%

Nox +10% +2%

Non-Regulated 

 Sulfates -100% -20%a 

 PAH (Polycyclic Aromatic Hydrocarbons)

b -80% -13%

 nPAH (nitrated PAH’s)b -90% -50%c 

 Ozone potential of speciated HC -50% -10%

Emissions in relation to conventional diesel

Source: 

National Biodiesel Board, Biodiesel Fact Sheets, Emissions. 

Note: Testing was performed by the EPA. The full report titled "A Comprehensive Analysis of Biodiesel 

Impacts on Exhaust Emissions" can be found at: www.epa.gov/otaq/models/biodsl.htm

B100 is 100% biodiesel while B20 is a blend of 20% biodiesel and 80% conventional petroleum based 

diesel. 

_______________________ 

a

 Estimated from B100 result. 

b

 Average reduction across all compounds measured. 

c

 2-nitroflourine results were within test method variability. 
56 

Biomass Energy Data Book: Edition 1 

The market effects of increased biodiesel production and use in the United States would likely drive up 

the price of soybean oil while driving down the price for soybean meal used in livestock feed. The overall 

net impact on farm incomes is estimated to be an increase of about 0.3%. 

Table 2.23 

Estimated Impacts from Increased Use of Biodiesel 

Low Medium High

Soybean oil production 0.3 0.8 1.6

Soybean oil price 2.8 7.2 14.1

Soybean meal price –0.7 –1.7 –3.3 

Soybean price 0.4 1 2

Livestock price (“broilers”) –0.3 –0.7 –1.4 

US net farm income 0.1 0.2 0.3

Market scenario (percentage change from baseline)

Source: 

International Energy Agency "Biofuels for Transport: An International Perspective," Page 96, Table 4.12. 
 57

Biomass Energy Data Book: Edition 1 

BioOil Overview

A totally different process than that used to produce biodiesel can be used to convert biomass into a type 

of fuel similar to diesel known as BioOil. The process, called fast or flash pyrolysis, occurs when heating 

compact solid fuels at temperatures between 350 and 500 degrees Celsius for a very short period of time 

(less than 2 seconds). While there are several fast pyrolysis technologies under development, there are 

only two commercial fast pyrolysis technologies as of 2006. The BioOils currently produced are suitable 

for use in boilers for electricity generation. Additional research and development is needed to produce 

BioOil of sufficient quality for transportation applications. 

DynaMotive Energy Systems is commercializing a proprietary fast pyrolysis process that converts forest 

and agricultural residue into liquid BioOil and char. The company launched the first BioOil cogeneration 

facility in West Lorn, Ontario, in collaboration with Erie Flooring and Wood Products Company. The 

flooring company provides the wood residue and DynaMotive’s 2.5 megawatt plant uses its fast pyrolysis 

technology and a gas turbine to supply power to the wood product’s mills and lumber kilns. DynaMotive is 

now in the process of building a second 200 ton-per-day plant in Western Canada.

Ensyn Group Inc. has commercialized a fast pyrolysis technology under the name of Rapid Thermal 

Processing RTP[tm]. This technology is based on the biomass refining concept, where value added 

chemicals are produced in addition to a consistent quality BioOil. Ensyn has four RTP[tm] facilities in 

commercial operation; a new facility and a BioOil refining plant are currently under construction. Three of 

the commercial facilities are in Wisconsin and one is in Ottawa, Canada. The largest of these facilities, 

built in 1996, processes about 75 green tons per day of mixed hardwood wastes. Ensyn currently 

produces about 30 chemicals products from RTP[tm] BioOil with lower value remnant BioOil used for 

energy. Ensyn is just beginning to enter the energy market.

Sources: DynaMotive Energy Systems Corporation, http://www.dynamotive.com/; Ensyn Group Inc. 

http://www.ensyn.com/
58 

Biomass Energy Data Book: Edition 1 

BioOils are being commercially produced in North America by only two companies as of 2006—Ensyn 

Group, Inc, and DynaMotive Energy Systems. BioOil has many of the advantages of petroleum fuels 

since it can be stored, pumped and transported. It is currently being combusted directly in boilers, gas 

turbines, and slow and medium speed diesels for heat and power applications. 

Figure 2.12 

A Fast Pyrolysis Process for Making BioOil 

Source: 

http://www.dynamotive.com/biooil/technology.html 

Information from DynaMotive’s website describes the process as follows. Prepared feedstocks with less 

than 10% moisture content and a 1-2 mm particle size are fed into the bubbling fluid-bed reactor. The 

fluidized bed is heated to 450-500 degrees Celsius in the absence of oxygen. The feedstock flashes and 

vaporizes and the resulting gases pass into a cyclone where solid particles, char, are extracted. The 

gases enter a quench tower where they are quickly cooled using BioOil already made in the process. 

The BioOil condenses and falls into the product tank, while the non-condensable gases are returned to 

the reactor to maintain process heating. The entire reaction from injection to quenching takes only two 

seconds. 

One hundred percent of the feedstock is utilized in the process to produce BioOil and char. The 

characteristics of the BioOil are described in tables found under BioOil in the Biofuels section of this book 

and can also be found at the source listed above. The char that is collected is a high Btu value solid fuel 

that can be used in kilns, boilers and the briquette industry. The non-condensed gases are re-circulated 

to fuel approximately 75% of the energy needed by the pyrolysis process. The relative yields of BioOil, 

char, and non-condensable gases vary depending on feedstock composition. 
 59

Biomass Energy Data Book: Edition 1 

"BioOil is a dark brown, free flowing liquid comprised of highly oxygenated compounds. As a fuel, BioOil 

is considered to be CO2 neutral, and emits no SOx and low NOx when combusted. BioOil density is high 

at 1.2 kgs/litre. Heating value on a weight basis is approximately 40 % to that of diesel. On a volume 

basis the heating value compared to diesel is approximately 55%." –DynaMotive. 

Table 2.24 

BioOil Characteristics 

Pine 53% Spruce 47% 

(including bark) Bagasse

pH 2.4 2.6

Water Content wt% 23.4 20.8

Methanol Insolvable Solids (Lignin content wt%) 24.9 23.5

Solids Content wt% <0.10 <0.10

Ash Content wt% <0.02 <0.02

Density kg/L 1.19 1.2

Low Heating Mj/kg 16.4 15.4

Kinematic Viscosity cSt @ 20o

C 40 50

Kinematic Viscosity cSt @ 80o

C 6 7

Feedstock

BioOil Characteristics

Source: 

DynaMotive, http://www.dynamotive.com/biooil/whatisbiooil.html

Note: wt% =percent by weight. 

The exact composition of BioOil may vary depending on feedstock and processing. The 

table above is based on the fast pyrolysis method using the specific feedstock listed in the 

table. Other companies also produce BioOil though conversion processes and feedstocks 

can vary widely. 
60 

Biomass Energy Data Book: Edition 1 

"BioOil is miscible with alcohols such as ethanol and methanol but is immiscible with hydrocarbons. The 

following table lists the chemical composition of major BioOil constituents." –DynaMotive. 

Table 2.25 

BioOil Composition 

Concentrations wt%

Feedstock: Pine 53% Spruce 47% 

(including bark) Bagasse

Water 23.4 20.8

Methanol Insolvable Solids & Lignin 24.9 23.5

Cellubiosan 1.9 -

Glyoxal 1.9 2.2

Hydroxyacetaldehyde 10.2 10.2

Levoglucosan 6.3 3

Formaldehyde 3 3.4

Formic Acid 3.7 5.7

Acetic Acid 4.2 6.6

Acetol 4.8 5.8

Source: 

DynaMotive, http://www.dynamotive.com/biooil/whatisbiooil.html

Note: wt% =percent by weight. 

The exact composition of BioOil may vary depending on feedstock and processing. The table above 

is based on the fast pyrolysis method using the specific feedstock listed in the table. Other companies 

also produce BioOil though conversion processes and feedstocks can vary widely. 
 61

Biomass Energy Data Book: Edition 1 

"BioOil fuels have unique characteristics that distinguish them from petroleum-based (hydro carbon) 

products. The table below illustrates the primary differences between BioOil and other fuels including light 

and heavy fuel oil." –DynaMotive 

Table 2.26 

BioOil Fuel Comparisons 

BioTherm BioOil Light Fuel Oil Heavy Fuel Oil

Heat of combustion Btu/lb 7,100 18,200 17,600

Heat of combustion MJ/liter 19.5 36.9 39.4

Viscosity (centistokes) 50o

C 7 4 50

Viscosity (centistokes) 80o

C 4 2 41

Ash % by weight <0.02 <0.01 0.03

Sulphur % by weight Trace 0.15 to 0.5 0.5 to 3

Nitrogen % by weight Trace 0 0.3

Pour Point o

C -33 -15 -18

Turbine NOx g/MJ <0.7 1.4 N/A

Turbine SOx g/MJ 0 0.28 N/A

Source: 

DynaMotive, http://www.dynamotive.com/biooil/whatisbiooil.html

Note: N/A = Not available. 

The exact characteristics of BioOil may vary depending on feedstock and processing. The 

table above is based on the fast pyrolysis method using feedstock composed of 53% pine 

and 47% spruce including bark. Other companies also produce BioOil though conversion 

processes and feedstocks can vary widely. 
62 

Biomass Energy Data Book: Edition 1 
 63

Biomass Energy Data Book: Edition 1 

3. BIOPOWER 

BIOMASS POWER OVERVIEW 

Biomass power technologies convert renewable biomass fuels to heat and electricity using processes 

similar to that used with fossil fuels. Next to hydropower, more electricity is generated from biomass than 

any other renewable energy resource in the United States. A key attribute of biomass is its availability 

upon demand - the energy is stored within the biomass until it is needed. Other forms of renewable 

energy are dependent on variable environmental conditions such as wind speed or sunlight intensity. 

Today in parts of the developing world (and until several decades ago in the United States), biomass is 

primarily used to provide heat for cooking and comfort. Technologies have now been developed which 

can generate electricity from the energy in biomass fuels. Biomass technologies are highly scaleable – 

small enough to be used on a farm or in remote villages, or large enough to provide power for a small 

city. 

There are four primary classes of biopower systems: direct-fired, co-fired, gasification, and modular 

systems. Most of today's biopower plants are direct-fired systems that are similar to most fossil-fuel fired 

power plants. The biomass fuel is burned in a boiler to produce high-pressure steam. This steam is 

introduced into a steam turbine, where it flows over a series of aerodynamic turbine blades, causing the 

turbine to rotate. The turbine is connected to an electric generator, so as the steam flow causes the 

turbine to rotate, the electric generator turns and electricity is produced. Biomass power boilers are 

typically in the 20-50 MW range, compared to coal-fired plants in the 100-1500 MW range. The small 

capacity plants tend to be lower in efficiency because of economic trade-offs; efficiency-enhancing 

equipment cannot pay for itself in small plants. Although techniques exist to push biomass steam 

generation efficiency over 40%, actual plant efficiencies are often in the low 20% range. 

Co-firing involves substituting biomass for a portion of coal in an existing power plant furnace. It is the 

most economic near-term option for introducing new biomass power generation. Because much of the 

existing power plant equipment can be used without major modifications, co-firing is far less expensive 

than building a new biopower plant. Compared to the coal it replaces, biomass reduces sulphur dioxide 

(SO2), nitrogen oxides (NOx), and other air emissions. After "tuning" the boiler for peak performance, 

there is little or no loss in efficiency from adding biomass. This allows the energy in biomass to be 

converted to electricity with the high efficiency (in the 33-37% range) of a modern coal-fired power plant. 

Biomass gasifiers operate by heating biomass in an environment where the solid biomass breaks down 

to form a flammable gas. The biogas can be cleaned and filtered to remove problem chemical 

compounds. The gas can be used in more efficient power generation systems called combined-cycles, 

which combine gas turbines and steam turbines to produce electricity. The efficiency of these systems 

can reach 60%. 

Modular systems employ some of the same technologies mentioned above, but on a smaller scale that 

is more applicable to villages, farms, and small industry. These systems are now under development and 

could be most useful in remote areas where biomass is abundant and electricity is scarce. There are 

many opportunities for these systems in developing countries. 

 

Source: 

U.S. Department of Energy, Energy Efficiency and Renewable Energy. 
64 

Biomass Energy Data Book: Edition 1 

Table 3.1 

Biomass Power Technology in Commercial/Demonstration Phase during 2000-2006 

Technology 

Category

Biomass Conversion 

Technology

Primary Energy Form 

Produced

Primary Energy 

Conversion 

Technology

Final Energy 

Products

Direct combustion Stove/Furnace Heat Heat exchanger Hot air, hot water

Direct combustion Pile burners Heat, steam Steam turbine Electricity

Direct combustion Stoker grate boilers Heat, steam Steam turbine Electricity

Direct combustion Suspension boilers: Air 

spreader stoker or cyclonic

Heat, steam Steam turbine Electricity

Direct combustion Fluidized-bed combustor 

FB – bubbling CFBcirculating 

Heat, steam Steam turbine Electricity

Direct combustion Co-firing in coal-fired boilers

(several types)

Heat, steam Steam turbine Electricity

Gasification 

(atmospheric)

updraft, counter current 

fixed bed

Low Btu producer gas Combustion boiler + 

steam generator and 

turbine

Process heat or 

heat plus 

electricity

Gasification 

(atmospheric)

Downdraft, moving bed Low Btu producer gas Spark engine (internal 

combustion) 

Power, electricity

Gasification 

(atmospheric)

Circulating Fluidized Bed 

(CFB) dual vessel

medium Btu producer 

gas

Burn gas in boiler w/ 

Steam Turbine

Electricity

Gasification 

(atmospheric)

Co-firing in CFB gasifiers Low or medium Btu 

producer gas

Burn gas in boiler w/ 

Steam Turbine

Electricity

Pyrolysis Kilns or retorts Charcoal Cook stoves and 

furnaces

Heat

Pyrolysis Pryolysis units (for slow, 

fast or flash pyrolysis)

Synthetic fuel oil , gas 

and charcoal

Diesel engines, 

bioler/turbine, furnace

Power, electricity, 

heat

Anerobic digestion Digesters, landfills Low to medium Btu 

producer gas

Furnace, gas engine, 

gas turbine 

Heat, electricity, 

power

Source: 

Compiled by Lynn Wright, Oak Ridge, TN. 

Note: See Glossary for definitions of terms found under the "Technology Category" column. 

The following references are suggested for further reading: 

Overend, Ralph. 2003. Heat, power and combined heat and power. Chapter 3 in: Sims, R. Bioenergy 

Options for a Cleaner Environment: In Developed and Developing Countries, Elsiver, ISBN: 0-08-

044351-6. 193 pages 

Broek, R. van den, Faaij, A., and van Wijk, J. 1995, Biomass Combustion Power Generation 

Technologies, Study performed within the framework of the extended JOULE-IIA programme of 

CECDGXII, project “Energy from biomass: an assessment of two promising systems for energy 

production”, Department of Science, Technology and Society, Utrech University, Utrecht (Report no. 

95029). Available at website: http://www.chem.uu.nl/nws/www/publica/95029.htm
 65

Biomass Energy Data Book: Edition 1 

Table 3.2 

Biomass Power Technology Fuel Specifications and Capacity Range

Biomass Conversion 

Technology Commonly used fuel typesa

Particle Size 

Requirements

Moisture Content 

Requirements (wet

basis)b

Average capacity range / link to

examples

Stove/Furnace solid wood, pressed logs, wood 

chips and pellets

Limited by stove size 

and opening

10 – 30% 15 kWt to ? 

Pile burners Virtually any kind of wood 

residuesc or agricultural residuesd 

except wood flour

Limited by grate size 

and feed opening

< 65% 4 to 110 MWe 

Pile burner fed with 

underfire stoker (biomass 

fed by auger below bed)

Sawdust, non-stringy bark, 

shavings, chips, hog fuel

0.25-2 in (6-38 mm) 10-30% 4 to 110 MWe

Stoker grate boilers Sawdust, non-stringy bark, 

shavings, end cuts, chips, chip 

rejects, hog fuel 

0.25 – 2 in (6 -50 mm) 10-50% (keep 

within 10% of design 

rate) 

20 to 300 Mwe many in 20 to 50 

MWe range

Suspension boilers Cyclonic Sawdust. Non-stringy bark, 

shavings, flour, sander dust

0.25 in (6 mm) max < 15% many < 30 MWe

Suspension boilers, Air 

spreader-stoker

Wood flour, sander dust, and 

processed sawdust, shavings

0.04 in -0.06 in (1-1.6 

mm)

< 20% 1.5 MWe to 30 Mwe

Many at 20 to 25 MWe, up to 300 

Example 1

Example 2

Co-firing: pulverized coal 

boiler

Sawdust, non-stringy bark, 

shavings, flour, sander dust 

<0.25 in (<6 mm) < 25% Up to 1500 MWee

 Example

Co-firing: cyclones Sawdust, non-stringy bark, 

shavings, flour, sander dust 

<0.5 in (<12 mm) 10 – 50% 40 to 1150 MWee

 Example

Co-firing: stokers, fluidized 

bed

Sawdust, non-stringy bark, 

shavings, flour, hog fuel

< 3 in (<72 mm) 10 – 50% MWee

 Example

Counter current, fixed bed 

(updraft) atmospheric 

Chipped wood or hog fuel, rice 

hulls, dried sewage sludge

0.25 – 4 in (6 – 100 

mm)

< 20% 5 to 90 MWt, + up to 12 MWe 

Example

Downdraft, moving bed 

atmospheric gasifier

Wood chips, pellets, wood scrapes, 

nut shells

< 2 in (<50 mm) <15% ~ 25-100 kWe Example

Circulating fluidized bed 

(CFB), dual vessel, gasifier

Most wood and chipped agricultural 

residues but no flour or stringy 

materials

0.25 – 2 in (6 -50 mm) 15-50% ~ 5 to 10 Mwe Example

~ 2.5 Mwe Example 1

Example 2

145 to 1700 x 103 kwhr/yr 

Example 1

Example 2

Animal manures & bedding, food 

processing residues, brewery byproducts, other industry organic 

residues 

NA 65 to 99.9% liquid 

depending on type, 

i.e., 0.1 to 35% 

solids

Anerobic digesters

Fast pryolysis Variety of wood and agricultural 

resources 

0.04-0.25 in (1-6 mm ) < 10% 

Fluidized-bed combustor 

(FB- bubbling or CFBcirculating)

Low alkali content fuels, mostly 

wood residues or peat no flour or 

stringy materials

< 2 in (<50 mm) < 60% 

Source: 

Compiled by Lynn Wright, Oak Ridge, TN. 

_______________________ 

a

 Primary source for fuel types is: Badger, Phillip C. 2002. Processing Cost Analysis for Biomass 

Feedstocks. ORNL/TM-2002/199. Available at http://bioenergy.ornl.gov/main.aspx (search by title or 

author). b

 Most primary biomass, as harvested, has a moisture content (MC) of 50 to 60% (by wet weight) 

while secondary or tertiary sources of biomass may be delivered at between 10 and 30%. A lower MC 

always improves efficiency and some technologies require low MC biomass to operate properly while 

others can handle a range of MC. c

 Wood residues may include forest logging residues and storm damaged trees (hog fuel), primary 

mill residues (e.g. chipped bark and chip rejects), secondary mill residues (e.g. dry sawdust), urban wood 

residues such as construction and demolition debris, pallets and packaging materials, tree trimmings, 

urban land clearing debris, and other wood residue components of municipal solid waste (as wood chips). d

 Agricultural residues may include straws and dried grasses, nut hulls, orchard trimmings, fruit pits, 

etc. Slagging may be more of a problem in some types of combustion units with high alkali straws and 

grasses, unless the boilers have been specially designed to handle these type fuels. e

 The biomass component of a co-firing facility will usually be less than the equivalent of 50MWe. 
66 

Biomass Energy Data Book: Edition 1 

There are three distinct markets for green power in the United States. In regulated markets, a single utility 

may provide a green power option to its customers through “green pricing,” which is an optional service or 

tariff offered to customers. These utilities include investor-owned utilities, rural electric cooperatives, and 

other publicly-owned utilities. More than 500 utilities in 34 states offer green pricing or are in the process 

of preparing programs. 

In restructured (or competitive) electricity markets, retail electricity customers can choose from among 

multiple electricity suppliers, some of which may offer green power. Electricity markets are now open to 

full competition in a number of states, while others are phasing in competition. 

Finally, consumers can purchase green power through “renewable energy certificates.” These certificates 

represent the environmental attributes of renewable energy generation and can be sold to customers in 

either type of market, whether or not they already have access to a green power product from their 

existing retail power provider. 

Utility market research shows that majorities of customer respondents are likely to state that they would 

pay at least $5 more per month for renewable energy. And business and other nonresidential customers, 

including colleges and universities, and government entities, are increasingly interested in green power.

Table 3.3 

New Renewable Capacity Supplying Green Power Markets, 2004

Source: 

National Renewable Energy Laboratory, Power Technologies Energy Data Book, Chapter 3, Table 3.6.5. 

http://www.nrel.gov/analysis/power_databook/chapter3.html 

Note: MW = megawatt. 

Source MW in Place % MW Planned % 

Wind 2045.6 91.6 364.5 80.1

Biomass 135.6 6.1 58.8 12.9

Solar 8.1 0.4 0.4 0.1

Geothermal 35.5 1.6 0 0

Small Hydro 8.5 0.4 31.3 6.9

Total 2233.3 100 455 100
 67

Biomass Energy Data Book: Edition 1 

Green pricing is an optional utility service that allows customers an opportunity to support a greater level 

of utility company investment in renewable energy technologies. Participating customers pay a premium 

on their electric bill to cover the extra cost of the renewable energy. Many utilities are offering green 

pricing to build customer loyalty and expand business lines and expertise prior to electric market 

competition. As of 2003, 36 utilities in 19 states had implemented green pricing options that used or 

included biomass feedstocks. 

Table 3.4 

New Renewable Capacity Supported through Utility Green Pricing Programs, 2004 

Source:

National Renewable Energy Laboratory, Power Technology Energy Data Book, Table 3.7.1, 

http://www.nrel.gov/analysis/power_databook/chapter3.html

Note: MW = megawatt. 

Source MW in Place % MW Planned % 

Wind 584.0 82.8 139.7 61.1

Biomass 76.3 10.8 57.5 25.1

Solar 6.1 0.9 0.2 0.1

Geothermal 30.5 4.3 0.0 0.0

Small Hydro 8.5 1.2 31.3 13.7

Total 705.5 100.0 228.7 100.0
68 

Biomass Energy Data Book: Edition 1 

There are a growing number of utilities offering green pricing programs that utilize biomass resources. 

Table 3.5 

Utility Green Pricing Programs Using Biomass and Biomass Based Resources

State Utility Name Program Name Resource Type Start Date Premium

Alabama Power Renewable Energy 

Rate

biomass co-firing 2003 / 2000 6.0¢/ kWh

TVA Green Power Switch wind, landfill gas, 

solar

2000 2.67¢/ kWh

Salt River Project EarthWise Energy central PV,landfill 

gas, small hydro

1998 / 2001 3.0¢/kWh

Tucson Electric GreenWatts landfill gas, PV, 

wind

2000 7.5-10¢/ kWh

Los Angeles Dept. of 

Water and Power

Green Power for a 

Green LA

wind, landfill gas 1999 3.0¢/kWh

Sacramento Municipal 

Utility District

Greenergy wind, landfill gas, 

hydro

1997 1.0¢/kWh

Colorado Tri-State Generation & 

Transmission

Renewable 

Resource Power 

Service

wind, landfill gas 1999 2.5¢/kWh

City of Tallahassee / 

Sterling Planet

Green for You biomass, solar 2002 1.6¢/kWh

Florida Power & Light / 

Green Mountain Energy

Sunshine Energy biomass, wind, 

solar

2004 0.975¢/kWh

Gainesville Regional 

Utilities

GRUgreen Energy landfill gas, wind, 

solar

2003 2.0¢/kWh

Tampa Electric Company 

(TECO)

Tampa Electric's 

Renewable Energy 

PV, landfill gas 2000 10.0¢/kWh

Georgia Electric 

Membership Corporation

Green Power EMC landfill gas 2001 TBD

Georgia Power Green Energy landfill gas, wind, 

solar

TBD 5.5¢/kWh

Savannah Electric Green Energy landfill gas, wind, 

solar

TBD 6.0¢/kWh

TVA Green Power Switch wind, landfill gas, 

solar

2000 2.67¢/ kWh

Alliant Energy Second Nature wind, landfill gas 2001 2.0¢/kWh

Farmers Electric 

Cooperative

Green Power Project biodiesel, wind 2004 Contribution

Iowa Association of 

Municipal Utilities

Green City Energy wind, biomass, 

solar

2003 Varies by 

utility

Continued on next page

Florida

Georgia

Iowa

Arizona

California

Alabama
 69

Biomass Energy Data Book: Edition 1 

Table 3.5 (Continued) 

Utility Green Pricing Programs Using Biomass and Biomass Based Resources 

State Utility Name Program Name Resource Type Start Date Premium

Illinois City of St. Charles / 

ComEd and Community 

Energy, Inc.

TBD wind, landfill gas 2003 Contribution

Hoosier Energy EnviroWatts landfill gas 2001 2.0¢/kWh-4.0¢/kWh

PSI Energy/Cinergy Green Power Rider wind, solar, landfill 

gas, digester gas

2001 Contribution

Wabash Valley Power 

Association

EnviroWatts landfill gas 2000 0.9-1.0¢/kWh

East Kentucky Power 

Cooperative

EnviroWatts landfill gas 2002 2.75¢/kWh

TVA Green Power Switch landfill gas, solar, 

wind

2000 2.67¢/kWh

Michigan Lansing Board of Water 

and Light

GreenWise Electric Power landfill gas, small 

hydro

2001 3.0¢/kWh

We Energies Energy for Tomorrow wind, landfill gas, 

hydro

2000 2.04¢/kWh

Minnesota Alliant Energy Second Nature wind, landfill gas 2002 2.0¢/kWh

Mississippi TVA Green Power Switch wind, landfill gas, 

solar

2000 2.67¢/kWh

Dominion North Carolina 

Power, Power, Progress 

Energy/CP&L Plus 7 cities 

and 14 cooperatives

NC GreenPower biomass, wind, solar 2003 4.0¢/kWh

TVA Green Power Switch landfill gas, solar, 

wind

2000 2.67¢/kWh

Omaha Public Power 

District

Green Power Program landfill gas, wind 2002 3.0¢/kWh

Tri-State: Chimney Rock 

Public Power District, 

Renewable Resource Power 

Service

wind, landfill gas 2001 2.5¢/kWh

New Mexico Tri-State: Kit Carson 

Electric Cooperative

Renewable Resource Power 

Service

wind, landfill gas 2001 2.5¢/kWh

Ohio City of Bowling Green Bowling Green Power small hydro, wind, 

landfill gas

1999 1.35¢/kWh

Oregon Pacific Northwest 

Generating Cooperative

Green Power landfill gas 1998 1.8-2.0¢/kWh

South Carolina Eight different 

cooperatives

Green Power Program landfill gas 2001 3.0¢/kWh

Kentucky

North Carolina

Nebraska

Indiana

Source: 

National Renewable Energy Laboratory, Power Technologies Energy Data Book, Table 3.8.2, 

http://www.nrel.gov/analysis/power_databook/chapter3.html
70 

Biomass Energy Data Book: Edition 1 

A growing number of states have companies that offer a range of green power products that allow 

consumers to purchase electricity generated in part or entirely from biomass resources. 

Table 3.6 

Competitive Electricity Markets Retail Green Power Product Offerings, October 2005

State Company Product Name

Residential 

Price Premiuma Fee Resource Mixb Certification

Community Energy (CT Clean 

Energy Options Program)

CT Clean Energy Options 

50% or 100% of usage 1.1¢/kWh —

50% new wind, 50% 

landfill gas —

Levco

100% Renewable Electricity 

Program 0.0¢/kWh —

98% waste-to-energy and 

hydro (Class II), 2% new 

solar, wind, fuel cells, and 

landfill gas —

Sterling Planet (CT Clean Energy 

Options Program)

Sterling Select 50% or 

100% of usage 1.15¢/kWh —

33% new wind, 33% 

existing small low impact 

hydro, 34% new landfill 

gas —

District of Columbia

PEPCO Energy Servicesc

Green Electricity 10%, 51% 

or 100% of usage

1.35¢/kWh (for 

100% usage) — landfill gas —

PEPCO Energy Servicesd

Green Electricity 10%, 51% 

or 100% of usage 

2.75¢/kWh (for 

100% usage) — landfill gas —

PEPCO Energy Servicesd Non-residential product NA —

50% to 100% eligible 

renewables Green-e

Cape Light Compacte

Cape Light Compact Green 

50% or 100%

1.768¢/kWh (for 

100% usage) —

75% small hydro, 24% new 

wind or landfill gas, 1% 

new solar —

Massachusetts Electric/Nantucket 

Electric/Mass Energy Consumers 

Alliance 

New England GreenStart 50% 

or 100% of usage 

2.4¢/kWh (for 

100% usage) — 

75% small hydro, 19% 

biomass, 5% wind, 1% solar 

		

 — 

Massachusetts Electric/Nantucket 

Electric/Sterling Planet 

Sterling Premium 50% or 

100% of usage 1.35¢/kWh — 

50% small hydro, 30% 

bioenergy, 15% wind, 5% 

new solar 

Environmental 

Resources Trust 

Green Mountain Energy Companyf Enviro Blend 1.0¢/kWh $3.95/mo. 

5% new wind, 0.4% solar, 

44.6% captured methane, 

50% large hydro — 

PSE&G/JCP&L/ Sterling Planet Clean Power Choice Program 1.2¢/kWh — 

33% wind, 33% small hydro, 

34% bioenergy 

Environmental 

Resources Trust 

Energy Cooperative of New Yorkg Renewable Electricity 

0.5¢/kWh to 

0.75¢/kWh — 

25% new wind, 75% existing 

landfill gas — 

Long Island Power Authority / 

EnviroGen Green Power Program 1.0¢/kWh — 

75% landfill gas, 25% small 

hydro — 

Long Island Power Authority / Sterling 

Planet New York Clean 1.0¢/kWh — 

55% small hydro, 35% 

bioenergy, 10% wind — 

Long Island Power Authority / Sterling 

Planet Sterling Green 1.5¢/kWh — 

40% wind, 30% small hydro, 

30% bioenergy — 

Niagara Mohawk / EnviroGen Think Green! 1.0¢/kWh — 75% landfill gas, 25% hydro — 

Niagara Mohawk / Sterling Planet Sterling Green 1.5¢/kWh — 

40% wind, 30% small hydro, 

30% bioenergy 

Environmental 

Resources Trust 

Suburban Energy Services /Sterling 

Planet 

Sterling Green Renewable 

Electricity 1.5¢/kWh — 

40% new wind, 30% small 

hydro, 30% bioenergy — 

New York 

Connecticut

Maryland

Massachusetts

New Jersey 

Energy Cooperative of 

Pennsylvaniah EcoChoice 100 2.78¢/kWh — 

89% landfill gas, 

10% wind, 1% 

solar Green-e 

PEPCO Energy Servicesh 

Green Electricity 

10%, 51% or 100% 

of usage 

3.7¢/kWh (for 100% 

usage) — 100% renewable — 

Rhode Island 

Narragansett Electric / 

Sterling Planet 

Sterling Supreme 

100% 1.98¢/kWh — 

40% small hydro, 

25% biomass, 

25% new solar, 

10% wind 

Environmental 

Resources Trust

TX 

Gexa Energyi Gexa Green -1.1¢/kWh — 100% renewable — 

VA 

PEPCO Energy Servicesj 

Green Electricity 

10%, 51% or 100% 

of usage 

4.53¢/kWh (for 100%

usage) — landfill gas — 

Pennsylvania 

Continued on next page
 71

Biomass Energy Data Book: Edition 1 

Table 3.6 (Continued) 

Competitive Electricity Markets Retail Green Power Product Offerings, October 2005 

Source: 

National Renewable Energy Laboratory, Power Technologies Energy Data Book, Table 3.8.8, 

http://www.nrel.gov/analysis/power_databook/chapter3.html. 

 

______________________ 

a

 Prices updated as of July 2005 and may also apply to small commercial customers. Prices may 

differ for large commercial/industrial customers and may vary by service territory. b

 New is defined as operating or repowered after January 1, 1999 based on the Green-e TRC 

certification standards. c

 Offered in PEPCO service territory. Product prices are for renewal customers based on annual 

average costs for customers in PEPCO's service territory (6.8¢/kWh). d

 Product offered in Baltimore Gas and Electric and PEPCO service territories. Price is for PEPCO 

service territory based on price to compare of 6.55¢/kWh. e

 Price premium is based on a comparison to the Cape Light Compact's standard electricity 

product. f

 Green Mountain Energy offers products in Conectiv, JCPL, and PSE&G service territories. Product 

prices are for PSE&G (price to compare of 6.503¢/kWh). 

g

 Price premium is for Niagara Mohawk service territory. Program only available in Niagara Mohawk 

service territory. Premium varies depending on energy taxes and usage. h

 Product prices are for PECO service territory (price to compare of 6.21¢/kWh). 

i

 Product prices are based on price to beat of 12.1¢/kWh for TXU service territory (specifically 

Dallas, Texas) (Except where noted). Except for Gexa Green, which is listed in price per kWh, prices 

based on 1000 kWh of usage monthly, and include monthly fees. j

 Products are available in Dominion Virginia Power service territory. 
72 

Biomass Energy Data Book: Edition 1 

Renewable energy certificates (RECs)—also known as green tags, renewable energy credits, or tradable 

renewable certificates—represent the environmental attributes of power generated from renewable 

electric plants. A number of organizations offer green energy certificates separate from electricity service 

(i.e., customers do not need to switch from their current electricity supplier to purchase these certificates). 

Organizations that offer green certificate products using biomass resources are listed below. 

Table 3.7 

Renewable Energy Certificate Product Offerings, October 2005 

Certificate Marketer Product Name

Renewable 

Resources

Location of 

Renewable 

Resources

Residential Price 

Premium Certification

Blue Sky Energy Corp Greener ChoiceTM Green

Tags 

Landfill Gas Utah 1.95¢/kWh —

Bonneville Environmental 

Foundation

Green Tags 	






new biomass

Washington, 

Oregon, Wyoming, 

Montana, Alberta

2.0¢/kWh Green-e

Clean Energy 

Partnership/Sterling Planet 

National New Clean 

Energy MIx 

24% wind, 25% 

biomass, 50% landfill 

gas, 1% solar 

National 0.6¢/kWh Environmental 

Resources Trust 

Maine Interfaith Power & 

Light/BEF

Green Tags (supplied 

by BEF)

	






new biomass

Washington, 

Oregon, Wyoming, 

Montana, Alberta

2.0¢/kWh —

NativeEnergy CoolHome New biogas and new 

wind

Vermont and 

Pennsylvania 

(biomass), South 

Dakota (wind)

0.8¢/kWh - 

1.0¢/kWh 

a

Sterling Planet Green America 45% new wind 50% 

new biomass 5% new

solar

Nationwide 1.6¢/kWh Green-e

TerraPass Inc. TerraPass Various (including 

efficiency and CO2 

offsets) 

Nationwide ~$11/ton CO2 —

Source: 

National Renewable Energy Laboratory, Power Technologies Energy Data Book, Table 3.8.9, 

 http://www.nrel.gov/analysis/power_databook/chapter3.html

Note: — = Information not available. 

New is defined as operating or repowered after January 1, 1999, based on the Green-e TRC certification 

standards. Most product prices are as of July 2005. 

_________________________ 

a

 The Climate Neutral Network certifies the methodology used to calculate the CO2 emissions 

offset. 
 73

Biomass Energy Data Book: Edition 1 

Table 3.8 

Current Biomass Power Plants

Plant Name

Boiler/Generator/

Committed Unit State Name County Capacity MW Heat Rate Cogeneration On-line Year

Florida Coast Paper Co LLC G Florida GULF 0.128873283 8538.991465 Yes 1937

Florida Coast Paper Co LLC G Florida GULF 0.128873283 8538.991465 Yes 1937

Florida Coast Paper Co LLC G Florida GULF 0.128873283 8538.991465 Yes 1947

Florida Coast Paper Co LLC G Florida GULF 0.180422596 8538.991465 Yes 1952

Florida Coast Paper Co LLC G Florida GULF 0.214788805 8538.991465 Yes 1952

Great Northern Paper G Maine PENOBSCOT 0.044617579 8538.991465 Yes 1954

Great Northern Paper G Maine PENOBSCOT 0.044617579 8538.991465 Yes 1956

Fort Bragg Western Wood Products G California MENDOCINO 1.448629561 8538.991465 Yes 1961

Stone Container Corporation Florence G South Carolina FLORENCE 3.280605752 8538.991465 Yes 1963

Fort Bragg Western Wood Products G California MENDOCINO 1.448629561 8538.991465 Yes 1969

Florida Coast Paper Co LLC G Florida GULF 0.365140968 8538.991465 Yes 1974

Stone Container Corporation Florence G South Carolina FLORENCE 4.199175363 8538.991465 Yes 1974

Somerset Plant G Maine SOMERSET 0.673694411 8538.991465 Yes 1976

Fort Bragg Western Wood Products G California MENDOCINO 1.448629561 8538.991465 Yes 1977

Vaagen Brothers Lumber Incorporated G Washington STEVENS 4.00 8538.991465 Yes 1979

Forster Inc Strong Plant G Maine FRANKLIN 0.12519927 8538.991465 Yes 1980

Stone Container Corporation Hopewell G Virginia PRINCE 4.760897033 8538.991465 Yes 1980

Diamond Walnut G California SAN JOAQUIN 3.901181102 15339 Yes 1981

Wheelabrator Hudson Energy Co G California SHASTA 5.841304881 12368.66667 No 1982

Rayonier Inland Wood Products G Idaho BENEWAH 6.25 8538.991465 Yes 1982

Tamarack Energy Partnership G Idaho ADAMS 5.201707828 25416.43077 Yes 1983

Snider Industries Incorporated G Texas HARRISON 1.542490288 12368.66667 Yes 1983

Agrilectric Power Partners Limited G Louisiana CALCASIEU 9.213845328 9224 No 1984

Bio Energy Corporation G New Hampshire MERRIMACK 11.42246966 8538.991465 Yes 1984

Susanville Facility G California LASSEN 1.002430238 9224 No 1985

Collins Pine Company Project G California PLUMAS 4.169269438 8538.991465 Yes 1985

Wheelabrator Martell Inc G California AMADOR 6.487078891 8538.991465 Yes 1985

Susanville Facility G California LASSEN 7.503397937 9224 No 1985

Pacific Oroville Power Inc G California BUTTE 8.53833579 9224 No 1985

Pacific Oroville Power Inc G California BUTTE 8.53833579 9224 No 1985

Mt Lassen Power G California SHASTA 10.33804027 9224 No 1985

Burney Mountain Power G California SHASTA 10.57367613 9224 No 1985

Ultrapower Chinese Station G California TUOLUMNE 21.38108255 9224 No 1985

Biomass One L P G Oregon JACKSON 0.882171777 8538.991465 Yes 1985

Biomass One L P G Oregon JACKSON 13.23257666 8538.991465 Yes 1985

Crestwood Corporation Dothan G Alabama HOUSTON 3.733695627 8538.991465 Yes 1986

Lincoln Facility G California PLACER 2.13531303 9224 No 1986

Quincy Facility G California PLUMAS 10.50316385 9224 No 1986

Burney Facility G California SHASTA 11.96450375 9224 No 1986

Fairhaven Power Co G California HUMBOLDT 15.19195204 9224 No 1986

Timber Energy Resources Incorporated G Florida LIBERTY 13.56859989 9224 No 1986

Sherman Energy Facility G Maine PENOBSCOT 18.45844126 8538.991465 Yes 1986

Pinetree Power Incoporated G New Hampshire GRAFTON 16.35655942 9224 No 1986

Co Gen LLC G Oregon GRANT 6.84375 25416.43077 Yes 1986

Wheelabrator Shasta G California SHASTA 16.35622526 9224 No 1987

Wheelabrator Shasta G California SHASTA 16.35622526 9224 No 1987

Wheelabrator Shasta G California SHASTA 16.35622526 9224 No 1987

Gorbell Thermo Electron Power G Maine SOMERSET 14.0130841 9224 No 1987

Hillman Power Company L L C G Michigan MONTMORENCY 18.10515075 9224 No 1987

Hemphill Power and Light Company G New Hampshire SULLIVAN 14.27220787 9224 No 1987

Bridgewater Power Company LP G New Hampshire GRAFTON 18.05291407 9224 No 1987

Pinetree Power Tamworth Inc G New Hampshire CARROLL 22.69876766 9224 No 1987

Co-Gen II, LLC G Oregon DOUGLAS 6.852791878 25416.43077 Yes 1987

Stone Container Corporation Florence G South Carolina FLORENCE 20.7596732 8538.991465 Yes 1987

The Pacific Lumber Company G California HUMBOLDT 6.001523055 8538.991465 Yes 1988

Greenville Steam Company G Maine PISCATAQUIS 14.59498243 25416.43077 No 1988

Viking Energy of McBain G Michigan MISSAUKEE 16.51695997 9224 No 1988

Whitefield Power and Light Co G New Hampshire COOS 14.51030066 9224 No 1988

Susquehanna Plant G Pennsylvania LYCOMING 10.91578166 7995.373263 Yes 1988

Viking Energy of Northumberland G Pennsylvania NORTHUMBERL 16.94882449 9224 No 1988

The Pacific Lumber Company G California HUMBOLDT 6.001523055 8538.991465 Yes 1989

Loyalton Facility G California SIERRA 15.50036449 8538.991465 Yes 1989

Woodland Biomass Power Limited G California YOLO 24.57285808 9224 No 1989

Mendota Biomass Power Limited G California FRESNO 24.70598521 9224 No 1989

Wadham Energy Limited Partnership G California COLUSA 25.4990433 9224 No 1989

Burney Forest Products G California SHASTA 27.61054735 9082.609668 Yes 1989

HL Power Plant G California LASSEN 31.50214419 9224 No 1989

A R Lavallee Incorporated G Maine YORK 0.447784134 8538.991465 Yes 1989

S D Warren Company 2 G Maine CUMBERLAND 4.066280247 8538.991465 Yes 1989

Winslow, Maine G Maine KENNEBEC 10.36716597 8538.991465 Yes 1989

S D Warren Company 2 G Maine CUMBERLAND 12.87655412 8538.991465 Yes 1989

Boralex Stratton Energy Inc G Maine FRANKLIN 41.89923255 9224 No 1989

Viking Energy of Lincoln G Michigan ALCONA 16.44424521 9224 No 1989

Continued on next page. 
74 

Biomass Energy Data Book: Edition 1 

Table 3.8 (Continued) 

Current Biomass Power Plants 

Plant Name

Boiler/Generator/

Committed Unit State Name County Capacity MW Heat Rate Cogeneration On-line Year

Tracy Biomass Plant G California SAN JOAQUIN 20.50248146 9224 No 1990

Delano Energy Company Incorporated G California KERN 27.07152119 9224 No 1990

Great Northern Paper G Maine PENOBSCOT 0.086375057 8538.991465 Yes 1990

Somerset Plant G Maine SOMERSET 0.842118014 8538.991465 Yes 1990

Craven County Wood Energy L P G North Carolina CRAVEN 46.69179392 9224 No 1990

Potlatch Corp Southern Wood Products G Arkansas BRADLEY 7.683280889 8538.991465 Yes 1991

Mecca Plant G California RIVERSIDE 48.30915139 9224 No 1991

Beaver Livermore Falls G Maine ANDROSCOGGI 36.25127717 9224 No 1992

Pinetree Power Fitchburg Inc G Massachusetts WORCESTER 16.07467078 9224 No 1992

Lyonsdale Power Company LLC G Michigan GRATIOT 19.36820024 8538.991465 Yes 1992

Grayling Generating Station G Michigan CRAWFORD 37.99570523 9224 No 1992

Ryegate Power Station G Vermont CALEDONIA 19.50652465 9224 No 1992

Delano Energy Company Incorporated G California KERN 21.48884374 9224 No 1993

Beaver Ashland G Maine AROOSTOOK 36.2184593 9224 No 1993

Cadillac Renewable Energy G Michigan WEXFORD 35.86121164 10013.6 No 1993

KES Chateaugay Power Station G New York FRANKLIN 17.62961823 9224 No 1993

Sauder Power Plant G Ohio FULTON 3.085144462 10891.8 Yes 1993

Sauder Power Plant G Ohio FULTON 3.085144462 10891.8 Yes 1993

Ridge Generating Station G Florida POLK 40.06031261 9224 No 1994

Aroostook Valley G Maine AROOSTOOK 29.50 9224 No 1994

Multitrade of Pittsylvania County L P Pl G Virginia PITTSYLVANIA 41.347412 9224 No 1994

Multitrade of Pittsylvania County L P Pl G Virginia PITTSYLVANIA 41.347412 9224 No 1994

Okeelanta Power Limited Partnership G Florida PALM BEACH 61.33887206 8538.991465 Yes 1995

Cox Waste to Energy G Kentucky TAYLOR 1.075439298 9224 No 1995

Agrilectric Power Partners Limited G Louisiana CALCASIEU 1.139857154 9224 No 1995

Genesee Power Station Limited G Michigan GENESEE 36.03528491 9224 No 1996

Everett Cogen G Washington SNOHOMISH 36.00 8538.991465 Yes 1996

Bioten Operations Inc G Tennessee MACON 0.731874145 10013.6 No 1997

Anderson Facility G California SHASTA 0.679977523 10891.8 No 1998

Washington Veneer G Washington OKANOGAN 0.962570193 8538.991465 Yes 1998

Washington Veneer G Washington OKANOGAN 1.443855289 8538.991465 Yes 1998

Lincoln Facility G California PLACER 0.060566964 8011 Yes 1999

Quincy Facility G California PLUMAS 5.799762734 8011 No 1999

Trigen-Colorado Metro Facility Site G Colorado ADAMS 3.52 29657 Yes 2000

Trigen-Colorado Metro Facility Site G Colorado ADAMS 3.52 29657 Yes 2000

Horry LFG Site G South Carolina HORRY 1.00 29657 No 2001

Horry LFG Site G South Carolina HORRY 1.00 29657 No 2001

Jacobs Energy Corporation C Illinois a 4.68 8911 No 2002

St. Paul Cogen, NonMandated C Minnesota a 7.60 8911 No 2002

St. Paul Cogen, Mandated C Minnesota a 23.75 8911 No 2002

Scott Wood C Virginia a 0.90 8911 No 2002

Scott Wood C Virginia a 2.80 8911 No 2002

Gorge Energy Div SDS C Washington a 5.00 8911 No 2002

Environmental Forest Solutions C Arizona a 2.85 8911 No 2003

Jacobs Energy Corporation C Illinois a 0.62 8911 No 2003

Ware Biomass Cogen C Massachusetts a 7.79 8911 No 2003

Massachusetts RPS 2003 - Biomass C Massachusetts a 9.22 8911 No 2003

Aberdeen C Washington a 16.00 8911 No 2003

Source: 

(National Electric Energy System (NEEDS) Database for IPM 2004, 

http://www.epa.gov/airmarkets/epa-ipm/#needs. 

____________________ 

a

 Data are not available. 
 75

Biomass Energy Data Book: Edition 1 

Table 3.9 

Current Landfill Gas Power Plants 

Plant Name

Boiler/Generator/C

ommitted Unit State Name County Capacity MW Heat Rate Cogeneration On-line Year

Puente Hills Energy Recovery G California LOS ANGELES 44.76434101 11000 No 1986

Palos Verdes Gas to Energy Facility G California ORANGE 11.60288061 11000 No 1988

Coyote Canyon Steam Plant G California ORANGE 17.5218204 11000 No 1989

BKK Landfill G California LOS ANGELES 5.984199375 11805 No 1993

O Brien Biogas IV LLC G New Jersey MIDDLESEX 9.986892485 11805 No 1997

North City Cogeneration Facility G California SAN DIEGO 0.933474164 11805 No 1999

North City Cogeneration Facility G California SAN DIEGO 0.933474164 11805 No 1999

North City Cogeneration Facility G California SAN DIEGO 0.933474164 11805 No 1999

North City Cogeneration Facility G California SAN DIEGO 0.933474164 11805 No 1999

Prima Desheha Landfill G California ORANGE 2.65094446 11805 No 1999

Prima Desheha Landfill G California ORANGE 2.65094446 11805 No 1999

Kiefer LF G California SACRAMENTO 2.769899605 11805 No 1999

Kiefer LF G California SACRAMENTO 2.769899605 11805 No 1999

Kiefer LF G California SACRAMENTO 2.769899605 11805 No 1999

BKK Landfill G California LOS ANGELES 4.245327517 11805 No 1999

Tazewell Gas Recovery G Illinois TAZEWELL 0.566133167 11805 No 1999

KMS Joliet Power Partners LP G Illinois WILL 0.754613209 13648 No 1999

Roxana LF G Illinois MADISON 1.000000002 13648 No 1999

Roxana LF G Illinois MADISON 1.000000002 13648 No 1999

Roxana LF G Illinois MADISON 1.000000002 13648 No 1999

Brickyard G Illinois VERMILION 1.000000037 13648 No 1999

Brickyard G Illinois VERMILION 1.000000037 13648 No 1999

Brickyard G Illinois VERMILION 1.000000037 13648 No 1999

Dixon G Illinois LEE 1.000000047 13648 No 1999

Dixon G Illinois LEE 1.000000047 13648 No 1999

Dixon G Illinois LEE 1.000000047 13648 No 1999

Streator G Illinois LA SALLE 1.000000058 13648 No 1999

Streator G Illinois LA SALLE 1.000000058 13648 No 1999

Biodyne Pontiac G Illinois LIVINGSTON 1.54425 11805 No 1999

Deercroft Gas Recovery G Indiana LA PORTE 0.783213037 11805 No 1999

Metro Methane Recovery Facility G Iowa POLK 0.786481001 11805 No 1999

HMDC Kingsland Landfill G New Jersey BERGEN 0.881475967 11805 No 1999

HMDC Kingsland Landfill G New Jersey BERGEN 0.881475967 11805 No 1999

LFG Energy Inc G New York ERIE 0.765217333 11805 No 1999

LFG Energy Inc G New York ERIE 0.765217333 11805 No 1999

LFG Energy Inc G New York ERIE 0.765217333 11805 No 1999

LFG Energy Inc G New York ERIE 0.765217333 11805 No 1999

LFG Energy Inc G New York ERIE 0.765217333 13648 No 1999

High Acres Gas Recovery G New York MONROE 0.778894571 11805 No 1999

Blackburn Co-Generation G North Carolina CATAWBA 0.857569492 11805 No 1999

Blackburn Co-Generation G North Carolina CATAWBA 0.857569492 11805 No 1999

Blackburn Co-Generation G North Carolina CATAWBA 0.857569492 13648 No 1999

Blackburn Co-Generation G North Carolina CATAWBA 0.857569492 13648 No 1999

Charlotte Motor Speedway G North Carolina CABARRUS 4.499151173 11805 No 1999

Cuyahoga Regional Landfill G Ohio CUYAHOGA 1.777833611 11805 No 1999

Cuyahoga Regional Landfill G Ohio CUYAHOGA 1.777833611 11805 No 1999

Roosevelt Biogas 1 G Washington KLICKITAT 2.10 11805 No 1999

Roosevelt Biogas 1 G Washington KLICKITAT 2.10 11805 No 1999

Roosevelt Biogas 1 G Washington KLICKITAT 2.10 11805 No 1999

Roosevelt Biogas 1 G Washington KLICKITAT 2.10 11805 No 1999

Tajiguas Landfill G California SANTA BARBARA 2.752165154 11805 No 2000

KMS Joliet Power Partners LP G Illinois WILL 0.759300247 13648 No 2000

Biodyne Pontiac G Illinois LIVINGSTON 0.778130417 11805 No 2000

Upper Rock G Illinois ROCK ISLAND 1.00 13648 No 2000

Upper Rock G Illinois ROCK ISLAND 1.00 13648 No 2000

Upper Rock G Illinois ROCK ISLAND 1.00 13648 No 2000

Roxana LF G Illinois MADISON 1.000000002 13648 No 2000

Fall River Electric G Massachusetts BRISTOL 0.879903479 11805 No 2000

Fall River Electric G Massachusetts BRISTOL 0.879903479 11805 No 2000

Randolph Electric G Massachusetts NORFOLK 0.943396199 11805 No 2000

Randolph Electric G Massachusetts NORFOLK 0.943396199 11805 No 2000

Randolph Electric G Massachusetts NORFOLK 0.943396199 11805 No 2000

Fall River Electric G Massachusetts BRISTOL 4.399517393 11805 No 2000

Grand Blanc Generating Station G Michigan GENESEE 0.767358272 11805 No 2000

M M Nashville G Tennessee DAVIDSON 0.95 11805 No 2000

M M Nashville G Tennessee DAVIDSON 0.95 11805 No 2000

Roosevelt Biogas 1 G Washington KLICKITAT 2.10 11805 No 2000

Metro Gas Recovery G Wisconsin MILWAUKEE 0.698586128 13648 No 2000

Metro Gas Recovery G Wisconsin MILWAUKEE 0.698586128 13648 No 2000

Metro Gas Recovery G Wisconsin MILWAUKEE 0.698586128 13648 No 2000

Metro Gas Recovery G Wisconsin MILWAUKEE 0.698586128 13648 No 2000

Continued on next page. 
76 

Biomass Energy Data Book: Edition 1 

Table 3.9 (Continued) 

Current Landfill Gas Power Plants

Plant Name

Boiler/Generator/C

ommitted Unit State Name County Capacity MW Heat Rate Cogeneration On-line Year

Pheasant Run Landfill Gas Recovery G Wisconsin KENOSHA 0.75417871 11805 No 2000

Pheasant Run Landfill Gas Recovery G Wisconsin KENOSHA 0.75417871 11805 No 2000

Pheasant Run Landfill Gas Recovery G Wisconsin KENOSHA 0.75417871 13648 No 2000

Pheasant Run Landfill Gas Recovery G Wisconsin KENOSHA 0.75417871 13648 No 2000

Winnebago County Landfill Gas G Wisconsin WINNEBAGO 0.930046772 11805 No 2000

Winnebago County Landfill Gas G Wisconsin WINNEBAGO 0.930046772 11805 No 2000

Winnebago County Landfill Gas G Wisconsin WINNEBAGO 0.930046772 11805 No 2000

Tri - Cities G Arizona MARICOPA 0.80 11805 No 2001

Tri - Cities G Arizona MARICOPA 0.80 11805 No 2001

Tri - Cities G Arizona MARICOPA 0.80 11805 No 2001

Tri - Cities G Arizona MARICOPA 0.80 11805 No 2001

Tri - Cities G Arizona MARICOPA 0.80 11805 No 2001

Badlands G California RIVERSIDE 1.10 11805 No 2001

Biodyne Congress G Illinois COOK 1.794993515 11805 No 2001

Biodyne Congress G Illinois COOK 1.794993515 11805 No 2001

Biodyne Congress G Illinois COOK 1.794993515 11805 No 2001

Biodyne Pontiac G Illinois LIVINGSTON 3.60325 11805 No 2001

Model City Energy G New York NIAGARA 0.686324989 11805 No 2001

Model City Energy G New York NIAGARA 0.686324989 11805 No 2001

Model City Energy G New York NIAGARA 0.686324989 11805 No 2001

Model City Energy G New York NIAGARA 0.686324989 11805 No 2001

Model City Energy G New York NIAGARA 0.686324989 11805 No 2001

Model City Energy G New York NIAGARA 0.686324989 11805 No 2001

Model City Energy G New York NIAGARA 0.686324989 11805 No 2001

Green Knight G Pennsylvania NORTHAMPTON 2.494937456 11805 No 2001

Green Knight G Pennsylvania NORTHAMPTON 2.494937456 11805 No 2001

Green Knight G Pennsylvania NORTHAMPTON 2.494937456 11805 No 2001

Superior Glacier Ridge Landfil G Wisconsin DODGE 0.90 11805 No 2001

Superior Glacier Ridge Landfil G Wisconsin DODGE 0.90 11805 No 2001

Omega Hills Gas Recovery G Wisconsin WASHINGTON 2.50 11805 No 2001

Jamacha LFG C California a 0.27 13648 No 2002

Operating Industries LFG C California a 0.40 13648 No 2002

Lopez Canyon LFG C California a 1.43 13648 No 2002

Central Disposal Sonoma Phase C California a 1.52 13648 No 2002

AB1890City/Cty San F C California a 1.95 13648 No 2002

Quad Cities C Illinois a 0.90 13648 No 2002

Morris C Illinois a 1.30 13648 No 2002

Morris C Illinois a 1.30 13648 No 2002

Morris C Illinois a 1.30 13648 No 2002

Biodyne Pontiac C Illinois a 4.20 13648 No 2002

Onyx Zion LFG C Illinois a 5.04 13648 No 2002

BioEnergy Com-Ed Biogas C Illinois a 5.16 13648 No 2002

South Side LFG C Indiana a 4.75 13648 No 2002

Brent Run C Michigan a 0.80 13648 No 2002

Elk River C Minnesota a 2.28 13648 No 2002

Douglas County LFG C Nebraska a 3.04 13648 No 2002

Brookhaven Facility C New York a 1.20 13648 No 2002

Brookhaven Facility C New York a 1.20 13648 No 2002

Blackburn Co-Generat C North Carolina a 0.99 13648 No 2002

Bradford C Pennsylvania a 0.76 13648 No 2002

Rolling Hills C Pennsylvania a 2.50 13648 No 2002

Rolling Hills C Pennsylvania a 2.50 13648 No 2002

Reliant Energy Renew C Texas a 1.02 13648 No 2002

Reliant Energy Renew C Texas a 1.02 13648 No 2002

Reliant Energy Renew C Texas a 1.02 13648 No 2002

Reliant Energy Renew C Texas a 1.02 13648 No 2002

Reliant Energy Renew C Texas a 1.02 13648 No 2002

Reliant Energy Renew C Texas a 1.30 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Reliant Energy Renew C Texas a 1.36 13648 No 2002

Continued on next page. 
 77

Biomass Energy Data Book: Edition 1 

Table 3.9 (Continued) 

Current Landfill Gas Power Plants 

Plant Name

Boiler/Generator/C

ommitted Unit State Name County Capacity MW Heat Rate Cogeneration On-line Year

Tessman Road Project LFG, Phas C Texas a 4.94 13648 No 2002

Covel Gardens C Texas a 6.65 13648 No 2002

Arlington LF C Texas a 8.55 13648 No 2002

Chesterfield County LFG C Virginia a 0.52 13648 No 2002

Amelia Landfill LFG C Virginia a 3.99 13648 No 2002

Va Beach Mt Trashmore II LFG C Virginia a 11.97 13648 No 2002

Pheasant Run Landfil C Wisconsin a 0.80 13648 No 2002

Pheasant Run Landfil C Wisconsin a 0.80 13648 No 2002

Ridgeview C Wisconsin a 0.80 13648 No 2002

Ridgeview C Wisconsin a 0.80 13648 No 2002

Ridgeview C Wisconsin a 0.80 13648 No 2002

Acme Landfill C California a 0.27 13648 No 2003

AB1890RiversideCty,C C California a 0.90 13648 No 2003

California Street C California a 0.95 13648 No 2003

AB1890Colton (NEO Co C California a 1.14 13648 No 2003

AB1890Milliken(NEO C C California a 2.38 13648 No 2003

AB1890Mid-Valley(NEO C California a 2.38 13648 No 2003

Keller Canyon LFG C California a 2.66 13648 No 2003

AB1890EgyDevelopment C California a 3.71 13648 No 2003

AB1890BFI, Newby Isl C California a 5.23 13648 No 2003

Bradley C California a 6.18 13648 No 2003

SW Alachua C Florida a 2.38 13648 No 2003

Beecher LFG C Illinois a 4.94 13648 No 2003

Bavarian Waste C Kentucky a 4.75 13648 No 2003

Massachusetts RPS 2003 - LFG C Massachusetts a 3.90 13648 No 2003

Plainville LFG C Massachusetts a 5.32 13648 No 2003

Chicopee II LFG C Massachusetts a 5.42 13648 No 2003

Grand Blanc C Michigan a 0.78 13648 No 2003

3 Landfill Gas Projects C New York a 4.94 13648 No 2003

Palmetto C South Carolina a 4.75 13648 No 2003

Reliant Energy Renew C Texas a 0.99 13648 No 2003

Reliant Energy Renew C Texas a 0.99 13648 No 2003

Blue Bonnet LFG C Texas a 2.00 13648 No 2003

Tessman Road LFG - Added Capac C Texas a 2.47 13648 No 2003

Hutchins LFG C Texas a 2.47 13648 No 2003

City of Conroe LFG C Texas a 2.76 13648 No 2003

Sanifill - Baytown C Texas a 3.80 13648 No 2003

Security Recycling LFG C Texas a 5.99 13648 No 2003

Coastal Plains C Texas a 6.37 13648 No 2003

Coastal Plains C Texas a 9.50 13648 No 2003

WMI Atascocit LFG C Texas a 9.98 13648 No 2003

Essex Junction Wastewater Trea C VERMONT a 0.06 13648 No 2003

Janesville Landfill (WI) C Wisconsin a 2.91 13648 No 2003

Source: 

National Electric Energy System (NEEDS) Database for IPM 2004, 

http://www.epa.gov/airmarkets/epa-ipm/#needs. 
78 

Biomass Energy Data Book: Edition 1 

Table 3.10 

Total Net Generation of Electricity by State from Wood and Wood Waste, 2002 

(Thousand Kilowatt Hours) 

State

Alabama 3,727,493 29.6% 12,575,137

Alaska 1,031 0.1% 1,451,506

Arkansas 1,580,608 31.5% 5,021,095

California 3,957,589 7.2% 54,821,196

Florida 1,552,891 29.1% 5,327,515

Georgia 6,218,978 68.1% 9,130,809

Idaho 508,303 5.5% 9,277,624

Iowa 91 0.0% 1,963,785

Kentucky 365,465 8.3% 4,390,214

Louisiana 2,748,900 73.2% 3,754,232

Maine 3,723,759 51.7% 7,197,599

Maryland 182,904 7.5% 2,437,654

Massachusetts 106,687 3.7% 2,913,724

Michigan 1,474,552 35.4% 4,170,656

Minnesota 377,392 13.1% 2,886,179

Mississippi 936,593 98.7% 948,724

Missouri 143 0.0% 1,423,273

Montana 63,470 0.7% 9,630,379

New Hampshire 699,767 33.9% 2,065,997

New York 412,218 1.5% 27,671,006

North Carolina 1,682,804 31.7% 5,310,327

Ohio 126,067 19.7% 639,640

Oklahoma 239,045 10.7% 2,226,889

Oregon 624,086 1.8% 35,500,087

Pennsylvania 766,289 15.4% 4,968,055

South Carolina 1,228,895 46.7% 2,634,168

Tennessee 750,892 8.6% 8,776,126

Texas 1,073,462 21.0% 5,116,927

Vermont 355,599 24.0% 1,480,893

Virginia 1,407,922 41.6% 3,386,411

Washington 1,126,145 1.4% 79,955,049

West Virginia 51 0.0% 1,097,110

Wisconsin 644,947 17.5% 3,676,150

Total 38,665,038 11.9% 323,826,136

Wood/Wood Waste Percent of all Renewables Total from all Renewables

Source: 

Energy Information Administration, Renewable Energy Annual 2004, Table C6. 

http://www.eia.doe.gov/cneaf/solar.renewables/page/rea_data/rea_sum.html. 

Note: States not listed contained no data for wood/wood waste. 
 79

Biomass Energy Data Book: Edition 1 

Table 3.11 

Net Generation and Fuel Consumption at Power Plants Consuming Coal 

and Biomass by State and Plant Name, 2003 

Biomass Coal Other

Talladega U S Alliance Coosa Pines 173,254 13,134,273 5,911,501 45.01 54.99

Choctaw Georgia Pacific Naheola Mill 428,406 17,123,967 12,892,753 75.29 14.18 10.53

Marengo Gulf States Paper 144,742 10,488,058 8,689,654 82.85 7.30 9.85

Autauga International Paper Prattville 496,108 20,716,033 16,225,436 78.32 8.78 12.89

Mobile Mobile Energy Services LLC 416,485 6,961,111 3,033,258 43.57 52.68 3.75

Wilcox Weyerhaeuser Pine Hill Operati 477,473 6,352,999 3,621,355 57.00 10.01 32.99

 Alaska Fairbanks North Star Eielson AFB Central Heat & Pow 82,455 2,919,023 26,599 0.91 97.77 1.32

 Arizona Pima Irvington 1,048,187 11,086,805 154,014 1.39 56.56 42.05

 Arkansas Little River Ashdown 849,495 41,001,419 36,029,685 87.87 8.03 4.10

San Joaquin Stockton Cogen 452,689 5,741,432 528,273 9.20 54.29 36.50

Kern Mt Poso Cogeneration 450,228 5,125,472 12,237 0.24 69.44 30.32

 Connecticut Hartford Covanta Mid-Connecticut Energy 450,215 8,664,367 8,512,216 98.24 1.76

Escambia Crist 6,413,151 66,408,961 2,080 0.00 99.79 0.21

Escambia International Paper Pensacola 463,167 19,758,653 14,615,865 73.97 13.54 12.48

Duval Northside Generating Station 4,724,993 48,641,433 76,943 0.16 15.18 84.67

Nassau Jefferson Smurfit Fernandina B 593,529 18,167,538 11,360,666 62.53 30.73 6.74

Polk C D McIntosh Jr 4,271,266 39,831,464 62,406 0.16 59.17 40.67

Orange Stanton Energy Center 6,054,342 59,081,269 1,007,967 1.71 98.14 0.16

Bay Stone Container Panama City Mi 236,641 20,068,826 17,409,869 86.75 7.52 5.73

Duval Cedar Bay Generating LP 1,833,539 23,812,502 60,039 0.25 99.54 0.21

Early Georgia Pacific Cedar Springs 701,709 37,200,341 28,956,649 77.84 18.10 4.06

Effingham Savannah River Mill 616,517 9,999,695 55,381 0.55 9.12 90.33

Floyd Inland Paperboard Packaging Ro 437,595 21,075,416 12,717,543 60.34 27.61 12.05

Chatham International Paper Savanna Mi 819,569 22,625,484 13,597,613 60.10 30.75 9.15

Richmond International Paper Augusta Mi 499,834 23,164,308 15,929,560 68.77 22.49 8.74

Bibb Riverwood International Macon 272,388 12,444,817 9,829,168 78.98 9.98 11.04

Laurens SP Newsprint 257,674 8,242,895 5,876,174 71.29 19.73 8.98

Oahu AES Hawaii 1,558,310 15,768,698 197,811 1.25 98.03 0.72

Maui Hawaiian Comm and Sugar Puunen 196,437 6,327,592 5,073,883 80.19 18.02 1.80

Macon Archer Daniels Midland Decatur 1,285,911 35,123,776 379,235 1.08 98.92

Randolph Baldwin Energy Complex 13,090,406 133,957,397 1,082,779 0.81 99.10 0.09

Story Ames Electric Services Power P 417,670 5,042,727 351,818 6.98 92.46 0.56

Linn Prairie Creek 988,852 10,404,803 126,754 1.22 97.23 1.55

Linn Sixth Street 147,644 3,280,837 20,616 0.63 77.34 22.03

Johnson University of Iowa Main Power 96,154 3,493,728 303,494 8.69 80.71 10.60

 Kentucky Daviess Elmer Smith 2,576,356 26,232,220 315,669 1.20 97.60 1.20

De Soto Mansfield Mill 823,390 25,267,624 20,284,572 80.28 5.28 14.44

Morehouse International Paper Louisiana 573,028 20,240,021 17,793,018 87.91 1.44 10.65

Oxford Rumford Cogeneration 761,994 14,988,922 10,674,204 71.21 28.79

Cumberland S D Warren Somerset 405,698 6,776,035 3,981,923 58.76 37.70 3.54

 Maryland Allegany Luke Mill 479,094 17,525,830 7,452,148 42.52 57.48

Dickinson International Paper Quinnesec 220,975 10,079,834 9,772,982 96.96 0.18 2.86

Alpena Louisiana Pacific 44,646 739,198 57,597 7.79 60.85 31.36

Delta Mead Paper 684,599 18,935,467 12,154,663 64.19 22.06 13.75

Muskegon S D Warren Muskegon 250,591 7,668,122 2,867,940 37.40 58.72 3.87

Manistee TES Filer City Station 458,857 6,101,760 501,018 8.21 91.79

Wayne Wyandotte 270,603 3,951,663 305,851 7.74 91.39 0.87

St Louis Hibbing 45,670 1,531,495 78 0.01 99.99 0.00

Itasca Rapids Energy Center 130,699 3,608,215 2,769,301 76.75 16.16 7.09

 Mississippi Lowndes Weyerhaeuser Columbus MS 613,650 20,090,225 18,705,609 93.11 3.83 3.06

St Louis City Anheuser Busch St Louis 120,498 4,094,333 278,326 6.80 88.85 4.35

Jackson Sibley 3,170,801 32,841,421 314,186 0.96 99.01 0.04

Jasper Asbury 1,301,578 14,793,004 298,172 2.02 97.72 0.27

Pike Hercules Missouri Chemical Wor 84,970 2,864,296 3,573 0.12 98.92 0.95

Saline Marshall 35,538 571,009 4,734 0.83 94.14 5.03

St Charles Sioux 6,332,833 60,585,566 631,649 1.04 98.15 0.81

Boone University of Missouri Columbi 127,509 3,444,927 76,558 2.22 91.00 6.78

 Maine

 Michigan

 Minnesota

 Missouri

 Hawaii

 Illinois

 Iowa

 Louisiana

 Alabama

 California

 Florida

 Georgia

County

Net Electricity 

Generation 

(Thousand 

Kilowatthours)

Total Energy 

Consumed 

(MMBtu)

Energy 

Consumed 

from 

Biomass 

State Plant Name (MMBtu)

Percent of Energy Consumed

from

Continued on next page. 
80 

Biomass Energy Data Book: Edition 1 

Table 3.11 (Continued) 

Net Generation and Fuel Consumption at Power Plants Consuming Coal 

and Biomass by State and Plant Name, 2003 

Biomass Coal Other

Yates AES Greenidge LLC 1,040,354 11,705,155 99,328 0.85 98.90 0.25

Jefferson Black River Power LLC 355,861 4,539,007 9,635 0.21 74.06 25.73

Niagara WPS Power Niagara 251,890 3,353,781 28,760 0.86 98.21 0.94

Haywood Canton North Carolina 344,245 20,265,972 9,641,230 47.57 52.12 0.30

Forsyth Corn Products Winston Salem 56,591 3,948,209 3,441,379 87.16 11.73 1.11

Halifax International Paper Roanoke Ra 174,563 12,732,892 8,624,055 67.73 23.23 9.04

Columbus International Paper Riegelwood 503,301 25,783,234 18,114,256 70.26 5.22 24.52

Bladen Elizabethtown Power LLC 117,590 1,659,872 383,987 23.13 76.87

Robeson Lumberton 83,280 1,075,248 201,011 18.69 81.31

Martin Weyerhaeuser Plymouth NC 806,280 39,957,341 32,330,211 80.91 17.27 1.81

Pickaway Picway 402,519 4,674,846 29,550 0.63 98.86 0.51

 Ohio Ross Mead Custom Paper 532,453 15,151,763 8,077,827 53.31 45.29 1.40

Delaware Chester Operations 389,779 6,591,803 23,657 0.36 54.54 45.10

Northampton Northhampton Generating LP 820,274 8,762,273 205,553 2.35 56.42 41.24

Schuylkill Kline Township Cogen Facility 393,564 5,978,255 423,384 7.08 92.01 0.91

York P H Glatfelter 680,328 17,422,344 8,766,181 50.32 48.75 0.94

Elk Johnsonburg Mill 279,550 8,572,138 4,801,100 56.01 38.92 5.07

Richland International Paper Eastover F 529,454 21,208,564 16,189,319 76.33 16.94 6.72

Georgetown International Paper Georgetown 527,894 21,735,489 17,702,311 81.44 10.33 8.23

Florence Stone Container Florence Mill 710,340 20,402,914 12,541,662 61.47 27.28 11.25

McMinn Bowater Newsprint Calhoun Oper 525,280 21,325,300 15,574,553 73.03 25.16 1.81

Sullivan Tennessee Eastman Operations 1,239,569 40,812,321 300,054 0.74 98.39 0.88

Hardin Packaging Corp of America 373,340 22,112,700 18,034,060 81.56 9.63 8.82

Sullivan Weyerhaeuser Kingsport Mill 101,154 6,722,666 5,825,213 86.65 13.35

Bedford Georgia Pacific Big Island 52,032 3,357,369 1,720,872 51.26 46.83 1.91

Isle of Wight International Paper Franklin M 776,727 25,587,752 14,481,554 56.60 22.09 21.32

King William St Laurent Paper West Point 525,859 17,126,189 12,851,000 75.04 17.05 7.92

Portsmouth City SPSA Waste To Energy Power Pla 173,116 5,415,699 5,388,534 99.50 0.00 0.50

Hopewell City Stone Container Hopewell Mill 319,104 8,636,244 6,255,293 72.43 25.30 2.27

Covington Covington Facility 671,771 29,004,636 13,064,973 45.04 42.23 12.72

 Washington Cowlitz Weyerhaeuser Longview WA 327,661 18,235,976 14,422,210 79.09 7.72 13.19

Preston Albright 1,669,380 18,709,260 1,806 0.01 99.79 0.20

Pleasants Willow Island 1,095,678 12,279,409 196,900 1.60 98.02 0.37

Kanawha Union Carbide South Charleston 21,488 3,309,914 73,163 2.21 64.49 33.30

Wood Georgia Pacific Nekoosa Mill 203,635 5,584,402 3,224,101 57.73 36.09 6.17

Price Fraser Paper 36,422 334,360 113,361 33.90 66.10

Outagamie International Paper Kaukauna M 211,943 7,634,467 3,344,608 43.81 39.06 17.13

Dane Blount Street 451,308 6,299,195 180,864 2.87 80.63 16.50

Manitowoc Manitowoc 315,087 4,761,246 23,264 0.49 66.17 33.34

Ashland Bay Front 296,711 4,529,448 1,795,854 39.65 58.60 1.75

Lincoln Packaging of America Tomahawk 133,041 10,575,641 7,959,582 75.26 23.01 1.72

Dane Univ of Wisc Madison Charter S 42,282 3,947,769 323,026 8.18 82.18 9.64

Dodge Waupun Correctional Central He 4,130 288,951 20,665 7.15 88.90 3.95

Wood Biron Mill 246,244 4,614,572 326,216 7.07 91.64 1.29

Marinette Niagara Mill 114,749 3,000,275 196,181 6.54 71.80 21.66

Portage Whiting Mill 25,362 1,572,137 208,755 13.28 78.43 8.29

Wood Wisconsin Rapids Pulp Mill 374,930 12,125,962 8,338,658 68.77 26.14 5.10

Marathon Wausau Mosinee Paper Pulp 122,059 12,335,121 10,406,885 84.37 13.37 2.26

Sheboygan Edgewater 4,893,820 47,746,013 665,280 1.39 98.48 0.12

Total 95,304,634 1,709,675,399 630,926,946 36.90 53.78 9.32

 Tennessee

 Virginia

 West Virginia

 Wisconsin

 New York

 North Carolina

 Pennsylvania

 South Carolina

County

Net Electricity 

Generation 

(Thousand 

Kilowatthours)

Total Energy 

Consumed 

(MMBtu)

Energy 

Consumed 

from 

Biomass 

State Plant Name (MMBtu)

Percent of Energy Consumed

from

Source: 

Energy Information Administration. Derived from Table 9: Net Generation and Fuel Consumption at Power Plants 

Consuming Coal and Biomass by State and Plant name, 2003, 

http://www.eia.doe.gov/cneaf/solar.renewables/page/trends/table1.html 

Note: MMBtu = One million British thermal units. Blank cell indicates the plant had no consumption or other energy to 

report. 
 81

Biomass Energy Data Book: Edition 1 

Table 3.12 

Coal Displacement Calculation, 2006 

 Conversion Formula: Step 1 Capacity (A) x Capacity Factor (B) x Annual Hours (C) = Annual Electricity Generation (D) 

 Step 2 Annual Electricity Generation (D) x Conversion Efficiency (E) = Total Output (F) 

 Step 3 Total Output (F) / Fuel Heat Rate (G) = Quantity Fuel (H)

Technology Wind Geothermal Biomass

(A) Capacity (kW) 11,558,205 2,232,495 6,594,096

(B) Capacity Factor (%) 36.0% 90.0% 80.0%

(C) Annual Hours 8,760 8,760 8,760

(D) Annual Electricity Generation (kWh) 36,449,954,187 17,600,991,128 46,211,427,727

(E) Conversion Efficiency (Btu/kWh) 10,107 10,107 10,107

(F) Total Output (Million Btu) 368,399,686 177,893,217 467,058,900

(G) Coal Heat Rate (Btu per short ton) 20,411,000 20,411,000 20,411,000

(H) Coal (short tons) 18,049,076 8,715,556 22,882,705

Technology Hydropower PV Solar Thermal

(A) Capacity (kW) 78,312,583 280,355 388,893

(B) Capacity Factor (%) 44.2% 22.5% 24.4%

(C) Annual Hours 8,760 8,760 8,760

(D) Annual Electricity Generation (kWh) 303,176,455,525 552,579,314 831,235,472

(E) Conversion Efficiency (Btu/kWh) 10,107 10,107 10,107

(F) Total Output (Million Btu) 3,064,204,435 5,584,919 8,401,296

(G) Coal Heat Rate (Btu per short ton) 20,411,000 20,411,000 20,411,000

(H) Coal (short tons) 150,125,150 273,623 411,606

Source: 

National Renewable Energy Laboratory, Power Technologies Energy Data Book, Table 12.3, 

http://www.nrel.gov/analysis/power_databook/chapter12.html. 

Original Sources: Capacity: EIA, Annual Energy Outlook 2006, DOE/EIA-0383 (2006) (Washington, D.C., 

February 2006), Table A16. 

Capacity Factors: Hydropower calculated from EIA, Annual Energy Outlook 2006, DOE/EIA-0383 (2006) 

(Washington, D.C., February 2006), Table A16. All others based on DOE, Renewable Energy 

Technology Characterizations, EPRI TR-109496, 1997 and Program data. 

Conversion Efficiency: EIA, Annual Energy Review 2004, DOE/EIA-0384(2004) (Washington, D.C., 

August 2005), Table A6. 

Heat Rate: Annual Energy Outlook 2006, DOE/EIA-0383 (2006) (Washington, D.C., February 2006), 

Table F1. 

Note: Capacity values exclude combined-heat-and-power (CHP) data but include end-use sector 

(industrial and commercial) non-CHP data. 
82 

Biomass Energy Data Book: Edition 1 

Table 3.13 

Renewable Energy Impacts Calculation, 2006 

 Conversion Formula: Step 1 Capacity (A) x Capacity Factor (B) x Annual Hours (C) = Annual Electricity Generation (D) 

 Step 2 Annual Electricity Generation (D) x Competing Heat Rate (E) = Annual Output (F) 

 Step 3 Annual Output (F) x Emissions Coefficient (G) = Annual Emissions Displaced (H) 

Technology Wind Geothermal Biomass

(A) Capacity (kW) 11,558,205 2,232,495 6,594,096

(B) Capacity Factor (%) 36.0% 90.0% 80.0%

(C) Annual Hours 8,760 8,760 8,760

(D) Annual Electricity Generation (kWh) 36,449,954,187 17,600,991,128 46,211,427,727

(E) Competing Heat Rate (Btu/kWh) 10,107 10,107 10,107

(F) Annual Output (Trillion Btu) 177.9 368.4 467.1 

(G) Carbon Coefficient (MMTCB/Trillion Btu) 0.01783 0.01783 0.01783

(H) Annual Carbon Displaced (MMTC) 6.569 3.172 8.328

Technology Hydropower PV Solar Thermal

(A) Capacity (kW) 78,312,583 280,355 388,893

(B) Capacity Factor (%) 44.2% 22.5% 24.4%

(C) Annual Hours 8,760 8,760 8,760

(D) Annual Electricity Generation (kWh) 303,176,455,525 552,579,314 831,235,472

(E) Competing Heat Rate (Btu/kWh) 10,107 10,107 10,107

(F) Annual Output (Trillion Btu) 5.6 3,064.2 8.4 

(G) Carbon Coefficient (MMTCB/Trillion Btu) 0.01783 0.01783 0.01783

(H) Annual Carbon Displaced (MMTC) 54.635 0.100 0.128

Source: 

National Renewable Energy Laboratory. Power Technologies Energy Data Book, Table 12.1, 

http://www.nrel.gov/analysis/power_databook/chapter12.html

Original sources: Capacity: EIA, Annual Energy Outlook 2005, DOE/EIA-0383 (2005) (Washington, DC, 

February 2005), Table A16, 2005. 

Capacity Factors: Hydropower calculated from EIA, Annual Energy Outlook 2005, DOE/EIA-0383 (2005) 

(Washington, DC, February 2005), Table A16. All others based on DOE, Renewable Energy 

Technology Characterizations, EPRI TR-109496, 1997 and Program data. 

Heat Rate: EIA, Annual Energy Review 2003, DOE/EIA-0384(2003) (Washington, DC, September 2004), 

Table A6. 

Carbon Coefficient: DOE, GPRA2003 Data Call, Appendix B, page B-16, 2003. 

Note: Capacity values exclude combined-heat-and-power (CHP) data but include end-use sector 

(industrial and commercial) non-CHP data. Competing heat rate from fossil-fueled steam-electric plants 

heat rate. 
 83

Biomass Energy Data Book: Edition 1 

Table 3.14 

Number of Home Electricity Needs Met Calculation, 2006 

Conversion Formula: Step 1 Capacity (A) x Capacity Factor (B) x Annual Hours (C) = Annual Electricity Generation (D)

Step 2 Annual Electricity Generation (D) / Average Consumption (E) = Number of Households (F)

Technology Wind Geothermal Biomass Hydropower PV

Solar 

Thermal

(A) Capacity (kW) 11,558,205 2,232,495 6,594,096 78,312,583 280,355 388,893

(B) Capacity Factor (%) 36.0% 90.0% 80.0% 44.2% 22.5% 24.4%

(C) Annual Hours 8,760 8,760 8,760 8,760 8,760 8,760

(D) Annual Electricity Generation 

(kWh) 36,449,954,187 17,600,991,128 46,211,427,727 303,176,455,525 552,579,314 831,235,472

(E) Average Annual Household 

Electricity Consumption (kWh) 11,576 11,576 11,576 11,576 11,576 11,576

(F) Number of Households 3,148,804 1,520,497 3,992,068 26,190,515 47,736 71,808

Source: 

National Renewable Energy Laboratory, Power Technologies Data Book, Table 12.2, 

http://www.nrel.gov/analysis/power_databook/chapter12.html. 

Original sources: Capacity: EIA, Annual Energy Outlook 2006, DOE/EIA-0383 (2006) (Washington, D.C., 

February 2006), Table A16, 2006. 

Capacity Factors: Hydropower calculated from EIA, Annual Energy Outlook 2005, DOE/EIA-0383 (2005) 

(Washington, D.C., February 2005), Table A16. All others based on DOE, Renewable Energy 

Technology Characterizations, EPRI TR-109496, 1997 and Program data. 

Household electricity Consumption: Calculated from EIA, Annual Energy Outlook 2006, DOE/EIA-0383 

(2006) (Washington, D.C., February), Tables A4 and A8, 2006. 

Note: Capacity values exclude combined-heat-and-power (CHP) data but include end-use sector 

(industrial and commercial) non-CHP data. 
84 

Biomass Energy Data Book: Edition 1 

A tax credit for biomass power production from closed-loop biomass was first enacted as part of the 

comprehensive Energy Policy Act of 1992. Subsequent acts extended the credit to various other types of 

renewable energy facilities. Because no biomass power facilities were able to meet the closed-loop 

biomass definition of the 1992 Act, the tax credit was expanded in 2005 to include open-loop biomass at 

1⁄2 the tax credit available to a closed-loop facility. Closed and open-loop biomass are defined as follows: 

Closed-loop biomass - Crops grown, in a sustainable manner, for the purpose of optimizing their value 

for bioenergy and bioproduct uses. This includes annual crops such as maize and wheat, and perennial 

crops such as trees, shrubs, and grasses such as switchgrass. 

Open-loop biomass - Biomass that can be used to produce energy and bioproducts even though it was 

not grown specifically for this purpose. Examples of open-loop biomass include agricultural livestock 

waste and residues from forest harvesting operations and crop harvesting.

Table 3.15 

Major Federal Biomass Power Incentives

Title Code Fuel Type Incentive Qualifying Period Limitsc

Production Tax 

Credit – extensiona

IRC §45 Closed-loop biomass $0.019/kWhrb

 -2005 In service between 2003 - 

2007. 10 year max

phase out above 8¢/kWhr 

(inflation adjusted)

Production Tax 

Credit – extensiona

IRC §45 Closed-loop biomass, 

co-fired with coal or 

other biomass

$0.019/kWhrb

 -2005 Anytime before 2008, 10 

year max from 10/23/2004 

or in-service date

Same as above

Production Tax 

Credit – extensiona 

IRC §45 Open-loop biomass - 

existing

$0.009/kWhrb (2005) In service before 1/1/2005, 

5 year limit

Credit to operator not owner; 

phase out above 8¢/kWhr; 

exclusion of biomass co-fired 

with fossil fuel 

Production Tax 

Credit – extensiona

IRC §45 Open-loop biomass - 

new

$0.009/kWhrb (2005) In service between 

8/8/2005-12/31/2007, 10 

year limit

Same as above

Renewable Energy 

Production Incentive 

(REPI)d

42 USCS § 13317 Biomass except for 

MSW combustion

$0.015/kWhr (1993 $ 

indexed for inflation)

Renewed appropriations 

for 2006 - 2026

Available to non-profit 

electrical co-ops, public 

utilities, government facilities

More information on this can be found at the following websites: 

http://www.msi-network.com/content/cmsdoc496.asp

Internal Revenue Code bulletins on §45 at http://www.irs.gov/irb/2004-17_IRB/ar09.html and at: 

http://www.irs.gov/irb/2005-20_IRB/ar08.html

A business can take the credit by completing Form 8835 (http://www.irs.gov/pub/irspdf/f8835.pdf)“Renewable Energy Production Credit.” 

_______________________ 

a

 The 2004 American Jobs Creation Act and the 2005 Energy Policy Act extended the Production 

Tax Credit §45 so that it now includes wind, open and closed loop biomass, geothermal energy, solar 

energy, small irrigation power, landfill gas, municipal solid waste, and qualified hydropower production, as 

well as refined coal production and Indian coal production facilities. b

 Annual inflation adjusted rate above the base §45 tax credit rate of $0.015/kWhr or 1⁄2 the adjusted 

rate in the case of open-loop biomass, small irrigation power facilities, landfill gas facilities, hydropower 

facilities. Rates are adjusted annually. c

 More limits and explanations of limits can be found at http://www.msinetwork.com/content/cmsdoc496.asp and in the August 2005 issue of Bioenergy Update. d

 More information on REPI, including reauthorizing language in Section 202 of the Energy Policy 

Act of 2005 is available at http://www.dsireusa.org. 
 85

Biomass Energy Data Book: Edition 1 

A Renewable Portfolio Standard (RPS) is a policy that obligates a retail electricity supplier to include 

renewable resources in its electricity generation portfolio. Retail suppliers can meet the obligation by 

constructing or owning eligible renewable resources or purchasing the power from eligible generators. To 

date, 16 states have adopted RPS policies or renewable purchase obligations. All these states include 

some type of biomass as a qualifying renewable energy technology. Initially, most states adopted RPS 

policies as part of electric industry restructuring; but, more recently, a number of states have implemented 

policies by legislation or proceedings that are separate from restructuring activities. In conjunction with 

system benefits funds, RPS policies are expected to lead to the development of more than 17,000 MW of 

new renewable energy capacity by 2017. 

Figure 3.1 

States with Renewable Portfolio Standards 

Source: 

National Renewable Energy Laboratory, Power Technologies Energy Data Book, Chapter 3, 

http://www.nrel.gov/analysis/power_databook/chapter3.html
86 

Biomass Energy Data Book: Edition 1 

Almost half of the states have renewable portfolio standards and purchase requirements; the standards 

and requirements vary widely among those states that do have renewable portfolio requirements. 

Table 3.16 

State Renewable Portfolio Standards and Purchase Requirements 

State

Purchase 

Requirements Eligible Resources Credit Trading Penalties

Arizona 15% by 2015 (of this 

30% must be customer 

sited)

PV and solar thermal 

electric, R&D, solar hot 

water, and in-state landfill 

gas, wind, and biomass.

No central credit trading

system

Under consideration

California Investor-owned utilities 

must add minimum 1% 

annually to 20% by 

2017.

Biomass, solar thermal, 

photovoltaic, wind, 

geothermal, existing hydro < 

30MW, fuel cells using 

renewable fuels, digester 

gas, landfill gas, ocean 

energy.

WREGIS system under 

development

At discretion of CPUC

Colorado 10% by 2015 Photovoltaics, Landfill Gas, 

Wind, Biomass, Geothermal 

Electric, Anaerobic 

Digestion, Small 

Hydroelectric, Fuel Cells 

(Renewable Fuels)

WREGIS system under 

development

To be determined

Connecticut 3% Class I or II 

Technologies by Jan 1, 

2004. Class I 1% Jan 1,

2004 increasing to 

1.5% by 2005, 2% by 

2006, 3.5% by 2007, 

5% by 2008, 6% by 

2009, and 7% by Jan 1, 

2010

Class I: solar, wind, new 

sustainable biomass, 

landfill gas, fuel cells, ocean

thermal, wave, tidal, 

advanced renewable energy 

conversion technologies, 

new run of river hydro 

(<5MW). Class II: licensed 

hydro, MSW, and other 

biomass.

Yes. Using NEPOOL 

Generation Information 

System.

Penalty of 5.5¢/kWh 

paid to the Renewable 

Energy Investment 

Fund for the 

development of Class I 

renewables

Delaware 10% by 2019 Solar Thermal Electric, 

Photovoltaics, Landfill Gas, 

Wind, Biomass, 

Hydroelectric, Geothermal 

Electric, Anaerobic 

Digestion, Tidal Energy, 

Wave Energy, Ocean 

Thermal, Fuel Cells 

(Renewable Fuels)

Yes. GATS Penalty of 2.5¢/kWh 

(increases to 5¢/kWh 

for multi-year 

noncompliance)

District of Columbia 11% by 2022 (0.386% 

solar)

Solar Thermal Electric, 

Photovoltaics, Landfill Gas, 

Wind, Biomass, 

Hydroelectric, Geothermal 

Electric, Municipal Solid 

Waste, Cofiring, Tidal 

Energy, Wave Energy, 

Yes. GATS. Electric 

delivery requirement to 

PJM

Penalty of 2.5¢/kWh for 

tier 1 resources, 

1¢/kWh for tier II, and 

30¢/kWh for PV

Hawaii 8% by end of 2005, 

10% by 2010, 15% by 

2015 and 20% by 2020

Wind, solar, hydropower, 

biomass including landfill 

gas, waste to energy, and 

fuels derived from organic 

sources, geothermal, ocean 

energy, fuel cells using 

hydrogen from renewables

Unspecified Unspecified: standard to 

be revisited if utilities 

can not meet it in costeffective manner

Iowa Investor-owned utilities 

to purchase 105 MW 

(~2% of 1999 sales)

Solar, wind, methane 

recovery, and biomass

No Unspecified

Continued on next page
 87

Biomass Energy Data Book: Edition 1 

Table 3.16 (Continued) 

State Renewable Portfolio Standards and Purchase Requirements 

State Purchase Requirements Eligible Resources Credit Trading Penalties

Maine 30% of retail sales in 2000 

and thereafter. PUC will 

revisit within 5 years.

Fuel cells, tidal, solar, wind, 

geothermal, hydro, biomass, 

and MSW (<100MW); high 

efficiency cogeneration. 

Selfgeneration is not eligible. 

Resource supply under this 

definition exceeds RPS 

requirement.

Yes. NEPOOL 

Generation 

Information System.

Possible sanctions at

discretion of PUC

Maryland 3.5% by 2006 with 1% from 

Tier 1 sources, Tier 1 

increasing by 1% every 

other year from 2007 to 

2018, Tier II remains at 

2.5%, 7.5% total by 2019 

and in subsequent years.

Tier 1: solar, wind, geothermal, 

qualifying biomass, small 

hydropower (<30MW), and 

landfill methane Tier II: 

existing large hydropower, 

poultry litter incineration, 

existing waste to energy

Yes Alternative 

Compliance fee of 

2¢/kWh for Tier 1 

and 1.5¢/kWh for 

Tier 2 paid to 

Maryland Renewable 

Energy Fund

Massachusetts 1% of sales to enduse 

customers from new 

renewables in 2003, 

+0.5%/yr to 4% in 2009 

1%/yr increase thereafter 

until determined by Division

of Energy Resources

New renewables placed into 

commercial operation after 

1997, including solar, wind, 

ocean thermal, wave, tidal, fuel 

cells using renewable fuels, 

landfill gas, and low-emission

advanced biomass. Excess 

production from existing 

generators over historical 

baseline eligible.

Yes. Using NEPOOL 

Generation 

Information System.

Entities may comply 

by paying 5¢/kWh. 

Non-complying 

retailers must submit 

a compliance plan. 

Revocation or 

suspension of 

license is possible.

Minnesota (Not true RPS) Applies to 

Xcel Energy only: 425 MW 

wind by 2002 and 110 MW 

biomass. Additional 400 

MW wind by 2006 and 300 

MW by 2010

Wind, biomass No, other than 

standard regulatory 

oversight.

No

Montana 5% in 2008; 10% in 2010; 

15% in 2015

Solar Thermal Electric, 

Photovoltaics, Landfill Gas, 

Wind, Biomass, Hydroelectric, 

Geothermal Electric, Anaerobic

Digestion, Fuel Cells 

(Renewable Fuels)

Yes. Electricity must 

be delivered to MT.

Penalty of 1¢/kWh 

goes to universal lowincome energy 

assistance fund.

Nevada 6% in 2005, rising to 20% 

by 2015.

Solar, wind, geothermal, & 

biomass (includes 

agricultural waste, wood, 

MSW, animal waste and 

aquatic plants). Distributed 

resources receives extra credit 

(1.15).

Yes. Financial penalties 

may be applied for 

noncompliance.

New Jersey Class I or II: 2.5% by 2008

Class I: 4% by 2008, with 

solar requirement of 0.16% 

retail sales (90MW)

Goal of 20% by 2020.

Class I.: Solar, PV, wind, fuel 

cells, geothermal, wave, tidal, 

landfill methane, and 

sustainable biomass. Class II: 

hydro <30 MW and MSW 

facilities that meet air pollution 

requirements.

Yes. GATS. Alternative 

Compliance Payment

of 5¢/kWh, 30¢/kWh 

for solar.

Continued on next page
88 

Biomass Energy Data Book: Edition 1 

Table 3.16 (Continued) 

State Renewable Portfolio Standards and Purchase Requirements 

State Purchase Requirements Eligible Resources Credit Trading Penalties

New Mexico 5% of retail sales by 2006. 

Increase by 1%/yr to 10% 

by January 1, 2011 and 

thereafter.

Solar, wind, hydro (<=5 MW), biomass, 

geothermal, and fuel cells. 1 kWh solar 

=3kWh; 1 kWh biomass, geothermal, 

landfill gas, or fuel cells =2 kWh toward 

compliance.

Yes. RECs valid 

for 4 years from 

date of issuance.

At discretion of PUC

New York 25% by 2013; 1% voluntary 

standard; 2% of total 

incremental RPS 

requirement (7.71%) is setaside for customer-sited

Photovoltaics, Landfill Gas, Wind, 

Biomass, Hydroelectric, Fuel Cells, 

CHP/Cogeneration, Biogas, Liquid 

Biofuel, Anaerobic Digestion, Tidal 

Energy, Wave Energy, Ocean Thermal

Possibly. 

Electricity must be

delivered to NY.

Unspecified

Pennsylvania 18% by 2020; 8% Tier 1 

and 10% Tier II

Solar set-aside of 0.5% by 

2020

Solar Water Heat, Solar Space Heat, 

Solar Thermal Electric, Solar Thermal 

Process Heat, Photovoltaics, Landfill 

Gas, Wind, Biomass, Hydroelectric, 

Geothermal Electric, Fuel Cells, Municipal 

Solid Waste, CHP/Cogeneration, Waste 

Coal, Coal Mine Methane, Coal 

Gasification, Anaerobic Digestion, Other 

Distributed Generation Technologies.

Yes. GATS Penalty of 4.5¢/kWh, for 

solar penalty is 200% of 

PV REC value.

Rhode Island 16% by 2020; 3% by 2003, 

increasing 0.5% annually 

2008-2010, increasing 1% 

annually 2011-2014, 

increasing 1.5% annually 

2015-2019

Solar, wind, eligible biomass, including 

cofiring, geothermal, small hydropower, 

ocean, fuel cells using hydrogen derived 

from renewables.

Yes. Using 

NEPOOL 

Generation 

Information 

System.

Penalty of 5¢/kWh can be 

made to Renewable 

Energy Development 

Fund.

Texas 5,880 MW by 2015 (5000 

MW new)

Target of at least 500 MW 

from renewables other than

wind

Solar, wind, geothermal, hydro, wave, 

tidal, biomass, including landfill gas. 

New (operational after Sept. 1, 1999) or 

small (<2MW) facilities eligible.

Yes. ERCOT REC

Trading System.

Lesser of 5¢/kWh or 

200% of average market 

value of renewable 

energy credits.

Wisconsin 0.5% by 2001 increasing to 

2.2% by 2011 (0.6% can 

come from facilities 

installed prior to 1998).

Wind, solar, biomass, geothermal, tidal, 

fuel cells that use renewable fuel, & hydro 

under 60 MW. Eligibility may be xtended 

by PUC.

Yes. Utilities with 

excess RECs can 

trade or bank 

them.

Penalty of $5,000-

$500,000 is allowed in 

legislation.

Source: 

National Renewable Energy Laboratory, Power Technologies Energy Data Book, Chapter 3, Table 3.3.1, 

http://www.nrel.gov/analysis/power_databook/chapter3.html
 89

Biomass Energy Data Book: Edition 1 

In addition to State Renewable Portfolio Standards and Purchase Requirements, there are also some 

nonbinding goals that three states have adopted. 

Table 3.17 

State Renewable Energy Goals (Nonbinding) 

State Purchase Requirements Eligible Resources

Illinois 8% by 2013 (75% wind) Solar Water Heat, Solar Thermal Electric, 

Photovoltaics, Landfill Gas, Wind, Biomass, 

Hydroelectric, CHP/Cogeneration, "Other Such 

Alternative Sources of Environmentally Preferable 

Energy"

Minnesota 1% by 2005 increasing by at least 1%/year 

to 10% by 2015

Wind, solar, hydro (<60 MW), and biomass

Vermont Meet growth in electricity demand from 

2005-2013 with renewable energy sources 

(becomes mandatory in 2013 if not met).

Solar Thermal Electric, Photovoltaics, Landfill Gas, 

Wind, Biomass, Hydroelectric, Anaerobic 

Digestion, Fuel Cells (Renewable Fuels)

Source: 

National Renewable Energy Laboratory, Power Technologies Energy Data Book, Chapter 3, Table 3.3.2, 

http://www.nrel.gov/analysis/power_databook/chapter3.html
90 

Biomass Energy Data Book: Edition 1 
 91

Biomass Energy Data Book: Edition 1 

4. BIOREFINERIES 

BRIEF OVERVIEW 

As a petroleum refinery uses petroleum as the major input and processes it into many different products, 

a biorefinery uses lignocellulosic biomass as the major input and processes it into many different 

products. Currently, wet-mill corn processing and pulp and paper mills can be categorized as biorefineries 

since they produce multiple products from biomass. Research is currently being conducted to foster new 

industries to convert biomass into a wide range of products, including ones that would otherwise be made 

from petrochemicals. The idea is for biorefineries to produce both high-volume liquid fuels and high-value 

chemicals or products in order to address national energy needs while enhancing operation economics. 

Two of the most promising emerging biorefinery platforms are the sugar platform and the thermochemical 

platform (also known as the syngas platform). Sugar platform biorefineries would break biomass down 

into different types of component sugars for fermentation or other biological processing into various fuels 

and chemicals. Thermochemical biorefineries would convert biomass to synthesis gas (hydrogen and 

carbon monoxide) or pyrolysis oil, the various components of which could be directly used as fuel. 

The diagram below illustrates the biorefinery concept. 

Source: 

National Renewable Energy Laboratory, Biomass Program, June 2006, 

http://www.nrel.gov/biomass/biorefinery.html
92 

Biomass Energy Data Book: Edition 1 

The Department of Energy Biomass Program is currently focusing efforts on two biorefinery platforms – 

sugar and thermochemical – but other platforms also have potential for expanding the use of biomass 

energy. 

Table 4.1 

Biorefinery Platforms 

Platform Description

Sugar Platform Developing technology to break cellulose and hemicellulose down into their component sugars. 

Those sugars can then be processed to fuel ethanol or other building block chemicals. Lignin can 

either be burned to provide process heat and electricity or can itself be converted to fuels and 

chemicals

Thermochemical 

Platform

Converting solid biomass to a gaseous or liquid fuel by heating it with limited oxygen prior to 

combustion can greatly increase the overall efficiency, and also make it possible to instead convert 

the biomass to valuable chemicals or materials. Developing thermochemical technologies will allow 

a more efficient means of tapping the enormous energy potential of lignocellulosic biomass.

Biogas Platform Decomposing biomass with natural consortia of microorganisms in closed tanks known as 

anaerobic digesters produces methane (natural gas) and carbon dioxide. This methane-rich biogas 

can be used as fuel or as a base chemical for biobased products.

Carbon-Rich Chains 

Platform

Natural plant oils such as soybean, corn, palm, and canola oils are in wide use today for food and 

chemical applications. Transesterification of vegetable oil or animal fat produces fatty acid methyl 

ester, commonly known as biodiesel. The glycerin byproduct of biodiesel, and the fatty acids from 

which it is made, could all be platform chemicals for biorefineries.

Plant Products 

Platform

Selective breeding and genetic engineering can develop plant strains that produce greater amounts

of desirable feedstocks or chemicals or even compounds that the plant does not naturally produce 

— getting the biorefining done in the biological plant rather than the industrial plant.

Source: 

U. S. Department of Energy, Energy Efficiency and Renewable Energy, Biomass Program, June 2006, 

http://www1.eere.energy.gov/biomass/index.html

Note: This is not an exhaustive list of platforms. 
 93

Biomass Energy Data Book: Edition 1 

In April 2002 the U.S. Department of Energy solicited projects for “Biomass Research and Development 

for the Production of Fuels, Power, Chemicals and Other Economical and Sustainable Products.” The 

following six projects, which will be completed in three to four years, were selected to assist in the 

development of sugar platform research. 

Table 4.2 

U.S. Department of Energy Sugar Platform Biorefinery Projects

Project name Partner Project cost Project Description

A Second Generation Dry 

Mill Biorefinery

Broin and Associates $5.4 million Separate bran, germ, and endosperm from corn kernels prior to making 

ethanol from the remaining starch. Investigate making high-value products, 

as well as ethanol and animal feed from the separated fractions.

A New Biorefinery Platform 

Intermediate

Cargill, Inc. $6 million Develop fermentative organisms and processes to ferment carbohydrates to 

3-hydroxypropionic acid (3-HP) and then make a slate of products from the 3-

HP.

Making Industrial Biorefining

Happen

Cargill-Dow LLC $26 million Develop and build a pilot-scale biorefinery that produces sugars and 

chemicals such as lactic acid and ethanol from grain. 

Integrated Corn-Based 

Biorefinery

E.I. du Pont de 

Nemours & Co., Inc.

$18.2 million Development of a biorefinery concept that converts both starch (such as 

corn) and lignocellulose (such as corn stover) to fermentable sugars for 

production of value added chemicals (like 1,3 propanediol) and fuel ethanol.

Advanced Biorefining of 

Distillers’ Grain and Corn 

Stover Blends: PreCommercialization of a 

Biomass-Derived Process 

Technology

High Plains Corporation 

(now Abengoa S.A.)

$17.7 million Develop a process for pretreating a blend of distillers’ grain (animal feed coproduct from corn ethanol production) and stover to allow ethanol production 

from both, while leaving a high-protein animal feed. A large-scale pilot facility 

will be built for integration with High Plains’ ethanol plant in York, Nebraska.

Separation of Corn Fiber 

and Conversion to Fuels 

and Chemicals Phase II: 

Pilot-Scale Operation

National Corn Growers 

Association

$2.4 million Under a previous DOE-funded project, a process was developed for 

separation of hemicellulose, protein, and oil from corn fiber. This project will 

pilot-scale test and validate this process for commercial use.

Source: 

U. S. Department of Energy, Energy Efficiency and Renewable Energy, Biomass Program, June 2006, 

http://www1.eere.energy.gov/biomass/sugar_biorefineries.html
94 

Biomass Energy Data Book: Edition 1 
 95

Biomass Energy Data Book: Edition 1 

5. FEEDSTOCKS 

PRIMARY BIOMASS FEEDSTOCKS 

Primary biomass is produced directly by photosynthesis and includes all terrestrial plants now used for 

food, feed, fiber and fuelwood. All plants in natural and conservation areas (as well as algae and other 

aquatic plants growing in ponds, lakes, oceans, or artificial ponds and bioreactors) are also considered 

primary biomass. However, only a small portion of the primary biomass produced will ever be harvested 

as feedstock material for the production of bioenergy and bioproducts.

Primary biomass feedstocks are thus primary biomass that is harvested or collected from the field or 

forest where it is grown. Examples of primary biomass feedstocks currently being used for bioenergy 

include grains and oilseed crops used for transportation fuel production, plus some crop residues (such 

as orchard trimmings and nut hulls) and some residues from logging and forest operations that are 

currently used for heat and power production. In the future it is anticipated that a larger proportion of the 

residues inherently generated from food crop harvesting, as well as a larger proportion of the residues 

generated from ongoing logging and forest operations, will be used for bioenergy. Additionally, as the 

bioenergy industry develops, both woody and herbaceous perennial crops will be planted and harvested 

specifically for bioenergy and bioproducts end-uses. 

Because this version of the Data Book is focusing primarily on the bioenergy industry as it exists today, 

including the biomass feedstocks actually used, only information on the grain and oilseeds crops are 

included. It would be desirable to include information on the amount and types of crop residues and forest 

logging, or pulp fiber residues currently being used for energy on a state by state basis, but that 

information is not readily available. Clearly there is also no nationwide source of information on woody or 

herbaceous crops being used for energy since this is occurring only on a very small scale in a few 

isolated experimental situations. 

This Data Book covers only current usage of biomass and does not attempt to address the potential for 

biomass feedstock. Nontheless, other sources of information do exist concerning the future potential of 

biomass. Tables, maps and explanations for assumptions behind the potential biomass resource 

calculations that have been performed by Oak Ridge National Laboratory biomass economists can be 

found on the Bioenergy Feedstock Information Network (BFIN) website at www.bioenergy.ornl.gov.

Source: Lynn Wright, Oak Ridge, TN. 
96 

Biomass Energy Data Book: Edition 1 

USDA’s corn baseline projections show a continuing rise in bushels of corn allocated to fuel alcohol use, 

a continuing increase in corn yields, a slight increase in corn acreage, and a continuing increase in net 

returns (over variable costs) through 2014. This analysis is updated annually. 

Table 5.1 

Corn Baseline Projections, 2004—2015 

Item 2003/04 2004/05 2005/06 2006/07 2007/08 2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15

Area (million acres):

 Planted acres 78.7 81.0 81.0 81.0 81.5 82.0 82.5 83.0 83.5 84.0 84.0 84.0

 Harvested acres 71.1 73.3 73.6 73.6 74.1 74.6 75.1 75.6 76.1 76.6 76.6 76.6

Yields (bushels per acre):

 Yield/harvested acre 142.2 160.2 145.6 147.4 149.2 151.0 152.8 154.6 156.4 158.2 160.0 161.8

Supply and use (million bushels):

 Beginning stocks 1,087 958 1,819 1,724 1,549 1,394 1,264 1,159 1,109 1,109 1,164 1,194

 Production 10,114 11,741 10,715 10,850 11,055 11,265 11,475 11,690 11,900 12,120 12,255 12,395

 Imports 14 15 15 15 15 15 15 15 15 15 15 15

 Supply 11,215 12,714 12,549 12,589 12,619 12,674 12,754 12,864 13,024 13,244 13,434 13,604

 Feed & residual 5,783 6,075 5,800 5,800 5,825 5,850 5,900 5,950 6,000 6,050 6,125 6,200

 Food, seed, & industrial 2,577 2,770 2,875 2,965 3,000 3,035 3,070 3,105 3,140 3,180 3,215 3,250

 Fuel alcohol use 1,204 1,370 1,470 1,550 1,575 1,600 1,625 1,650 1,675 1,700 1,725 1,750

 Domestic 8,360 8,845 8,675 8,765 8,825 8,885 8,970 9,055 9,140 9,230 9,340 9,450

 Exports 1,897 2,050 2,150 2,275 2,400 2,525 2,625 2,700 2,775 2,850 2,900 2,975

 Total use 10,257 10,895 10,825 11,040 11,225 11,410 11,595 11,755 11,915 12,080 12,240 12,425

 Ending stocks 958 1,819 1,724 1,549 1,394 1,264 1,159 1,109 1,109 1,164 1,194 1,179

 Stocks/use ratio, percent 9.3 16.7 15.9 14.0 12.4 11.1 10.0 9.4 9.3 9.6 9.8 9.5

Prices (dollars per bushel):

 Farm price 2.42 1.90 2.00 2.15 2.25 2.35 2.40 2.45 2.45 2.45 2.45 2.45

 Loan rate 1.98 1.95 1.95 1.95 1.95 1.95 1.95 1.95 1.95 1.95 1.95 1.95

Variable costs of production (dollars):

 Per acre 158.85 164.93 168.05 170.46 171.98 173.52 175.16 176.96 178.85 180.75 182.67 184.65

 Per bushel 1.12 1.03 1.15 1.16 1.15 1.15 1.15 1.14 1.14 1.14 1.14 1.14

Returns over variable costs (dollars per acre):

 Net returnsa 185.28 179.50 144.99 146.45 163.72 181.33 191.56 201.81 204.33 206.84 209.33 211.76

Source: 

USDA Agricultural Baseline Projections to 2014, February 2005 (OCE-2005-1), Table 8 - U.S. corn, 

http://usda.mannlib.cornell.edu/data-sets/baseline/2005/index.html

_______________________ 

a

 Net returns include estimates of marketing loan benefits. 
 97

Biomass Energy Data Book: Edition 1 

The figure below shows the dramatic rise in demand for corn as a feedstock for ethanol production that 

has occurred over the last several years. 

Figure 5.1 

Corn Used for Ethanol Production, 1985—2005

271

349

396

429

481

526

566

628

706

996

1,168

1,323

1,575

0

200

400

600

800

1,000

1,200

1,400

1,600

1,800

1985 1990 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005

Million Bushels

Source: 

National Corn Growers Association, The World of Corn, 2005, http://www.ncga.com, Also found at: 

http://www.ethanolrfa.org/industry/outlook/ 
98 

Biomass Energy Data Book: Edition 1 

In 2005, ethanol production accounted for about 15% of the overall corn consumption. Corn used for 

feed/residual is by far the largest usage. 

Figure 5.2 

Corn Usage by Segment, 2005

Source: 

National Corn Growers Association, The World of Corn, 2005, 

http://www.ncga.com/WorldOfCorn/main/consumption1.asp

6,000

1,850

1,575

535

285

220

190

135

20

Feed/Residual

Export

Ethanol

HFCS

Starch

Sw eeteners

Cereal/Other

Alcohol

Seed

Million Bushels
 99

Biomass Energy Data Book: Edition 1 

In the baseline year of 2001, 7.5% of all corn grain produced was used for ethanol production. Over the 

past 10 years the corn acres planted have varied between about 71 and 81 million acres; acreage 

variation is related to feed and export demands, crop subsidy programs, previous year grain prices and 

animal demand for silage. Yield variation relates to climate variation and improved varieties. The year 

2004 provided an unusually favorable climate for high corn yields over much of the corn belt. 

Table 5.2 

Corn: Area, Yield, Production, and Value, 1996-2005 

1,000 

Acres 1,000 Acres Bushels 1,000 Bushels Dollars 1,000 Dollars

1,000 

Acres Tons 1,000 Tons

1996 79,229 72,644 127.1 9,232,557 2.71 25,149,013 5,607 15.4 86,581

1997 79,537 72,671 126.7 9,206,832 2.43 22,351,507 6,054 16.1 97,192

1998 80,165 72,589 134.4 9,758,685 1.94 18,922,084 5,913 16.1 95,479

1999 77,386 70,487 133.8 9,430,612 1.82 17,103,991 6,037 15.8 95,633

2000 79,551 72,440 136.9 9,915,051 1.85 18,499,002 6,082 16.8 102,156

2001 75,702 68,768 138.2 9,502,580 1.97 18,878,819 6,142 16.6 101,992

2002 78,894 69,330 129.3 8,966,787 2.32 20,882,448 7,122 14.4 102,293

2003 78,603 70,944 142.2 10,089,222 2.42 24,476,803 6,583 16.3 107,378

2004 80,929 73,631 160.4 11,807,086 2.06 24,381,294 6,101 17.6 107,293

2005 a 81,759 75,107 147.9 11,112,072 1.90 21,040,707 5,920 18 106,311

Year

Area 

Planted 

for all 

purposes

Corn for grain Corn for silage

Marketing 

year 

average 

price per 

bushel

Area 

harvested

Yield per 

harvested 

acre Production Production

Value of 

production

Area 

Harvested

Yield per 

harvested 

acre

Source: 

USDA, 2006 Agricultural Statistics, Table 1-34, 

http://www.nass.usda.gov/Publications/Ag_Statistics/index.asp

_______________________ 

a

 Preliminary. 
100 

Biomass Energy Data Book: Edition 1 

Production of sufficient quantities of corn to support ethanol production facilities occurs primarily in the 

mid-western states. Yields vary considerably across the states, high yields in the western states occur 

under irrigation. 

Table 5.3 

Corn: Area, Yield, and Production, by State, 2003—2005 

2002 2003 2004a 2002 2003 2004a 2002 2003 2004a

1,000 

Acres

1,000 

Acres

1,000 

Acres

1,000 

Acres

1,000 

Acres

1,000 

Acres Bushels Bushels Bushels

1,000 

Bushels

1,000 

Bushels

1,000 

Bushels

Alabama 220 220 220 190 195 200 122 123 119 23,180 23,985 23,800

Arizona 47 53 50 22 27 22 190 180 195 4,180 4,860 4,290

Arkansas 365 320 240 350 305 230 140 140 131 49,000 42,700 30,130

California 530 540 540 140 150 110 160 175 172 22,400 26,250 18,920

Colorado 1,080 1,200 1,100 890 1,040 950 135 135 148 120,150 140,400 140,600

Connecticut 30 30 28 b b b b b b b b b

Delaware 170 160 160 162 153 154 123 152 143 19,926 23,256 22,022

Florida 75 70 65 39 32 28 82 90 94 3,198 2,880 2,632

Georgia 340 335 270 290 280 230 129 130 129 37,410 36,400 29,670

Idaho 190 230 235 50 75 60 140 170 170 7,000 12,750 10,200

Illinois 11,200 11,750 12,100 11,050 11,600 11,950 164 180 143 1,812,200 2,088,000 1,708,850

Indiana 5,600 5,700 5,900 5,390 5,530 5,770 146 168 154 786,940 929,040 888,580

Iowa 12,300 12,700 12,800 11,900 12,400 12,500 157 181 173 1,868,300 2,244,400 2,162,500

Kansas 2,900 3,100 3,650 2,500 2,880 3,450 120 150 135 300,000 432,000 465,750

Kentucky 1,170 1,210 1,250 1,080 1,140 1,180 137 152 132 147,960 173,280 155,760

Louisiana 520 420 340 500 410 330 134 135 136 67,000 55,350 44,880

Maine 28 28 26 b b b b b b b b b

Maryland 480 490 470 410 425 400 123 153 135 50,430 65,025 54,000

Massachusetts 20 20 20 b b b b b b b b b

Michigan 2,250 2,200 2,250 2,030 1,920 2,020 128 134 143 259,840 257,280 288,860

Minnesota 7,200 7,500 7,300 6,650 7,050 6,850 146 159 174 970,900 1,120,950 1,191,900

Mississippi 550 460 380 530 440 365 135 136 129 71,550 59,840 47,085

Missouri 2,900 2,950 3,100 2,800 2,880 2,970 108 162 111 302,400 466,560 329,670

Montana 68 70 65 17 15 17 140 143 148 2,380 2,145 2,516

Nebraska 8,100 8,250 8,500 7,700 7,950 8,250 146 166 154 1,124,200 1,319,700 1,270,500

Nevada 4 4 5 b b b b b b b b b

New Hampshire 15 15 15 b b b b b b b b b

New Jersey 80 86 80 61 72 62 113 143 122 6,893 10,296 7,564

New Mexico 130 125 140 48 58 55 180 180 175 8,640 10,440 9,625

New York 1,000 980 990 440 500 460 121 122 124 53,240 61,000 57,040

North Carolina 740 820 750 680 740 700 106 117 120 72,080 86,580 84,000

North Dakota 1,450 1,800 1,410 1,170 1,150 1,200 112 105 129 131,040 120,750 154,800

Ohio 3,300 3,350 3,450 3,070 3,110 3,250 156 158 143 478,920 491,380 464,750

Oklahoma 230 250 290 190 200 250 125 150 115 23,750 30,000 28,750

Oregon 51 58 53 30 28 25 170 170 160 5,100 4,760 4,000

Pennsylvania 1,450 1,400 1,350 890 980 960 115 140 122 102,350 137,200 117,120

Rhode Island 2 2 2 b b b b b b b b b

South Carolina 240 315 300 215 295 285 105 100 116 22,575 29,500 33,060

South Dakota 4,400 4,650 4,450 3,850 4,150 3,950 111 130 119 427,350 539,500 470,050

Tennessee 710 680 650 620 615 595 131 140 130 81,220 86,100 77,350

Texas 1,830 1,830 2,050 1,650 1,680 1,850 118 139 114 194,700 233,520 210,900

Utah 55 55 55 13 12 12 155 155 163 2,015 1,860 1,956

Vermont 100 95 95 b b b b b b b b b

Virginia 470 500 490 330 360 360 115 145 118 37,950 52,200 42,480

Washington 130 170 150 70 105 80 195 200 205 13,650 21,000 16,400

West Virginia 48 48 45 27 29 28 115 131 109 3,105 3,799 3,052

Wisconsin 3,750 3,600 3,800 2,850 2,600 2,900 129 136 148 367,650 353,600 429,200

Wyoming 85 90 80 50 50 49 129 131 140 6,450 6,550 6,860

US 78,603 80,929 81,759 70,944 73,631 75,107 142.2 160.4 147.9 10,089,222 11,807,086 11,112,072

Area planted for all purposes

Area harvested Yield per harvested acre Production

Corn for grain

2003 2004 2005a

State

Source: 

USDA, 2006 Agricultural Statistics, Table 1-36, 

http://www.nass.usda.gov/Publications/Ag_Statistics/index.asp

_______________________ 

a

 Preliminary. 

b

 Not estimated. 
 101

Biomass Energy Data Book: Edition 1 

The large majority of U.S. corn grain is produced in just a few mid-western states. The highest 

concentration of corn production is found in central Illinois, northern Iowa/southern Minnesota, and 

eastern Nebraska. 

Figure 5.3 

Corn for Grain, Harvested Acres, 2002

Source: 

U.S. Department of Agriculture, National Agricultural Statistics Service, 

www.nass.usda.gov/research/atlas02/atlas-crops.html
102 

Biomass Energy Data Book: Edition 1 

Currently, planted acres can be related primarily to anticipated market demand; acres harvested for grain 

are always less than planted acres due to silage and crop failure. 

Figure 5.4 

Corn Acres, Planted and Harvested, 1984—2005

Source: 

U.S. Department of Agriculture, National Agricultural Statistics Service, 

www.usda.gov/nass/aggraphs/crops.htm
 103

Biomass Energy Data Book: Edition 1 

Doberman et. al., noted in 2002 that average corn yields have increased linearly at a rate of 1.7 bushels 

per acre (bu/ac) per year. At present that translates to a rate of 1.1% per year, but if the same average 

linear rate continues, the percentage rate will decline. Corn yields must continue to increase at a rate of at 

least 1% per year to meet the demands created by expected population growth. 

In 2002 average corn yields approached 140 bu/ac with progressive farmers routinely harvesting 160 to 

220 bu/ac. Yields rose in the 60’s and 70’s largely due to increasing application of fertilizer to responsive 

corn hybrids; however, after 1980 yield increases were maintained without continued fertilizer increases 

due to significant increases in nutrient use efficiency. In the past 15 years, yields have continued to 

increase due to improved hybrids with greater stress resistance together with improved crop management 

techniques such as conservation tillage, higher plant densities and improved seed qualities. 

Yields at a given site fluctuate as much as 10-15% from year to year due to normal variations in solar 

radiation and temperature regimes assuming suitable moisture levels. Lack of sufficient moisture is the 

most important factor reducing yields in most of the U.S. corn belt where most corn is not irrigated. The 

yield potential of corn continues to be much greater than the average yields currently being obtained in 

most locations in the United States. 

Genetic improvements (particularly in drought resistance) are expected to continue to contribute to yield 

increases, but continued improvements in crop management will be ever more important. Key references 

on yield potential.

Figure 5.5 

Corn Yield, 1975—2005

Source: 

U.S. Department of Agriculture, National Agricultural Statistics Service, 

www.usda.gov/nass/aggraphs/crops.htm
104 

Biomass Energy Data Book: Edition 1 

Figure 5.5 (Continued) 

Corn Yield, 1975—2005

Additional References for Corn Yield: 

Dobermann, A., T. Arkebauer, K. Cassman, J. Lindquist, J. Specht, D. Walters, and H. Yang. 2002. 

Understanding and Managing Corn Yield Potential. Proceedings of the Fertilizer Industry Round 

Table, Charleston, South Carolina. The Fertilizer Industry Round Table, Forest Hill, Maryland, 

October. Retrieved 5 January 2005 from: 

Dobermann, A., T. Arkebauer, K.G. Cassman, R.A. Drijber, J.L. Lindquist, J.E. Specht, D.T. Walters, H. 

Yang, D. Miller, D.L. Binder, G. Teichmeier, R.B. Ferguson, and C.S. Wortmann. 2003. 

Understanding corn yield potential in different environments. p. 67-82. In L.S. Murphy (ed.) Fluid 

focus: the third decade. Proceedings of the 2003 Fluid Forum, Vol. 20. Fluid Fertilizer Foundation, 

Manhattan, KS. 

Both Doberman et al. references can be obtained at the following url: 

http://soilfertility.unl.edu/Materials%20to%20include/Research%20Pubs/Ecological%20Intensificatio

n.htm

Tollenaar, M. and E. A. Lee. Yield potential, yield stability, and stress tolerance in maize. Field Crops 

Research 75 (2002):161-169. 

Duvick, D.N. and K.G. Cassman. 1999. Post-green revolution trends in yield potential of temperature 

maize in the North-Central United States. Crop Sci. 39:1622-1630. 
 105

Biomass Energy Data Book: Edition 1 

Production of food for domestic livestock is the largest single use of corn grain, accounting for nearly half 

of all corn grain produced. Ethanol production is included in the food, seed and industrial category. 

Table 5.4 

Corn: Supply and Disappearance, 1996—2005 

(million bushels) 

Feed and 

residual

Food, 

seed, and

industrial Total Exports

Total 

disappearance

Privately 

held a

Govern -

ment Total

1996 426 9,233 13 9,672 5,277 1,714 6,991 1,797 8,789 881 2 883

1997 883 9,207 9 10,099 5,482 1,805 7,287 1,504 8,791 1,304 4 1,308

1998 1,308 9,759 19 11,085 5,471 1,846 7,318 1,984 9,298 1,775 12 1,787

1999 1,787 9,431 15 11,232 5,664 1,913 7,578 1,937 9,515 1,704 14 1,718

2000 1,718 9,915 7 11,639 5,842 1,957 7,799 1,941 9,740 1,891 8 1,899

2001 1,899 9,503 10 11,412 5,864 2,046 7,911 1,905 9,815 1,590 6 1,596

2002 1,596 8,967 14 10,578 5,563 2,340 7,903 1,588 9,491 1,083 4 1,087

2003 1,087 10,089 14 11,190 5,795 2,537 8,332 1,900 10,232 958 0 958

2004 b 958 11,807 11 12,776 6,162 2,686 8,848 1,814 10,662 2,113 1 2,114

2005 c 2,114 11,112 10 13,236 6,000 2,960 8,960 1,850 10,810 2,425 1 2,426

Domestic use

Disappearance

Year 

(beginning 

September 1)

Supply Ending stocks August 31

Beginning 

stocks Production Imports Total

Source: 

USDA, 2006 Agricultural Statistics, Table 1-37, 

http://www.nass.usda.gov/Publications/Ag_Statistics/index.asp

_______________________ 

a

 Includes quantity under loan and farmer-owned reserve. 

b

 Preliminary. 

c

 Projected as of January 12, 2006, World Agricultural Supply and Demand Estimates. Totals may 

not add due to rounding. 
106 

Biomass Energy Data Book: Edition 1 

Prices of corn used for ethanol production may vary for each mill depending on whether the mills are 

owned by farmers’ cooperatives or whether the corn is purchased on the open market. Prices vary across 

states considerably. 

Table 5.5 

Corn for Grain: Marketing Year Average Price and Value, by State 

2003 2004 2005 2003 2004 2005b

Dollars Dollars Dollars 1,000 Dollars 1,000 Dollars 1,000 Dollars

Alabama 2.36 2.48 2.35 54,705 59,483 55,930

Arizona 3.28 3.03 2.9 13,710 14,726 12,441

Arkansas 2.37 2.39 2.1 116,130 102,053 63,273

California 2.9 2.65 2.75 64,960 69,563 52,030

Colorado 2.49 2.23 2.25 299,174 313,092 316,350

Delaware 2.87 2.19 2.05 57,188 50,931 45,145

Florida 2.55 2.3 2 8,155 6,624 5,264

Georgia 2.45 2.2 2.15 91,655 80,080 63,791

Idaho 2.94 2.82 2.65 20,580 35,955 27,030

Illinois 2.42 2.14 1.95 4,385,524 4,468,320 3,332,258

Indiana 2.53 1.99 1.8 1,990,958 1,848,790 1,599,444

Iowa 2.37 1.99 1.85 4,427,871 4,466,356 4,000,625

Kansas 2.51 2.12 2.1 753,000 915,840 978,075

Kentucky 2.53 2.24 2.05 374,339 388,147 319,308

Louisiana 2.4 2.45 2.25 160,800 135,608 100,980

Maryland 2.83 2.17 2 142,717 141,104 108,000

Michigan 2.37 1.97 1.7 615,821 506,842 491,062

Minnesota 2.35 1.94 1.75 2,281,615 2,174,643 2,085,825

Mississippi 2.28 2.43 2.15 163,134 145,411 101,233

Missouri 2.46 2.03 1.9 743,904 947,117 626,373

Montana 2.65 2.42 2.4 6,307 5,191 6,038

Nebraska 2.39 2.02 1.85 2,686,838 2,665,794 2,350,425

New Jersey 2.81 2.2 2 19,369 22,651 15,128

New Mexico 2.96 2.4 2.5 25,574 25,056 24,063

New York 2.82 2.37 2.05 150,137 144,570 116,932

North Carolina 2.68 2.44 2.25 193,174 211,255 189,000

North Dakota 2.37 1.88 1.8 310,565 227,010 278,640

Ohio 2.45 2.04 1.8 1,173,354 1,002,415 836,550

Oklahoma 2.6 2.53 2.4 61,750 75,900 69,000

Oregon 3.08 2.75 2.6 15,708 13,090 10,400

Pennsylvania 2.96 2.25 2.2 302,956 308,700 257,664

South Carolina 2.7 2.3 2.1 60,953 67,850 69,426

South Dakota 2.28 1.82 1.7 974,358 981,890 799,085

Tennessee 2.37 2.17 1.95 192,491 186,837 150,833

Texas 2.59 2.6 2.5 504,273 607,152 527,250

Utah 2.99 2.56 2.35 6,025 4,762 4,597

Virginia 2.57 2.17 2.1 97,532 113,274 89,208

Washington 3 2.97 2.75 40,950 62,370 45,100

West Virginia 2.72 2.2 2 8,446 8,358 6,104

Wisconsin 2.35 2.15 1.85 863,978 760,240 794,020

Wyoming 2.5 2.48 2.45 16,125 16,244 16,807

US 2.42 2.06 1.9 24,476,803 24,381,294 21,040,707

Marketing year average price per bushel

Statea

Value of production

Source: 

USDA, 2006 Agricultural Statistics. Table 1-39, 

http://www.nass.usda.gov/Publications/Ag_Statistics/index.asp

_______________________ 

a

 States with no data are not listed. 

b

 Preliminary.
 107

Biomass Energy Data Book: Edition 1 

These data show that government subsidies are vital to ensuring a profit to farmers, when land and labor 

opportunity costs are considered. However, many farmers only factor operating costs into the calculation, 

making corn the most profitable commodity crop in most regions of the country. If the residue from corn 

production also had a market as a bioenergy feedstock, then farmers in areas of high corn yield may 

come closer to making a profit without subsidies. 

Table 5.6 

Corn Production Costs and Returns per Planted Acre, 

Excluding Government Payments, 2002—2003a

(dollars per planted acre) 

 Item 2002 2003 2002 2003 2002 2003 2002 2003

Gross value of production

 Primary product: Corn grain 310.88 317.37 326.6 329.7 294.64 296.7 211.85 220.32

 Secondary product: Corn silage 1.94 2.25 1.33 1.36 4.73 5.62 4.55 5.4

 Total, gross value of production 312.82 319.62 327.93 331.06 299.37 302.32 216.4 225.72

Operating costs: 

 Seed 31.84 34.83 31.6 34.89 33.17 35.48 26.18 32.47

 Fertilizer 35.49 43.41 37.24 45 35.51 41.54 23.36 31.31

 Soil conditioners 0.12 0.13 0.09 0.09 0.45 0.49 0 0

 Manure 2.13 2.47 1.37 1.6 8.78 9.95 2.03 2.22

 Chemicals 26.11 26.2 26.22 26.5 25.43 25.77 20.64 20.5

 Custom operationsb 10.79 11.17 9.69 10.09 11.47 12.09 10.38 10.72

 Fuel, lube, and electricity 18.93 23.06 15.28 18.81 17.6 22.31 16.65 20.02

 Repairs 13.91 14.22 12.35 12.63 14.54 14.9 13.83 14.3

 Purchased irrigation water 0.22 0.22 0 0 0 0 2.02 1.94

 Interest on operating capital 1.17 0.82 1.13 0.79 1.24 0.86 0.97 0.71

 Total, operating costs 140.71 156.53 134.97 150.4 148.19 163.39 116.06 134.19

Allocated overhead: 

 Hired labor 3.06 3.14 2.19 2.3 3.63 3.72 5.26 5.3

 Opportunity cost of unpaid labor 25.74 26.53 23.03 23.79 34.17 34.8 21.75 22.62

 Capital recovery of machinery and equipment 55.26 56.67 51.87 53.06 59.43 60.99 51.74 53.78

 Opportunity cost of land (rental rate) 87.44 89.2 98.83 100.28 67.44 68.88 52.28 53.65

 Taxes and insurance 5.42 5.54 5.07 5.19 5.65 5.8 5.01 5.1

 General farm overhead 11.91 12.17 10.69 10.93 15.85 16.22 11.07 11.45

 Total, allocated overhead 188.83 193.25 191.68 195.55 186.17 190.41 147.11 151.9

Total, costs listed 329.54 349.78 326.65 345.95 334.36 353.8 263.17 286.09

Value of production less total costs listed -16.72 -30.16 1.28 -14.89 -34.99 -51.48 -46.77 -60.37

Value of production less operating costs 172.11 163.09 192.96 180.66 151.18 138.93 100.34 91.53

 

Supporting information:

 Yield (bushels per planted acre) 134 149 142 157 127 138 95 108

 Price (dollars per bushel at harvest) 2.32 2.13 2.3 2.1 2.32 2.15 2.23 2.04

 Enterprise size (planted acres) a 236 236 270 270 138 138 281 281

Production practices: a

 Irrigated (percent) 14 14 5 5 4 4 28 28

 Dryland (percent) 86 86 95 95 96 96 72 72

 

United States Heartland Northern Crescent Northern Great Planes

Continued on next page. 
108 

Biomass Energy Data Book: Edition 1 

Table 5.6 (Continued) 

Corn Production Costs and Returns per Planted Acre, 

Excluding Government Payments, 2002—2003a

(dollars per planted acre)

 Item 2002 2003 2002 2003 2002 2003

Gross value of production

 Primary product: Corn grain 308.7 330.75 172.19 225.4 227.95 298.8

 Secondary product: Corn silage 0.89 0.9 15.78 30.54 2 2.23

 Total, gross value of production 309.59 331.65 187.97 255.94 229.95 301.03

Operating costs: 

 Seed 34.62 35.41 29.67 35.02 31.96 33.36

 Fertilizer 31.45 41.3 37.1 45.57 42.19 44.74

 Soil conditioners 0.02 0.02 0.75 0.71 0.47 0.49

 Manure 0.79 0.95 2.57 3.16 2.1 2.23

 Chemicals 28.76 28.04 23.48 24.74 24.91 24.86

 Custom operationsb 15.72 16.16 7.79 9.68 12.22 12.76

 Fuel, lube, and electricity 39.16 47.93 6.86 10.54 14.63 20.21

 Repairs 20.66 21.6 10.09 10.95 16.42 17.15

 Purchased irrigation water 0.59 0.63 0 0 0 0

 Interest on operating capital 1.45 1.01 1 0.74 1.22 0.82

 Total, operating costs 173.22 193.05 119.31 141.11 146.12 156.62

Allocated overhead: 

 Hired labor 5.35 5.48 3.92 4.22 6.51 6.73

 Opportunity cost of unpaid labor 31.2 32.74 47.54 48.46 33.94 35.15

 Capital recovery of machinery and equipment 70.09 73.28 44.05 47.79 54.06 56.36

 Opportunity cost of land (rental rate) 71.02 73.48 48.67 50.12 50.48 51.32

 Taxes and insurance 6.54 6.74 6.07 6.2 9.84 10.13

 General farm overhead 14.58 14.99 12.22 12.53 16.67 16.96

 Total, allocated overhead 198.78 206.71 162.47 169.32 171.5 176.65

Total, costs listed 372 399.76 281.78 310.43 317.62 333.27

Value of production less total costs listed -62.41 -68.11 -93.81 -54.49 -87.67 -32.24

Value of production less operating costs 136.37 138.6 68.66 114.83 83.83 144.41

 

Supporting information:

 Yield (bushels per planted acre) 126 147 67 98 97 120

 Price (dollars per bushel at harvest) 2.45 2.25 2.57 2.3 2.35 2.49

 Enterprise size (planted acres) a 346 346 72 72 78 78

Production practices: a

 Irrigated (percent) 61 61 1 1 21 21

 Dryland (percent) 39 39 99 99 79 79

Prairie Gateway Eastern Uplands Southern Seaboard

Source:

Economic Research Service. US Department of Agriculture, 

http://www.ers.usda.gov/data/costsandreturns/testpick.htm

_______________________ 

a

 Developed from survey base year, 2001. 

b

 Cost of custom operations, technical services, and commercial drying. 
 109

Biomass Energy Data Book: Edition 1 

This table shows the historical trends of ups and downs in corn grain prices and the consequent effect on 

profitability. 

Table 5.7 

Corn Production Costs and Returns per Planted Acre, 

Excluding Government Payments, 1996—2003a

(dollars per planted acre) 

 Item 1996 1997 1998 1999 2000 2001 2002 2003

Gross value of production

 Primary product: Corn grain 366.46 327.60 259.76 228.15 244.26 264.96 310.88 317.37

 Secondary product: Corn silage 3.47 3.77 3.12 2.55 2.41 1.96 1.94 2.25

 Total, gross value of production 369.93 331.37 262.88 230.70 246.67 266.92 312.82 319.62

Operating costs: 

 Seed 26.65 28.71 30.02 30.29 30.02 32.34 31.84 34.83

 Fertilizer 47.04 46.21 41.44 38.75 39.04 47.72 35.49 43.41

 Soil conditioners 0.16 0.16 0.16 0.17 0.16 0.12 0.12 0.13

 Manure 0.60 0.56 0.51 0.49 0.48 2.65 2.13 2.47

 Chemicals 27.42 26.87 27.36 28.40 28.82 26.44 26.11 26.20

 Custom operations 11.30 11.30 11.29 11.37 11.48 10.94 10.79 11.17

 Fuel, lube, and electricity 24.43 24.55 22.96 23.04 29.12 20.88 18.93 23.06

 Repairs 15.78 16.17 16.65 17.17 17.55 13.76 13.91 14.22

 Purchased irrigation water 0.30 0.32 0.31 0.31 0.31 0.22 0.22 0.22

 Interest on operating capital 3.86 3.96 3.61 3.50 4.53 2.60 1.17 0.82

 Total, operating costs 157.54 158.81 154.31 153.49 161.51 157.67 140.71 156.53

Allocated overhead: 

 Hired labor 2.83 3.07 3.19 3.28 3.36 2.92 3.06 3.14

 Opportunity cost of unpaid labor 28.99 29.89 30.63 31.43 32.21 24.96 25.74 26.53

 Capital recovery of machinery and equipment 63.02 64.50 66.46 68.49 70.16 54.69 55.26 56.67

 Opportunity cost of land (rental rate) 80.79 84.81 86.35 86.77 89.36 86.50 87.44 89.20

 Taxes and insurance 6.98 7.00 7.05 6.96 7.13 5.49 5.42 5.54

 General farm overhead 10.38 12.21 11.47 10.88 11.11 11.67 11.91 12.17

 Total, allocated overhead 192.99 201.48 205.15 207.81 213.33 186.23 188.83 193.25

 Total, costs listed 350.53 360.29 359.46 361.30 374.84 343.90 329.54 349.78

Value of production less total costs listed 19.40 -28.92 -96.58 -130.60 -128.17 -76.98 -16.72 -30.16

Value of production less operating costs 212.39 172.56 108.57 77.21 85.16 109.25 172.11 163.09

Supporting information:

 Yield (bushels per planted acre) 130 130 136 135 138 144 134 149

 Price (dollars per bushel at harvest) 2.82 2.52 1.91 1.69 1.77 1.84 2.32 2.13

 Enterprise size (planted acres) 189 189 189 189 189 236 236 236

Production practices:

 Irrigated (percent) 15 15 15 15 15 14 14 14

 Dryland (percent) 85 85 85 85 85 86 86 86

Source: 

Economic Research Service. U.S. Department of Agriculture, 

http://www.ers.usda.gov/data/costsandreturns/testpick.htm

_______________________ 

a 1996-2000 estimates developed from survey base year, 1996. 2001-03 estimates developed from 

survey base year, 2001. 
110 

Biomass Energy Data Book: Edition 1 

Sorghum is currently a small contributor to ethanol production, but because it is largely grown in an area 

of the country that does not significantly overlap with corn production, it could become important in 

expanding the range of locations of ethanol production facilities. 

Figure 5.6 

Sorghum for Grain, Harvested Acres, 2002

Source: 

U.S. Department of Agriculture, National Agricultural Statistics Service, 

www.nass.usda.gov/research/atlas02/atlas-crops.html
 111

Biomass Energy Data Book: Edition 1 

Sorghum is grown in areas that are generally too dry for unirrigated corn, thus potential resource areas 

for starch based ethanol can be expanded through use of sorghum. Grain weight per bushel is 56 lbs. at 

assumed harvest moisture content of 14%. 

Table 5.8 

Sorghum: Area, Yield, Production, and Value, 1996—2005

Area 

harvested

Yield per 

harvested 

acre Production

Marketing year 

average price per

cwtcd

Value of 

productioncd

Area 

Harvested

Yield per 

harvested 

acre Production

1,000 

Acres 1,000 Acres Bushels

1,000 

Bushels Dollars 1,000 Dollars

1,000 

Acres Tons 1,000 Tons

1996 13,097 11,811 67.3 795,274 4.17 1,986,316 423 11.8 4,976

1997 10,052 9,158 69.2 633,545 3.95 1,408,534 412 13.1 5,385

1998 9,626 7,723 67.3 519,933 2.97 904,123 308 11.4 3,526

1999 9,288 8,544 69.7 595,166 2.8 937,081 320 11.6 3,716

2000 9,195 7,726 60.9 470,526 3.37 845,755 278 10.5 2,932

2001 10,248 8,579 59.9 514,040 3.46 978,783 352 11 3,860

2002 9,589 7,125 50.6 360,713 4.14 855,140 408 9.6 3,913

2003 9,420 7,798 52.7 411,237 4.26 964,978 343 10.4 3,552

2004 7,486 6,517 69.6 453,654 3.19 843,464 352 13.6 4,776

2005d 6,454 5,736 68.7 393,893 3.04 715,327 311 13.6 4,218

Sorghum for grainb Sorghum for silage

Year

Area 

Planted 

for all 

purposesa

Source:

USDA, 2006 Agricultural Statistics, Table 1-59. 

_______________________ 

a Grain and sweet sorghum for all uses, including syrup. 

b

 Includes both grain sorghum for grain, and sweet sorghum for grain or seed. 

c

 Based on the reported price of grain sorghum; cwt = 100 pounds. 

d

 Preliminary. 
112 

Biomass Energy Data Book: Edition 1 

Sorghum is used for ethanol production only in the two states that planted over 3 million acres, Kansas 

and Texas. 

Table 5.9 

Sorghum: Area, Yield, and Production, by State, 2003—2005 

2003 2004 2005a 2003 2004 2005a 2003 2004 2005a

1,000 

Acres

1,000 

Acres

1,000 

Acres

1,000 

Acres

1,000 

Acres

1,000 

Acres Bushels Bushels Bushels

1,000 

Bushels

1,000 

Bushels

1,000 

Bushels

Alabama 10 10 10 6 6 6 45 43 53 270 258 318

Arizona 17 20 23 6 6 7 90 95 95 540 570 665

Arkansas 225 60 66 210 56 62 82 84 80 17,220 4,704 4,960

California 18 28 26 10 12 10 90 90 90 900 1,080 900

Colorado 270 280 160 160 180 110 27 30 31 4,320 5,400 3,410

Delawareb 2 2 ............ 1 1 ............ 70 83 ............ 70 83 ............. 

Georgia 55 45 40 38 25 27 47 47 50 1,786 1,175 1,350

Illinois 110 85 85 105 82 83 82 109 92 8,610 8,938 7,636

Kansas 3,550 3,200 2,750 2,900 2,900 2,600 45 76 75 130,500 220,400 195,000

Kentucky 33 15 25 32 13 24 95 80 90 3,040 1,040 2,160

Louisiana 170 85 90 165 80 88 85 65 99 14,025 5,200 8,712

Marylandb 6 5 ............ 3 4 ............ 65 84 ............ 195 336 ............. 

Mississippi 75 20 25 73 18 23 84 79 80 6,132 1,422 1,840

Missouri 215 150 135 210 145 130 77 108 76 16,170 15,660 9,880

Nebraska 660 550 340 500 415 250 62 78 87 31,000 32,370 21,750

New Mexico 140 140 120 62 92 97 27 46 45 1,674 4,232 4,365

North Carolina 18 17 16 14 14 13 50 52 50 700 728 650

Oklahoma 300 270 270 250 240 240 37 60 52 9,250 14,400 12,480

Pennsylvania 15 12 11 5 4 4 87 83 50 435 332 200

South Carolina 7 7 10 5 5 7 52 52 51 260 260 357

South Dakota 270 250 180 150 150 85 45 42 52 6,750 6,300 4,420

Tennessee 45 20 22 40 17 20 82 90 92 3,280 1,530 1,840

Texas 3,200 2,210 2,050 2,850 2,050 1,850 54 62 60 153,900 127,100 111,000

Virginiab 9 5 ............ 3 2 ............ 70 68 ............ 210 136 ............. 

US 9,420 7,486 6,454 7,798 6,517 5,736 52.7 69.6 68.7 411,237 453,654 393,893

State Yield per harvested acre Production

Area planted for all purposes Sorghum for grain

2003 2004 2005a

Area harvested

Source: 

USDA, 2006 Agricultural Statistics, Table 1-62, 

http://www.nass.usda.gov/Publications/Ag_Statistics/index.asp

_______________________ 

a

 Preliminary. 

b

 Estimates discontinued in 2005. 
 113

Biomass Energy Data Book: Edition 1 

Sorghum is grown primarily for animal feed. About 11% of sorghum grain was used in the production of 

ethanol in 2004. This would account for most of the grain shown in the food, seed and industrial category 

in 2004. 

Table 5.10 

Sorghum: Supply and Disappearance, 1996—2005 

(million bushels) 

Feed and 

residual

Food, 

seed, and

industrial Total Exports

Total 

disappearance

Privately 

owned a

Government Total

1996 18 795 814 516 45 561 205 766 47 0 47

1997 47 634 681 365 55 420 212 632 49 0 49

1998 49 520 569 262 45 307 197 504 65 0 65

1999 65 595 660 285 55 340 255 595 65 0 65

2000 65 471 536 222 35 258 237 494 41 1 42

2001 42 514 556 230 23 253 242 495 61 0 61

2002 61 361 422 170 24 194 184 379 43 0 43

2003 43 411 454 182 40 222 199 421 34 0 34

2004 b 34 454 487 191 55 246 184 430 57 0 57

2005 c 57 394 451 150 55 205 170 375 76 0 76

Supply Disappearance Ending stocks August 31

Beginning 

stocks Production Total

Domestic use

Year 

(beginning 

September 1)

Source:

USDA, 2006 Agricultural Statistics, Table 1-61, 

http://www.nass.usda.gov/Publications/Ag_Statistics/index.asp

Note: Totals may not add due to independent rounding. 

_______________________ 

a Includes quantity under loan and farmer–owned reserve. 

b

 Preliminary. 

c

 Projected as of January 12, 2006, World Agricultural and Supply Demand Estimates. 
114 

Biomass Energy Data Book: Edition 1 

The lower yields of sorghum grain results in lower profit in sorghum production compared to corn. 

Sorghum biomass production can be quite high, making it a potential source of crop residue in some 

areas of the country. 

Table 5.11 

Sorghum Production Costs and Returns per Planted Acre, 

Excluding Government Payments, 2002—2003a

(dollars per planted acre)

 Item 2002 2003 2002 2003 2002 2003 2002 2003 2002 2003

Gross value of production:

 Sorghum 95.37 101.25 126.72 135.6 153.78 124.32 176.79 176.28 86.49 96.75

 Total, gross value of production 95.37 101.25 126.72 135.6 153.78 124.32 176.79 176.28 86.49 96.75

Operating costs:

 Seed 6.63 6.48 7.59 7.77 9.18 9.4 10.99 11.25 6.03 6.17

 Fertilizerb 15.1 18.17 24.08 29.03 25.32 30.53 24.21 29.19 13.87 16.72

 Chemicals 11.22 11.56 11.01 11.2 18.43 18.74 18.65 18.96 10.85 11.03

 Custom operations 4.38 3.89 7.15 7.33 5.64 5.78 9.14 9.37 3.43 3.52

 Fuel, lube, and electricity 24.92 32.74 38.03 47.54 30.88 38.6 13.01 16.26 25.52 31.9

 Repairs 17.48 17.94 20.59 21.06 15.68 16.04 20.09 20.55 17.45 17.85

 Interest on operating inputs 0.67 0.48 0.91 0.66 0.88 0.63 0.81 0.56 0.65 0.46

 Total, operating costs 80.4 91.26 109.36 124.59 106.01 119.72 96.9 106.14 77.8 87.65

Allocated overhead:

 Hired labor 7.45 7.16 3.21 3.29 2.68 2.75 13.17 13.51 7.33 7.52

 Opportunity cost of unpaid labor 22.98 23.73 28.98 29.74 21.77 22.34 15.06 15.45 23.04 23.64

 Capital recovery of machinery and equipment 60.91 62.55 71.47 72.44 54.52 55.26 65.29 66.17 61.59 62.42

 Opportunity cost of land 21.49 23.1 36.53 38.94 65.15 53.16 40.71 40.37 18.02 20.25

 Taxes and insurance 5.04 5.35 7.33 7.45 7.5 7.62 7.35 7.47 5 5.08

 General farm overhead 4.39 4.59 11.05 11.3 3.23 3.3 4.18 4.28 4.23 4.33

 Total, allocated overhead 122.26 126.48 158.57 163.16 154.85 144.43 145.76 147.25 119.21 123.24

Total costs listed 202.66 217.74 267.93 287.75 260.86 264.15 242.66 253.39 197.01 210.89

Value of production less total costs listed -107.29 -116.49 -141.21 -152.15 -107.08 -139.83 -65.87 -77.11 -110.52 -114.14

Value of production less operating costs 14.97 9.99 17.36 11.01 47.77 4.6 79.89 70.14 8.69 9.1

Supporting information:

 Sorghum Yield: bushels per planted acre 33 45 48 60 66 56 71 78 31 43

 Price: dollars per bushel 2.89 2.25 2.64 2.26 2.33 2.22 2.49 2.26 2.79 2.25

Production practices:a

 Irrigated (percent) 9 9 1 1 2 2 5 5 10 10

 Dryland (percent) 91 91 99 99 98 98 95 95 90 90

Land tenure:a

 Acres owned (percent) 31 31 30 30 41 41 15 15 32 32

 Acres cash rented (percent) 16 16 27 27 11 11 22 22 16 16

 Acres share rented (percent) 53 53 43 43 48 48 62 62 53 53

Land rent basisc Composite Composite Cash Cash Cash Cash Share Share Share Share

United States Heartland Prairie Gateway Eastern Uplands Mississippi Portal

Source: 

Economic Research Service, U.S. Department of Agriculture, 

http://www.ers.usda.gov/data/costsandreturns/testpick.htm

_______________________ 

a

 Developed from survey base year, 1995. 

b

 Commercial fertilizer and soil conditioners. 

c

 Method used to determine the opportunity cost of land. 
 115

Biomass Energy Data Book: Edition 1 

Sorghum costs and returns are quite variable, like corn. Sorghum is produced on lower cost, higher risk 

land, resulting in considerable yield variability. 

Table 5.12 

Sorghum Production Costs and Returns per Planted Acre, 

Excluding Government Payments, 1995—2003a

(dollars per planted acre) 

Item 1995 1996 1997 1998 1999 2000 2001 2002 2003

Gross value of production:

 Sorghum 143 170.1 153.43 96.66 96.66 88.62 93.86 95.37 101.25

 Total, gross value of production 143 170.1 153.43 96.66 96.66 88.62 93.86 95.37 101.25

Operating costs:

 Seed 5.42 6 6.57 6.72 6.72 6.33 6.35 6.63 6.48

 Fertilizerb 19.19 17.99 17.62 13.89 13.89 14.34 21.53 15.1 18.17

 Chemicals 12.63 12.29 11.69 11.2 11.2 11.15 11.31 11.22 11.56

 Custom operations 5.07 6.23 6.91 6.78 6.78 5.48 5.27 4.38 3.89

 Fuel, lube, and electricity 14.13 17.1 17.37 21.92 21.92 26.09 29.99 24.92 32.74

 Repairs 12.89 13.81 14.25 14.7 14.7 15.29 16.28 17.48 17.94

 Interest on operating inputs 1.91 1.85 1.9 1.77 1.77 2.27 1.53 0.67 0.48

 Total, operating costs 71.24 75.27 76.31 76.98 76.98 80.95 92.26 80.4 91.26

Allocated overhead:

 Hired labor 4.98 5.41 5.68 6.36 6.36 6.57 7.06 7.45 7.16

 Opportunity cost of unpaid labor 17.58 18.58 19.16 20.38 20.38 20.8 21.32 22.98 23.73

 Capital recovery of machinery and equipment 51.49 53.49 55.38 55.79 55.79 56.7 58.23 60.91 62.55

 Opportunity cost of land 33.02 39.2 36.18 23.53 23.53 21.02 20.63 21.49 23.1

 Taxes and insurance 5.06 4.98 5.02 4.9 4.9 5.07 5.1 5.04 5.35

 General farm overhead 3.68 3.76 3.84 3.97 3.97 4.08 4.23 4.39 4.59

 Total, allocated overhead 115.81 125.42 125.26 114.93 114.93 114.24 116.57 122.26 126.48

Total costs listed 187.05 200.69 201.57 191.91 191.91 195.19 208.83 202.66 217.74

Value of production less total costs listed -44.05 -30.59 -48.14 -95.25 -95.25 -106.57 -114.97 -107.29 -116.49

Value of production less operating costs 71.76 94.83 77.12 19.68 19.68 7.67 1.6 14.97 9.99

Supporting information:

 Sorghum Yield: bushels per planted acre 52 63 67 54 54 42 38 33 45

 Price: dollars per bushel 2.75 2.7 2.29 1.79 1.79 2.11 2.47 2.89 2.25

Production practices:a

 Irrigated (percent) 9 9 9 9 9 9 9 9 9

 Dryland (percent) 91 91 91 91 91 91 91 91 91

Land tenure:a 

 Acres owned (percent) 31 31 31 31 31 31 31 31 31

 Acres cash rented (percent) 16 16 16 16 16 16 16 16 16

 Acres share rented (percent) 53 53 53 53 53 53 53 53 53

Land rent basisc Composite Composite Composite Composite Composite Composite Composite Composite Composite

Source: 

Economic Research Service, U.S. Department of Agriculture, 

http://www.ers.usda.gov/data/costsandreturns/testpick.htm

_______________________ 

a

 Developed from survey base year, 1995. 

b

 Commercial fertilizer and soil conditioners. 

c

 Method used to determine the opportunity cost of land. 
116 

Biomass Energy Data Book: Edition 1 

USDA’s 2005 soybean baseline projections do not specifically show oil produced for use as a biofuel and 

do not reflect in the projections the probable increase in demand for soybean oil as a biofuel which is 

anticipated due to the Energy Policy Act of 2005. It is likely that future USDA soybean baseline 

projections will reflect the market changes. 

Table 5.13 

Soybeans and Products Baseline, 2004—2015 

Item 2003/04 2004/05 2005/06 2006/07 2007/08 2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15

Area (million acres):

 Planted 73.4 75.1 74.0 73.8 73.3 73.0 72.8 73.0 73.0 72.8 72.8 72.8

 Harvested 72.5 74.0 72.7 72.4 71.9 71.7 71.4 71.7 71.7 71.4 71.4 71.4

Yield/harvested acre (bushels 33.9 42.6 40.0 40.4 40.8 41.2 41.6 42.0 42.4 42.8 43.2 43.6

Supply (million bushels)

 Beginning stocks, Sept 1 178 112 460 400 330 255 230 210 209 210 207 209

 Production 2,454 3,150 2,910 2,925 2,935 2,955 2,970 3,010 3,040 3,055 3,085 3,115

 Imports 6 6 3 4 4 5 4 4 3 4 5 4

 Total supply 2,638 3,269 3,373 3,329 3,269 3,215 3,204 3,224 3,252 3,269 3,297 3,328

Disposition (million bushels)

 Crush 1,530 1,645 1,725 1,745 1,765 1,780 1,810 1,830 1,855 1,880 1,905 1,930

 Seed and residual 111 153 148 149 149 150 154 155 157 157 158 159

 Exports 885 1,010 1,100 1,105 1,100 1,055 1,030 1,030 1,030 1,025 1,025 1,030

 Total disposition 2,525 2,808 2,973 2,999 3,014 2,985 2,994 3,015 3,042 3,062 3,088 3,119

Carryover stocks, August 31

 Total ending stocks 112 460 400 330 255 230 210 209 210 207 209 209

 Stocks/use ratio, percent 4.4 16.4 13.5 11.0 8.5 7.7 7.0 6.9 6.9 6.8 6.8 6.7

Prices (dollars per bushel)

 Loan rate 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00 5.00

 Soybean price, farm 7.34 4.95 4.50 4.60 4.85 5.25 5.50 5.55 5.60 5.65 5.65 5.70

Variable costs of production (dollars):

 Per acre 79.15 81.26 82.30 83.54 84.22 84.91 85.59 86.29 87.02 87.77 88.55 89.36

 Per bushel 2.33 1.91 2.06 2.07 2.06 2.06 2.06 2.05 2.05 2.05 2.05 2.05

Returns over variable costs (dollars per acre):

 Net returns a 169.68 140.26 125.70 126.54 127.94 131.39 143.21 146.81 150.42 154.05 155.53 159.16

Soybean oil (million pounds)

 Beginning stocks, Oct. 1 1,491 1,057 1,187 1,487 1,682 1,877 1,962 2,107 2,127 2,077 1,937 1,752

 Production 17,077 18,425 19,390 19,630 19,875 20,060 20,415 20,660 20,960 21,265 21,565 21,865

 Imports 307 105 110 115 120 125 130 135 140 145 150 155

 Total supply 18,875 19,587 20,687 21,232 21,677 22,062 22,507 22,902 23,227 23,487 23,652 23,772

 Domestic disappearance 16,881 17,300 17,650 18,000 18,350 18,675 19,025 19,375 19,725 20,100 20,475 20,850

 Exports 937 1,100 1,550 1,550 1,450 1,425 1,375 1,400 1,425 1,450 1,425 1,350

 Total demand 17,818 18,400 19,200 19,550 19,800 20,100 20,400 20,775 21,150 21,550 21,900 22,200

 Ending stocks, Sept. 30 1,057 1,187 1,487 1,682 1,877 1,962 2,107 2,127 2,077 1,937 1,752 1,572

 Soybean oil price ($/lb) 0.2997 0.230 0.205 0.198 0.200 0.205 0.208 0.213 0.218 0.223 0.230 0.235

Soybean meal (thousand short tons)

 Beginning stocks, Oct. 1 220 212 250 250 250 250 250 250 250 250 250 250

 Production 36,318 39,173 41,035 41,485 41,985 42,385 43,035 43,585 44,135 44,710 45,285 45,985

 Imports 270 165 165 165 165 165 165 165 165 165 165 165

 Total supply 36,808 39,550 41,450 41,900 42,400 42,800 43,450 44,000 44,550 45,125 45,700 46,400

 Domestic disappearance 32,256 33,900 34,500 35,150 35,650 36,150 36,700 37,250 37,800 38,375 38,950 39,550

 Exports 4,340 5,400 6,700 6,500 6,500 6,400 6,500 6,500 6,500 6,500 6,500 6,600

 Total demand 36,596 39,300 41,200 41,650 42,150 42,550 43,200 43,750 44,300 44,875 45,450 46,150

 Ending stocks, Sept. 30 212 250 250 250 250 250 250 250 250 250 250 250

 Soybean meal price ($/ton) 256.05 160.00 150.00 155.00 163.00 176.50 185.00 183.50 182.50 181.50 177.00 176.00

 Crushing yields (pounds per bushel)

 Soybean oil 11.16 11.20 11.24 11.25 11.26 11.27 11.28 11.29 11.30 11.31 11.32 11.33

 Soybean meal 47.48 47.62 47.60 47.60 47.60 47.60 47.60 47.60 47.60 47.60 47.60 47.60

 Crush margin ($ per bushel) 2.08 1.44 1.37 1.31 1.28 1.26 1.24 1.22 1.20 1.19 1.17 1.15

Source: 

USDA Agricultural Baseline Projections to 2014, February 2005 (OCE-2005-1), Table 13 - U.S. soybean 

and products, http://usda.mannlib.cornell.edu/data-sets/baseline/2005/index.html

_______________________ 

a

 Net returns include estimates of marketing loan benefits. 
 117

Biomass Energy Data Book: Edition 1 

In 2001, only 5 million gallons of biodiesel fuel was produced requiring a very small amount of all 

soybeans harvested. By 2005, about 75 million gallons of biodiesel fuel was produced with about 90% 

being derived from soybeans. At a conversion rate of 1.5 gallons of biodiesel per bushel of soybeans 

(Source: National Biodiesel Board), the total bushels of soybeans used in biodiesel production was 

approximately 45 million bushels or about 1.5% of all soybeans produced. 

Table 5.14 

Soybeans: Area, Yield, Production, and Value, 1996—2005 

Area 

harvested

Yield per 

acre Production

Marketing year 

average price per 

bushel raised by 

farmers

Value of 

production

1,000 Acres 1,000 Acres Bushels 1,000 Bushels Dollars 1,000 Dollars

1996 64,195 63,349 37.6 2,380,274 7.35 17,439,971

1997 70,005 69,110 38.9 2,688,750 6.47 17,372,628

1998 72,025 70,441 38.9 2,741,014 4.93 13,493,891

1999 73,730 72,446 36.6 2,653,758 4.63 12,205,352

2000 74,266 72,408 38.1 2,757,810 4.54 12,466,572

2001 74,075 72,975 39.6 2,890,682 4.38 12,605,717

2002 73,963 72,497 38.0 2,756,147 5.53 15,252,691

2003 73,404 72,476 33.9 2,453,665 7.34 18,013,753

2004 75,208 73,958 42.2 3,123,686 5.74 17,894,948

2005 72,142 71,361 43.3 3,086,432 5.50 16,927,898

Year Area Planted

Soybeans for beans

Source: 

USDA, 2006 Agricultural Statistics, Table 3-26, 

http://www.nass.usda.gov/Publications/Ag_Statistics/index.asp
118 

Biomass Energy Data Book: Edition 1 

Table 5.15 

Soybeans: Supply and Disappearance, 1995—2004 

(thousand bushels) 

Farm Total 

1995 105,130 229,684 334,814 2,174,254 2,513,524

1996 59,523 123,935 183,458 2,380,274 2,572,636

1997 43,600 88,233 131,833 2,688,750 2,825,589

1998 84,300 115,499 199,799 2,741,014 2,944,334

1999 145,000 203,482 348,482 2,653,758 3,006,411

2000 112,500 177,662 290,162 2,757,810 3,051,540

2001 83,500 164,247 247,747 2,890,682 3,140,749

2002 62,700 145,361 208,061 2,756,147 2,968,869

2003 58,000 120,329 178,329 2,453,665 2,637,556

2004 29,400 83,014 112,414 3,123,686 3,241,676

Seed, feed 

and residual Exports Total

1995 1,369,541 111,441 849,084 2,330,066

1996 1,436,961 118,954 885,888 2,440,803

1997 1,596,983 154,476 874,334 2,625,793

1998 1,589,787 201,414 804,651 2,595,852

1999 1,577,650 165,194 973,405 2,716,249

2000 1,639,670 168,252 995,871 2,803,793

2001 1,699,741 169,296 1,063,651 2,932,688

2002 1,615,464 131,380 1,044,372 2,790,540

2003 1,529,699 108,892 886,551 2,525,142

2004b 1,696,088 187,386 1,102,695 2,986,169

Year beginning 

September

Table continued

Terminal market, 

interior mill, 

elevator, and 

warehouse

Crushedc

Disappearance

Stocks by Position

Production Totala

Year 

beginning 

September

Supply

Source:

USDA, 2006 Agricultural Statistics, Table 3-29, 

http://www.nass.usda.gov/Publications/Ag_Statistics/index.asp

_______________________ 

a

 Includes imports, beginning with 1988. 

b

 Preliminary. 

c

 Reported by the U.S. Department of Commerce. 
 119

Biomass Energy Data Book: Edition 1 

Soybean production is highly variable by state, with the mid-west producing the largest amount. States 

with the highest production levels are Illinois and Iowa. 

Table 5.16 

Soybeans: Area, Yield, and Production, by State, 2003—2005 

2003 2004 2005 2003 2004 2005 2003 2004 2005

1,000 

Acres

1,000 

Acres

1,000 

Acres

1,000 

Acres

1,000 

Acres

1,000 

Acres Bushels Bushels Bushels

1,000 

Bushels

1,000 

Bushels

1,000 

Bushels

Alabama 170 210 150 160 190 145 36 35 33 5,760 6,650 4,785

Arizona 2,920 3,200 3,030 2,890 3,150 3,000 38.5 39 34 111,265 122,850 102,000

Delaware 180 210 185 178 208 182 36 42 26 6,408 8,736 4,732

Florida 13 19 9 12 17 8 30 34 32 360 578 256

Georgia 190 280 180 180 270 175 33 31 26 5,940 8,370 4,550

Illinois 10,300 9,950 9,500 10,260 9,900 9,450 37 50 47 379,620 495,000 444,150

Indiana 5,450 5,550 5,400 5,370 5,520 5,380 38 51.5 49 204,060 284,280 263,620

Iowa 10,600 10,200 10,100 10,550 10,150 10,050 32.5 49 53 342,875 497,350 532,650

Kansas 2,600 2,800 2,900 2,480 2,710 2,850 23 41 37 57,040 111,110 105,450

Kentucky 1,250 1,310 1,260 1,240 1,300 1,250 43.5 44 43 53,940 57,200 53,750

Louisiana 760 1,100 880 740 990 850 34 33 34 25,160 32,670 28,900

Maryland 435 500 480 430 495 470 37 43 34 15,910 21,285 15,980

Michigan 2,000 2,000 2,000 1,990 1,980 1,990 27.5 38 39 54,725 75,240 77,610

Minnesota 7,500 7,300 6,900 7,450 7,050 6,800 32 33 45 238,400 232,650 306,000

Mississippi 1,440 1,670 1,610 1,430 1,640 1,590 39 37.5 37 55,770 61,500 58,830

Missouri 5,000 5,000 5,000 4,950 4,960 4,960 29.5 45 37 146,025 223,200 183,520

Nebraska 4,550 4,800 4,700 4,500 4,750 4,660 40.5 46 50.5 182,250 218,500 235,330

New Jersey 90 105 95 88 103 91 34 42 28 2,992 4,326 2,548

New York 140 175 190 138 172 188 35 39 42 4,830 6,708 7,896

North Carolina 1,450 1,530 1,490 1,400 1,500 1,460 30 34 27 42,000 51,000 39,420

North Dakota 3,150 3,750 2,950 3,050 3,570 2,900 29 23 37 88,450 82,110 107,300

Ohio 4,300 4,450 4,500 4,280 4,420 4,480 38.5 47 45 164,780 207,740 201,600

Oklahoma 270 320 325 245 290 305 26 30 26 6,370 8,700 7,930

Pennsylvania 380 430 430 375 425 420 41 46 41 15,375 19,550 17,220

South Carolina 430 540 430 420 530 420 28 27 20.5 11,760 14,310 8,610

South Dakota 4,250 4,150 3,900 4,200 4,120 3,850 27.5 34 36 115,500 140,080 138,600

Tennessee 1,150 1,210 1,130 1,120 1,180 1,100 42 41 38 47,040 48,380 41,800

Texas 200 290 260 185 270 230 29 32 26 5,365 8,640 5,980

Virginia 500 540 530 480 530 510 34 39 30 16,320 20,670 15,300

West Virginia 16 19 18 15 18 17 41 46 35 615 828 595

Wisconsin 1,720 1,600 1,610 1,670 1,550 1,580 28 34.5 44 46,760 53,475 69,520

US 73,404 75,208 72,142 72,476 73,958 71,361 33.9 42.2 43.3 2,453,665 3,123,686 3,086,432

State

Area planted Soybeans for beans

2003 2004 2005

Area harvested Yield per harvested acre Production

Source: 

USDA, 2006 Agricultural Statistics, Table 3-31, 

http://www.nass.usda.gov/Publications/Ag_Statistics/index.asp
120 

Biomass Energy Data Book: Edition 1 

Soybean production area is similar to corn production area, with the addition of more area in North and 

South Dakota and along the Mississippi Delta. 

Figure 5.7 

Soybeans for Beans, Harvested Acres, 2002 

Source: 

U.S. Department of Agriculture, National Agricultural Statistics Service, 

http://www.nass.usda.gov/research/atlas02/atlas-crops.html
 121

Biomass Energy Data Book: Edition 1 

As with all agricultural crops, soybean costs and returns per acre vary by region. In general, soybean 

returns are a little less than returns for corn when only operating costs are considered. 

Table 5.17 

Soybean Production Costs and Returns per Planted Acre, 

Excluding Government Payments, 2002—2003a

(dollars per planted acre) 

 Item 2002 2003 2002 2003 2002 2003 2002 2003

Gross value of production

 Primary product: Soybeans 210.64 233.61 225.59 237.02 213.96 194.46 175.39 184.84

 Total, gross value of production 210.64 233.61 225.59 237.02 213.96 194.46 175.39 184.84

Operating costs:

 Seed 25.45 27.42 25.72 27.78 25.65 27.46 22.39 26.76

 Fertilizer 6.79 7.39 6.47 6.87 10.39 11.00 5.73 7.46

 Soil conditioners 0.11 0.12 0.09 0.09 0.23 0.25 0.00 0.00

 Manure 0.40 0.46 0.41 0.48 1.48 1.75 0.03 0.03

 Chemicals 17.12 16.92 17.29 17.40 17.29 16.96 14.47 13.83

 Custom operations 6.16 6.32 5.35 5.48 8.99 9.37 5.72 5.65

 Fuel, lube, and electricity 6.98 8.73 5.72 7.16 8.27 10.30 6.46 7.84

 Repairs 9.76 9.77 8.62 8.73 11.28 11.14 9.29 9.70

 Purchased irrigation water 0.12 0.12 0.00 0.00 0.00 0.00 0.00 0.00

 Interest on operating capital 0.61 0.41 0.59 1.39 0.70 0.47 0.54 0.38

 Total, operating costs 73.50 77.66 70.26 75.38 84.28 88.70 64.63 71.65

Allocated overhead:

 Hired labor 1.84 1.90 1.19 1.24 3.14 3.26 1.72 1.84

 Opportunity cost of unpaid labor 15.59 16.11 14.57 15.09 21.02 21.76 10.95 11.45

 Capital recovery of machinery and equipment 43.30 43.43 40.22 40.68 49.03 48.44 40.59 42.52

 Opportunity cost of land(rental rate) 80.74 81.93 94.12 95.93 69.13 69.41 44.87 46.17

 Taxes and insurance 5.66 5.80 5.75 5.89 7.18 7.43 4.75 4.91

 General farm overhead 11.37 11.66 11.81 12.10 13.61 14.10 9.36 9.65

 Total, allocated overhead 158.50 160.83 167.66 170.93 163.11 164.40 112.24 116.54

 Total costs listed 232.00 238.49 237.92 246.31 247.39 253.10 176.87 188.19

Value of production less total costs listed -21.36 -4.88 -12.33 -9.29 -33.43 -58.64 -1.48 -3.35

Value of production less operating costs 137.14 155.95 155.33 161.64 129.68 105.76 110.76 113.19

Supporting information:

 Yield (bushels per planted acre) 40 36 43 36 41 30 35 30

 Price (dollars per bushel at harvest) 5.20 6.56 5.19 6.57 5.18 6.50 5.02 6.17

 Enterprise size (planted acres)a 268 268 280 280 135 135 460 460

Production practices:a

 Irrigated (percent) 9 9 5 5 3 3 3 3

 Dryland (percent) 91 91 95 95 97 97 97 97

United States Heartland

Northern 

Crescent

Northern Great 

Plains

Continued on the next page.
122 

Biomass Energy Data Book: Edition 1 

Table 5.17 (Continued) 

Soybean Production Costs and Returns per Planted Acre, 

Excluding Government Payments, 2002—2003a

(dollars per planted acre) 

 Item 2002 2003 2002 2003 2002 2003 2002 2003

Gross value of production

 Primary product: Soybeans 169.54 226.37 157.71 242.83 124.46 223.83 201.29 303.21

 Total, gross value of production 169.54 226.37 157.71 242.83 124.46 223.83 201.29 303.21

Operating costs:

 Seed 26.94 25.92 22.76 25.03 26.18 21.72 24.99 29.25

 Fertilizer 3.89 4.82 12.24 13.49 11.00 11.43 7.06 7.59

 Soil conditioners 0.03 0.03 0.36 0.35 0.91 0.97 0.06 0.07

 Manure 0.20 0.24 0.16 0.18 0.18 0.17 0.00 0.00

 Chemicals 15.25 14.53 16.52 15.79 17.97 18.20 19.67 18.06

 Custom operations 7.20 7.43 6.16 6.31 10.85 11.15 7.87 8.11

 Fuel, lube, and electricity 17.21 21.09 5.24 7.13 4.48 6.21 8.99 11.77

 Repairs 12.94 13.12 7.85 7.86 7.47 7.39 16.59 15.50

 Purchased irrigation water 1.71 1.80 0.00 0.00 0.00 0.00 0.00 0.00

 Interest on operating capital 0.72 0.47 0.62 0.44 0.68 0.41 0.72 0.48

 Total, operating costs 86.09 89.45 71.91 76.58 79.72 77.65 85.95 90.83

Allocated overhead:

 Hired labor 0.88 0.88 1.92 1.95 2.94 2.99 6.47 6.51

 Opportunity cost of unpaid labor 22.63 23.56 16.41 16.93 19.13 20.02 15.93 16.24

 Capital recovery of machinery and equipment 50.13 50.81 38.40 38.54 37.17 36.96 63.40 59.49

 Opportunity cost of land(rental rate) 63.03 63.97 53.62 55.11 34.28 34.44 56.85 58.85

 Taxes and insurance 4.32 4.44 3.77 3.85 4.50 4.56 6.48 6.64

 General farm overhead 8.94 9.19 7.42 7.54 8.36 8.55 11.93 12.21

 Total, allocated overhead 149.93 152.85 121.54 123.92 106.38 107.52 161.06 159.94

 Total costs listed 236.02 242.30 193.45 200.50 186.10 185.17 247.01 250.77

Value of production less total costs listed -66.48 -15.93 -35.74 42.33 -61.64 38.66 -45.72 52.44

Value of production less operating costs 83.45 136.92 85.80 166.25 44.74 146.18 115.34 212.38

Supporting information:

 Yield (bushels per planted acre) 33 34 29 37 23 32 37 45

 Price (dollars per bushel at harvest) 5.18 6.59 5.47 6.82 5.41 7.00 5.41 6.68

 Enterprise size (planted acres)a 246 246 171 171 180 180 538 538

Production practices:a

 Irrigated (percent) 32 32 8 8 0 0 43 43

 Dryland (percent) 68 68 92 92 100 100 57 57

Eastern 

Uplands

Southern 

Prairie Gateway Seaboard

Mississippi 

Portal

Source: 

Economic Research Service, U.S. Department of Agriculture, 

http://www.ers.usda.gov/data/costsandreturns/testpick.htm

_______________________ 

a

 Developed from survey base year, 2002. 
 123

Biomass Energy Data Book: Edition 1 

Secondary Biomass Feedstocks

Residues and byproduct streams from food, feed, fiber, wood, and materials processing plants are the 

main source of secondary biomass. Secondary biomass feedstocks differ from primary biomass 

feedstocks in that the secondary feedstocks are a by-product of processing of the primary feedstocks. By 

“processing” it is meant that there is substantial physical or chemical breakdown of the primary biomass 

and production of by-products. “Processors” may be factories or animals. Field processes such as 

harvesting, bundling, chipping or pressing do not cause a biomass resource that was produced by 

photosynthesis (e.g., tree tops and limbs) to be classified as secondary biomass.

Specific examples of secondary biomass includes sawdust from sawmills, black liquor (which is a byproduct of paper making), and cheese whey (which is a by-product of cheese making processes). 

Manures from concentrated animal feeding operations are collectable secondary biomass resources. 

Vegetable oils used for biodiesel that are derived directly from the processing of oilseeds for various uses 

are also a secondary biomass resource. 

It is difficult to find good direct sources of information on secondary biomass resources. In most cases, 

one has to estimate availability based on information and assumptions about the industries or companies 

generating the biomass. These estimates can be inaccurate because the amount of material that is a byproduct to a given process can change over time as processes become more efficient or new uses are 

found for some by-product components. 

The estimates provided in this databook were generated either by industries using secondary biomass to 

make a marketable fuel (e.g., the pellet fuel industry), or were generated by Forest Service staff using the 

Timber Product Output database http://www.fia.fs.fed.us/tools-data/tools/. This database is based on 

wood harvest and use inventories conducted every 5 years; the 2002 inventory is the latest source of 

information. The wood already used for energy provides insight on current bioenergy produced and the 

“unused” biomass represents wood that is already collected and potentially very easy to make available 

for additional energy production. Though a relatively small amount, it would likely be some of the first 

wood used if bioenergy use is accelerated in the U.S. 

Information on black liquor production and use for energy is kept and tracked by the forest products 

industry but is proprietary. An estimate of black liquor production could be made based on publicly 

available information on pulp mills. However, any current listing of pulp mills in operation will be out-ofdate within a month or two of publication because of the frequent closing of mills that is occurring. Thus, 

though a very important resource for bioenergy production today, no attempt is made to include a state 

level estimate of black liquor production in this book.

Source: Lynn Wright, Oak Ridge, TN 
124 

Biomass Energy Data Book: Edition 1 

About 42% of the residues produced at primary mills are used to produce energy, typically supplying the 

power needed to operate the mills. 

Table 5.18 

Residues from Primary Forest Product Mills 

(Dry tons) 

State Fiber Energy Miscellaneous Unused Total

Alabama 2,767,320 4,362,130 594,770 13,640 7,737,860 

Arizona 58,050 46,830 3,560 150 108,590 

Arkansas 2,040,540 2,436,230 291,320 2,790 4,770,880 

California 2,146,810 2,285,780 382,280 8,430 4,823,300 

Colorado 33,140 35,310 26,260 86,760 181,470 

Connecticut 2,710 39,710 47,740 - 90,160 

Delaware 910 4,030 11,430 60 16,430 

Florida 868,670 1,276,600 386,860 5,200 2,537,330 

Georgia - - - - - 

Idaho 2,602,590 1,557,240 171,180 69,250 4,400,260 

Illinois 61,060 97,910 104,920 18,520 282,410 

Indiana 198,970 180,300 288,200 28,170 695,640 

Iowa 28,190 44,120 82,040 2,660 157,010 

Kansas 4,190 3,710 20,430 6,400 34,730 

Kentucky 642,230 531,580 635,520 102,800 1,912,130 

Louisiana 1,729,960 2,831,950 193,340 18,270 4,773,520 

Maine 190,320 166,700 106,190 42,450 505,660 

Maryland 44,070 13,160 108,140 230 165,600 

Massachusetts 24,910 43,970 66,410 - 135,290 

Michigan 243,540 841,890 350,450 49,610 1,485,490 

Minnesota 100,950 805,670 82,900 75,090 1,064,610 

Mississippi 2,156,610 3,032,540 713,450 103,910 6,006,510 

Missouri 171,970 163,100 766,990 160,040 1,262,100 

Montana 1,475,950 346,090 74,440 40,580 1,937,060 

Nebraska - 8,940 48,760 11,470 69,170 

Nevada - - - - - 

New Hampshire 274,340 415,780 396,520 23,220 1,109,860 

New Jersey - 7,480 12,720 290 20,490 

New Mexico 82,990 37,470 40,530 3,640 164,630 

New York 217,340 467,230 562,330 28,250 1,275,150 

North Carolina 2,367,310 1,983,530 835,480 18,360 5,204,680 

North Dakota - 190 120 210 520 

Ohio 269,050 308,500 343,960 21,430 942,940 

Oklahoma 244,360 403,770 187,950 - 836,080 

Oregon 4,359,910 1,728,430 736,580 9,910 6,834,830 

Pennsylvania 351,080 419,530 686,490 172,790 1,629,890 

Rhode Island 920 11,530 13,210 - 25,660 

South Carolina 1,346,210 1,600,440 334,470 12,090 3,293,210 

South Dakota 106,540 33,700 24,860 5,320 170,420 

Tennessee 633,850 846,360 331,510 197,580 2,009,300 

Texas 1,512,300 995,850 249,160 10,570 2,767,880 

Utah - 47,140 35,510 19,790 102,440 

Vermont 64,940 59,090 - - 124,030 

Virginia 1,232,540 1,053,260 491,900 87,470 2,865,170 

Washington 2,944,230 2,257,790 482,840 4,950 5,689,810 

West Virginia 312,410 322,810 196,420 136,340 967,980 

Wisconsin 412,680 1,071,000 309,810 32,920 1,826,410 

Wyoming 72,620 77,380 57,560 47,380 254,940 

Total 34,399,280 35,303,750 11,887,510 1,678,990 83,269,530 

Source: 

Bioenergy Resource and Engineering Systems Program, Oak Ridge National Laboratory. 

Note: - No data. 

For information on estimation methods used, see: Appendix C - Estimation Methods for Logging 

Residues, Fuel Treatment Thinnings and Primary Forest Product Mill Residues. 
 125

Biomass Energy Data Book: Edition 1 

Although the mill residues shown in the map below are currently unused, they represent a source of 

biomass that could be utilized fairly easily compared with other sources of biomass. 

Figure 5.8 

Unused Mill Residues by County

Source: 

Bioenergy Resource and Engineering Systems Program, Oak Ridge National Laboratory. 

Note: For information on estimation methods used, see: Appendix C - Estimation Methods for Logging 

Residues, Fuel Treatment Thinnings and Primary Forest Product Mill Residues. 
126 

Biomass Energy Data Book: Edition 1 

Table 5.19 

Pellet Fuel Shipments from Pellet Fuel Manufacturers (tons) 

Region 1994-1995 1995-1996 1996-1997 1997-1998 1998-1999 1999-2000 2000-2001 2001-2002 2002-2003* 2003-2004* 2004-2005*

Pacific 293,000 262,000 228,000 236,000 231,000 235,500 204,000 229,000 269,000 241,000 183,323

Mountain 120,000 123,000 108,000 108,000 120,000 89,000 121,000 130,000 105,000 131,000 101,509

Central 15,000 19,000 36,000 49,000 31,000 17,500 43,000 39,000 49,000 76,000 49,176

Great Lakes 24,000 36,000 45,000 22,000 27,000 19,100 26,000 44,000 41,000 53,000 56,656

Northeast 84,000 107,000 143,000 154,000 135,000 147,000 197,000 226,000 254,000 272,000 241,344

Southeast 34,000 39,000 49,000 49,000 58,000 62,000 63,000 59,000 43,000 43,000 35,772

Total 570,000 586,000 609,000 618,000 602,000 570,100 654,000 727,000 761,000 816,000 667,780

Source: 

http://www.pelletheat.org/3/industry/marketResearch.html#

Note: * Represents heating season, not annual season. 1st Quarter April-June, 2nd Quarter July-Sept, 

3rd Quarter Oct-Dec, 4th Quarter Jan-Mar. 

Table 5.20 

Pellet Appliance Shipments from Manufacturers 

1998 1999 2000 2001 2002 2003 2004

34,000 18,400 31,000 53,500 34,000 48,500 67,000

Source: 

Statistics are gathered by Hearth, Patio & Barbecue Association, 

http://www.pelletheat.org/3/industry/marketResearch.html#
 127

Biomass Energy Data Book: Edition 1 

Tertiary Biomass Feedstocks

Tertiary biomass includes post consumer residues and wastes, such as fats, greases, oils, construction 

and demolition wood debris, other waste wood from the urban environments, as well as packaging 

wastes, municipal solid wastes, and landfill gases.

The category “other wood waste from the urban environment” could include trimmings from urban trees, 

which technically fits the definition of primary biomass. However, because this material is normally 

handled as a waste stream along with other post-consumer wastes from urban environments (and 

included in those statistics), it makes the most sense to consider it to be part of the tertiary biomass 

stream.

The proper categorization of fats and greases may be debatable since those are byproducts of the 

reduction of animal biomass into component parts. However, since we are considering animals to be a 

type of biomass processing factory and since most fats and greases, and some oils, are not available for 

bioenergy use until after they become a post-consumer waste stream, it seems appropriate for them to be 

included in the tertiary biomass category. Vegetable oils derived from processing of plant components 

and used directly for bioenergy (e.g., soybean oil used in biodiesel) would be a secondary biomass 

resource, though amounts being used for bioenergy are most likely to be tracked together with fats, 

greases and waste oils.

Source: Lynn Wright, Oak Ridge, TN. 
128 

Biomass Energy Data Book: Edition 1 

Construction and demolition produce a sizeable amount of biomass material, though, recovery and use of 

those materials pose economic challenges. 

Figure 5.9 

Total Construction and Demolition Residues 

Source: 

Bioenergy Resource and Engineering Systems Program, Oak Ridge National Laboratory. 

Note: For information on estimation methods used, see: Appendix C - Estimation Methods for Urban 

Wood Residues. 
 129

Biomass Energy Data Book: Edition 1 

Table 5.21 

Residues from Construction and Demolition by Statea

(Dry tons) 

State

Alabama 756,670 97,340 854,010

Arizona 14,410 152,970 167,380

Arkansas 254,800 44,660 299,460

California 11,530 1,288,300 1,299,830

Colorado 12,860 166,950 179,800

Connecticut 19,040 102,160 121,200

Delaware 1,590 28,700 30,290

Florida 710,340 536,140 1,246,480

Georgia 262,520 263,920 526,430

Idaho 83,570 50,100 133,670

Illinois 25,720 439,390 465,100

Indiana 64,290 204,710 269,000

Iowa 25,720 77,150 102,860

Kansas 803,600 79,840 883,440

Kentucky 1,729,530 89,470 1,819,000

Louisiana 424,660 84,960 509,620

Maine 63,470 35,790 99,270

Maryland 15,870 212,560 228,430

Massachusetts 12,690 166,900 179,600

Michigan 38,570 322,840 361,420

Minnesota 507,870 173,520 681,400

Mississippi 509,590 47,130 556,720

Missouri 25,720 161,510 187,230

Montana 12,860 19,960 32,820

Nebraska 122,150 53,460 175,610

Nevada 11,530 102,140 113,660

New Hampshire 1,590 31,680 33,270

New Jersey 1,590 243,210 244,790

New Mexico 46,330 36,980 83,300

New York 155,510 455,070 610,580

North Carolina 470,990 270,110 741,100

North Dakota 1,125,030 14,660 1,139,700

Ohio 469,300 340,690 809,990

Oklahoma 30,880 61,110 92,000

Oregon 17,290 165,790 183,080

Pennsylvania 7,930 303,920 311,860

Rhode Island 6,350 26,600 32,940

South Carolina 972,860 103,250 1,076,110

South Dakota 141,430 20,980 162,410

Tennessee 509,590 145,030 654,620

Texas 370,610 518,760 889,370

Utah 126,790 77,380 204,170

Vermont 1,590 17,050 18,630

Virginia 169,860 238,150 408,010

Washington 97,980 288,580 386,560

West Virginia 223,910 32,980 256,900

Wisconsin 225,010 189,980 414,980

Wyoming 6,430 15,490 21,910

Total 11,700,000 8,600,000 20,300,000

Demolition Construction Total

Source: 

Bioenergy Resource and Engineering Systems Program, Oak Ridge National 

Laboratory. 

Note: For information on estimation methods used, see: Appendix C - Estimation 

Methods for Urban Wood Residues. 
130 

Biomass Energy Data Book: Edition 1 

Although municipal solid wood waste residues constitute a significant amount of biomass material, it is 

important to note that it may not be available at a cost that is economically viable. 

Figure 5.10 

Total Municipal Solid Waste Wood Residues

Source: 

Bioenergy Resource and Engineering Systems Program, Oak Ridge National Laboratory. 

Note: For information on estimation methods used, see: Appendix C - Estimation Methods for Urban 

Wood Residues. 
 131

Biomass Energy Data Book: Edition 1 

Table 5.22 

Residues from Municipal Solid Waste Landfills by State 

(Dry tons)

State

Alabama 77,840 21,840 99,680

Arizona 86,060 27,090 113,150

Arkansas 45,020 10,510 55,530

California 1,144,880 308,330 1,453,210

Colorado 72,370 25,310 97,680

Connecticut 14,250 4,820 19,070

Delaware 27,960 8,800 36,750

Florida 400,940 107,570 508,510

Georgia 205,650 52,850 258,500

Idaho 17,900 5,120 23,020

Illinois 170,570 57,900 228,470

Indiana 150,330 50,450 200,780

Iowa 32,740 10,990 43,730

Kansas 32,830 11,500 44,340

Kentucky 85,700 22,600 108,300

Louisiana 58,440 17,350 75,800

Maine 13,490 4,410 17,890

Maryland 64,160 21,090 85,250

Massachusetts 67,640 22,200 89,840

Michigan 191,150 65,960 257,110

Minnesota 50,620 16,800 67,420

Mississippi 75,770 22,720 98,490

Missouri 119,280 39,840 159,130

Montana 8,400 2,930 11,330

Nebraska 20,910 7,160 28,070

Nevada 49,210 15,810 65,020

New Hampshire 11,110 3,780 14,890

New Jersey 99,140 32,530 131,660

New Mexico 54,820 17,650 72,470

New York 358,210 116,590 474,790

North Carolina 252,710 69,010 321,730

North Dakota 6,360 2,220 8,580

Ohio 161,680 55,510 217,190

Oklahoma 50,060 17,600 67,650

Oregon 74,210 20,340 94,550

Pennsylvania 123,940 41,090 165,020

Rhode Island 19,690 6,650 26,340

South Carolina 83,240 21,760 105,000

South Dakota 6,000 1,990 7,990

Tennessee 93,760 23,900 117,660

Texas 905,870 228,970 1,134,840

Utah 31,790 10,890 42,680

Vermont 6,680 2,220 8,900

Virginia 188,360 50,090 238,450

Washington 112,780 31,660 144,440

West Virginia 28,110 7,750 35,850

Wisconsin 41,160 13,790 54,960

Wyoming 6,230 2,180 8,400

Total 6,000,000 1,740,100 7,740,100

MSW wood Yard trimmings Total

Source: 

Bioenergy Resource and Engineering Systems Program, Oak Ridge National Laboratory. 

Note: For information on estimation methods used, see: Appendix C - Estimation 

Methods for Urban Wood Residues. 
132 

Biomass Energy Data Book: Edition 1 

Landfill gas is becoming a more prominent source of energy; all but nine states are using landfill gas to 

some extent. There are a number of states that are utilizing the majority of landfill sites available to them. 

Table 5.23 

Landfill Gas Projects and Candidate Landfills by State, January 2006

State Operational Projects Candidate Landfills

Alabama 3 21

Alaska 0 1

Arizona 4 13

Arkansas 1 5

California 73 40

Colorado 0 13

Connecticut 2 6

Delaware 1 3

Florida 11 18

Georgia 7 19

Hawaii 0 8

Idaho 1 3

Illinois 36 25

Indiana 17 16

Iowa 3 11

Kansas 4 6

Kentucky 4 18

Louisiana 2 10

Maine 0 2

Maryland 4 12

Massachusetts 18 3

Michigan 27 9

Minnesota 4 8

Mississippi 1 11

Missouri 5 18

Montana 0 5

Nebraska 1 5

Nevada 0 5

New Hampshire 6 a

New Jersey 12 3

New Mexico 0 1

New York 16 21

North Carolina 11 38

North Dakota 1 1

Ohio 18 28

Oklahoma 4 13

Oregon 4 7

Pennsylvania 23 19

Rhode Island 2 *

South Carolina 3 20

South Dakota 0 2

Tennessee 6 13

Texas 18 55

Utah 1 5

Vermont 3 1

Virginia 15 16

Washington 6 8

West Virginia 0 7

Wisconsin 18 11

Wyoming 0 1

U.S. Total 396 584

Source: 

EPA’s Landfill Methane Outreach Program. January 9, 2006. 

_______________________ 

a

 No data available. 
 133

Biomass Energy Data Book: Edition 1 

APPENDIX A 

CONVERSIONS
134 

Biomass Energy Data Book: Edition 1 
 135

Biomass Energy Data Book: Edition 1 

Table A.1 

Heat Content for Various Fuels

Automotive gasoline 125,000 Btu/gal(gross) = 115,400 Btu/gal(net)

Hydrogen 134,200 Btu/kg(gross) = 113,400 Btu/kg(net)

Diesel motor fuel 138,700 Btu/gal (gross) = 128,700 Btu/gal (net)

Biodiesel 126,206 Btu/gal (gross) = 117,093 Btu/gal (net)

Methanol 64,600 Btu/gal (gross) = 56,560 Btu/gal (net)

Ethanol 84,600 Btu/gal (gross) = 75,670 Btu/gal (net)

Gasohol 120,900 Btu/gal (gross) = 112,417 Btu/gal (net)

Aviation gasoline 120,200 Btu/gal (gross) = 112,000 Btu/gal (net)

Propane 91,300 Btu/gal (gross) = 83,500 Btu/gal (net)

Butane 103,000 Btu/gal (gross) = 93,000 Btu/gal (net)

Jet fuel (naphtha) 127,500 Btu/gal (gross) = 118,700 Btu/gal (net)

Jet fuel (kerosene) 135,000 Btu/gal (gross) = 128,100 Btu/gal (net)

Lubricants 144,400 Btu/gal (gross) = 130,900 Btu/gal (net)

Waxes 131,800 Btu/gal (gross) = 120,200 Btu/gal (net)

Asphalt and road oil 158,000 Btu/gal (gross) = 157,700 Btu/gal (net)

Petroleum coke 143,400 Btu/gal (gross)

Natural gas

Wet 1,109 Btu/ft3

Dry 1,027 Btu/ft3

Compressed 20,551 Btu/pound

960 Btu/cubic foot

Liquid 90,800 Btu/gal (gross) = 87,600 Btu/gal (net)

Crude petroleum 138,100 Btu/gal (gross) = 131,800 Btu/gal (net)

Fuel Oils

Residual 149,700 Btu/gal (gross) = 138,400 Btu/gal (net)

Distillate 138,700 Btu/gal (gross) = 131,800 Btu/gal (net)

Coal

Anthracite - Consumption 21.711 x 106

 Btu/short ton

Bituminous and lignite - Consumption 21.012 x 106

 Btu/short ton

Production average 21.352 x 106

 Btu/short ton

Consumption average 21.015 x 106

 Btu/short ton
136 

Biomass Energy Data Book: Edition 1 

Table A.2 

Approximate Heat Content of Selected Fuels for Electric Power Generation

Fossil Fuelsa

Residual Oil (million Btu per barrel) 6.287

Distillate Oil (million Btu per barrel) 5.799

Natural Gas (Btu per million cubic ft) 1,027

Coal (million Btu per Short Ton) 20.411

Biomass Materialsb 

Switchgrass Btu per pound 7,341

Bagasse, Btu per pound 6,065

Rice Hulls, Btu per pound 6,575

Poultry Litter, Btu per pound 6,187

Solid wood waste, Btu per pound 6,000-8,000

_______________________ 

a

 EIA, Annual Energy Outlook 2006, DOE/EIA-0383 (2006) (Washington, DC, February 2006), 

Table G1. 

b

 Animal Waste Screening Study, Electrotek Concepts, Inc., Arlington, VA. June 2001. 

Table A.3 

Alternative Measures of Greenhouse Gases

1 pound methane, measured in carbon = 1.333 pounds methane, measured at

units (CH4) full molecular weight (CH4)

1 pound carbon dioxide, measured in = 3.6667 pounds carbon dioxide, measured at 

carbon units (CO2-C) full molecular weight (CO2)

1 pound carbon monoxide, measured in = 2.333 pounds carbon monoxide, measured at

carbon units (CO-C) full molecular weight (CO)

1 pound nitrous oxide, measured in = 1.571 pounds nitrous oxide, measured at 

nitrogen units (N2O-N) full molecular weight (N2O)
 137

Biomass Energy Data Book: Edition 1 

Table A.4 

Area Conversions

1 acrea = 0.405 hectare. 

1 are = 119.599 square yards. 0.025 acre. 

1 hectare = 2.471 acres. 

[1 square (building)] = 100 square feet. 

1 square centimeter (cm2

) = 0.155 square inch. 

1 square decimeter (dm2

) = 15.500 square inches. 

1 square foot (ft2

) = 929.030 square centimeters. 

1 square inch (in2

) = 6.451 6 square centimeters (exactly). 

1 square kilometer (km2

) = 247.104 acres. 0.386 square mile. 

1 square meter (m2

) = 1.196 square yards. 10.764 square feet. 

 1 square mile (mi2

) = 258.999 hectares. 

 1 square millimeter (mm2

) = 0.002 square inch. 

 1 square rod (rd2

), sq pole, or sq perch = 25.293 square meters. 

 1 square yard (yd2

) = 0.836 square meter. 

Source: 

National Institute of Standards and Technology, General Tables of Units and Measurements, 

http://ts.nist.gov/ts/htdocs/230/235/owmhome.htm

_______________________ 

a

 An acre is a unit of area containing 43,560 square feet. It is not necessarily square, or even 

rectangular. But, if it is square, then the length of a side is equal to the square root of 43,560 or about 

208.71 feet. 
138 

Biomass Energy Data Book: Edition 1 

Table A.5 

Areas and Crop Yields 

1.0 US ton/acre = 2.24 t/ha

A "target" bioenergy crop yield might be:

5.0 US tons/acre (10,000 lb/acre) = 11.2 tonnes/hectare (1120 g/m^2)

1.0 metric tonne/hectare = 0.446 ton/acre

100 g/m^2 = 1.0 tonne/hectare = 892 lb/acre

US bushel = 0.0352 m^3 = 0.97 UK bushel = 56 lb, 25 kg (corn or sorghum) = 60 lb, 27 kg (wheat or 

soybeans) = 40 lb, 18 kg (barley)

1.0 hectare = 10,000 m^2 (an area 100 m x 100 m, or 328 x 328 ft) = 2.47 acres

1.0 acre = 0.405 hectares

1.0 km^2 = 100 hectares = 247 acres

Source: 

Bioenergy Feedstock Information Network, http://bioenergy.ornl.gov/. 

Table A.6 

Biomass Energy Conversions 

1.0 metric tonne wood = 1.4 cubic meters (solid wood, not stacked)

Metric tonne biodiesel = 37.8 GJ (33.3 - 35.7 MJ/liter)

Energy content of wood fuel (air dry, 20% moisture) = about 15 GJ/t (6,400 Btu/lb)

Ethanol energy content = 11,500 Btu/lb = 75,700 Btu/gallon = 26.7 GJ/t = 21.1 MJ/liter

Ethanol HHV = 84,000 Btu/gallon = 89 MJ/gallon = 23.4 MJ/liter

Ethanol Density (average) = 0.79 g/ml (= metric tonnes/m^3)

biodiesel density (average) = 0.88 g/ml (= metric tonnes/m^3)

Energy content of agricultural residues (range due to moisture content) = 10-17 GJ/t (4,300-7,300 Btu/lb)

Metric tonne charcoal = 30 GJ (= 12,800 Btu/lb)

(but usually derived from 6-12 t air-dry wood, i.e. 90-180 GJ original energy content)

Metric tonne ethanol = 7.94 petroleum barrels = 1262 liters

Cord: a stack of wood comprising 128 cubic feet (3.62 m^3); standard dimensions are 4 x 4 x 8 feet, including air

space and bark. One cord contains approx. 1.2 U.S. tons (oven-dry) = 2400 pounds = 1089 kg

Energy content of wood fuel (HHV, bone dry) = 18-22 GJ/t (7,600-9,600 Btu/lb)

Source: 

Bioenergy Feedstock Information Network, http://bioenergy.ornl.gov/
 139

Biomass Energy Data Book: Edition 1 

Table A.7 

Distance and Velocity Conversions

1 in. = 83.33 x 10-3 ft 1 ft = 12.0 in.

= 27.78 x 10-3 yd = 0.33 yd

= 15.78 x 10-6 mile = 189.4 x 10-3 mile

= 25.40 x 10-3 m = 0.3048 m

= 0.2540 x 10-6 km = 0.3048 x 10-3 km

1 mile = 63360 in. 1 km = 39370 in.

= 5280 ft = 3281 ft

= 1760 yd = 1093.6 yd

= 1609 m = 0.6214 mile

= 1.609 km = 1000 m

1 ft/sec = 0.3048 m/s = 0.6818 mph = 1.0972 km/h

1 m/sec = 3.281 ft/s = 2.237 mph = 3.600 km/h

1 km/h = 0.9114 ft/s = 0.2778 m/s = 0.6214 mph

1 mph = 1.467 ft/s = 0.4469 m/s = 1.609 km/h

Table A.8 

Energy Unit Conversions 

1 Btu = 778.2 ft-lb 1 kWhr = 3412 Btua

= 107.6 kg-m = 2.655 x 106

 ft-lb

= 1055 J = 3.671 x 105

 kg-m

= 39.30 x 10-5 hp-h = 3.600 x 106

 J

= 39.85 x 10-5 metric hp-h = 1.341 hp-h

= 29.31 x 10-5 kWhr = 1.360 metric hp-h

1 kg-m = 92.95 x 10-4 Btu 1 Joule = 94.78 x 10-5 Btu

= 7.233 ft-lb = 0.7376 ft-lb

= 9.806 J = 0.1020 kg-m

= 36.53 x 10-7 hp-h = 37.25 x 10-8 hp-h

= 37.04 x 10-7 metric hp-h = 37.77 x 10-8 metric hp-

= 27.24 x 10-7 kWhr = 27.78 x 10-8 kWhr

1 hp-h = 2544 Btu 1 metric hp-h = 2510 Btu

= 1.98 x 106

 ft-lb = 1.953 x 106 ft-lb

= 2.738 x 106 kgm = 27.00 x 104

 kg-m

= 2.685 x 106

 J = 2.648 x 106 J

= 1.014 metric hp-h = 0.9863 hp-h

= 0.7475 kWhr = 0.7355 kWhr

__________ 

a

This figure does not take into account the fact that electricity generation and distribution efficiency 

is approximately 29%. If generation and distribution efficiency are taken into account, 1 kWhr = 11,765 

Btu. 
140 

Biomass Energy Data Book: Edition 1 

Table A.9 

Fuel Efficiency Conversions

MPG Miles/liter Kilometers/L L/100 kilometers

10 2.64 4.25 23.52

15 3.96 6.38 15.68

20 5.28 8.50 11.76

25 6.60 10.63 9.41

30 7.92 12.75 7.84

35 9.25 14.88 6.72

40 10.57 17.00 5.88

45 11.89 19.13 5.23

50 13.21 21.25 4.70

55 14.53 23.38 4.28

60 15.85 25.51 3.92

65 17.17 27.63 3.62

70 18.49 29.76 3.36

75 19.81 31.88 3.14

80 21.13 34.01 2.94

85 22.45 36.13 2.77

90 23.77 38.26 2.61

95 25.09 40.38 2.48

100 26.42 42.51 2.35

105 27.74 44.64 2.24

110 29.06 46.76 2.14

115 30.38 48.89 2.05

120 31.70 51.01 1.96

125 33.02 53.14 1.88

130 34.34 55.26 1.81

135 35.66 57.39 1.74

140 36.98 59.51 1.68

145 38.30 61.64 1.62

150 39.62 63.76 1.57

Formula MPG/3.785 MPG/[3.785/1.609] 235.24/MPG

Table A.10 

Mass Conversions

FROM Pound Kilogram Short ton Long ton Metric ton

Pound 1 0.4536 5.0 x 10-4 4.4643 x 10-4 4.5362 x 10-4

Kilogram 2.205 1 1.1023 x 10-3 9.8425 x 10-4 1.0 x 10-3

Short ton 2000 907.2 1 0.8929 0.9072

Long ton 2240 1016 1.12 1 1.016

Metric ton 2205 1000 1.102 0.9842 1

TO
 141

Biomass Energy Data Book: Edition 1 

Table A.11 

Power Conversions

Metric Kilocalories 

FROM Horsepower Kilowatts horsepower Ft-lb per sec per sec Btu per sec

Horsepower 1 0.7457 1.014 550 0.1781 0.7068

Kilowatts 1.341 1 1.360 737.6 0.239 0.9478

Metric

horsepower 0.9863 0.7355 1 542.5 0.1757 0.6971

Ft-lb per sec 1.36 x 10-3 1.356 x 10-3 1.84 x 10-3 1 0.3238 x 10-3 1.285 x 10-3

Kilocalories 

per sec 5.615 4.184 5.692 3088 1 3.968

Btu per sec 1.415 1.055 1.434 778.2 0.2520 1

TO
142 

Biomass Energy Data Book: Edition 1 

Table A.12 

Volume and Flow Rate Conversionsa

1 U.S. gal = 231 in.3 1 liter = 61.02 in.3

= 0.1337 ft3 = 3.531 x 10-2 ft3

= 3.785 liters = 0.2624 U.S. gal

= 0.8321 imperial gal = 0.2200 imperial gal

= 0.0238 bbl = 6.29 x 10-3 bbl

= 0.003785 m3 = 0.001 m3

1 imperial gal = 277.4 in.3 1 bbl = 9702 in.3 

= 0.1606 ft3 = 5.615 ft3

= 4.545 liters = 158.97 liters

= 1.201 U.S. gal = 42 U.S. gal

= 0.0286 bbl = 34.97 imperial gal

= 0.004546 m3 = 0.15897 m3

1 U.S. gal/hr = 3.209 ft3

/day = 1171 ft3/year

= 90.84 liter/day = 33157 liter/year

= 19.97 imperial gal/day = 7289 imperial gal/year

= 0.5712 bbl/day = 207.92 bbl/year

1 liter/hr = 0.8474 ft3

/day = 309.3 ft3/year

= 6.298 U.S. gal/day = 2299 U.S. gal/year

= 5.28 imperial gal/day = 1927 imperial gal/year

= 0.1510 bbl/day = 55.10 bbl/year

 

1 bbl/hr = 137.8 ft3

/year = 49187 ft3 /year

= 1008 U.S. gal/day = 3.679 x 105

 U.S. gal/year

= 839.3 imperial gal/day = 3.063 x 105

 imperial gal/year

= 3815 liter/day = 1.393 x 106 liter/day

A U.S. gallon of gasoline weighs 6.2 pounds

For Imperial gallons, multiply above values by 1.201

_______________________ 

a

 The conversions for flow rates are identical to those for volume measures, if the time units are 

identical. 
 143

Biomass Energy Data Book: Edition 1 

Table A.13 

International Energy Conversions

Giga- Million tonnes of Million GigawattTo: Terajoules calories oil equivalent Btu hours

From: multiply by:

Terajoules 1 238.8 2.388 x 10-5 947.8 0.2778

Gigacalories 4.1868 x 10-3 1 10-7 3.968 1.163 x 10-3

Million tonnes

 of oil equivalent 4.1868 x 104 107 1 3.968 x 107 11,630

Million Btu 1.0551 x 10-3 0.252 2.52 X 10-8 1 2.931 x 10-4

Gigawatthours 3.6 860 8.6 x 10-5 3412 1

Table A.14 

SI Prefixes and Their Values 

Value Prefix Symbol

One million million millionth 10-18 atto a

One thousand million millionth 10-15 femto f

One million millionth 10-12 pico p

One thousand millionth 10-9 nano n

One millionth 10-6 micro

One thousandth 10-3 milli m

One hundredth 10-2 centi c

One tenth 10-1 deci d

One 100

Ten 101 deca da

One hundred 102 hecto h

One thousand 103 kilo k

One million 106 mega M

One billiona 109 giga G

One trilliona 1012 tera T

One quadrilliona 1015 peta P

One quintilliona 1018 exa E

_______________________ 

a

 Care should be exercised in the use of this nomenclature, especially 

in foreign correspondence, as it is either unknown or carries a different value 

in other countries. A "billion," for example, signifies a value of 1012 in most 

other countries. 
144 

Biomass Energy Data Book: Edition 1 

Table A.15 

Metric Units and Abbreviations

Quantity Unit name Symbol

Energy joule J

Specific energy joule/kilogram J/kg

Specific energy consumption joule/kilogram•kilometer J/(kg•km)

Energy consumption joule/kilometer J/km

Energy economy kilometer/kilojoule km/kJ

Power kilowatt Kw

Specific power watt/kilogram W/kg

Power density watt/meter3 W/m3

Speed kilometer/hour km/h

Acceleration meter/second2 m/s2

Range (distance) kilometer km

Weight kilogram kg

Torque newton•meter N•m

Volume meter3 m3

Mass; payload kilogram kg

Length; width meter m

Brake specific fuel consumption kilogram/joule kg/J

Fuel economy (heat engine) liters/100 km L/100 km
 145

Biomass Energy Data Book: Edition 1 

APPENDIX B 

BIOMASS CHARACTERISTICS
146 

Biomass Energy Data Book: Edition 1 
 147

Biomass Energy Data Book: Edition 1 

APPENDIX B 

BIOMASS CHARACTERISTICS

Biomass feedstocks and fuels exhibit a wide range of physical, chemical, and agricultural/process 

engineering properties. Despite their wide range of possible sources, biomass feedstocks are remarkably 

uniform in many of their fuel properties, compared with competing feedstocks such as coal or petroleum. 

For example, there are many kinds of coals whose gross heating value ranges from 20 to 30 GJ/tonne 

(gigajoules per metric tonne; 8,600-12,900 Btu/lb). However, nearly all kinds of biomass feedstocks 

destined for combustion fall in the range 15-19 GJ/tonne (6,450-8,200 Btu/lb). For most agricultural 

residues, the heating values are even more uniform – about 15-17 GJ/tonne (6,450-7,300 Btu/lb); the 

values for most woody materials are 18-19 GJ/tonne (7,750-8,200 Btu/lb). Moisture content is probably 

the most important determinant of heating value. Air-dried biomass typically has about 15-20% moisture, 

whereas the moisture content for oven-dried biomass is around 0%. Moisture content is also an important 

characteristic of coals, varying in the range of 2-30%. However, the bulk density (and hence energy 

density) of most biomass feedstocks is generally low, even after densification, about 10 and 40% of the 

bulk density of most fossil fuels. Liquid biofuels have comparable bulk densities to fossil fuels. 

Most biomass materials are easier to gasify than coal because they are more reactive with higher ignition 

stability. This characteristic also makes them easier to process thermochemically into higher-value fuels 

such as methanol or hydrogen. Ash content is typically lower than for most coals, and sulphur content is 

much lower than for many fossil fuels. Unlike coal ash, which may contain toxic metals and other trace 

contaminants, biomass ash may be used as a soil amendment to help replenish nutrients removed by 

harvest. A few biomass feedstocks stand out for their peculiar properties, such as high silicon or alkali 

metal contents – these may require special precautions for harvesting, processing and combustion 

equipment. Note also that mineral content can vary as a function of soil type and the timing of feedstock 

harvest. In contrast to their fairly uniform physical properties, biomass fuels are rather heterogeneous with 

respect to their chemical elemental composition. 

Among the liquid biomass fuels, biodiesel (vegetable oil ester) is noteworthy for its similarity to petroleumderived diesel fuel, apart from its negligible sulfur and ash content. Bioethanol has only about 70% the 

heating value of petroleum distillates such as gasoline, but its sulfur and ash contents are also very low. 

Both of these liquid fuels have lower vapor pressure and flammability than their petroleum-based 

competitors – an advantage in some cases (e.g., use in confined spaces such as mines) but a 

disadvantage in others (e.g., engine starting at cold temperatures). 

The following pages contain three tables that show some "typical" values or range of values for selected 

compositional, chemical and physical properties of biomass feedstocks and liquid biofuels. Figures for 

fossil fuels are provided for comparison. 

References for further information: 

US DOE Biomass Feedstock Composition and Property Database

PHYLLIS - database on composition of biomass and waste

Nordin, A. (1994) Chemical elemental characteristics of biomass fuels. Biomass and Bioenergy 6, 

pp. 339-347. 

Source: 

Information in Appendix B is from a fact sheet by Jonathan Scurlock, Oak Ridge National Laboratory, 

Bioenergy Feedstock Development Programs. P.O. Box 2008, Oak Ridge, TN 37831-6407. 
148 

Biomass Energy Data Book: Edition 1 

Table B.1 

Composition of Selected Feedstocks

 Cellulose (%) Hemi-cellulose (%) Lignin (%)

corn stover 35 28 16-21 

sweet 27 25 11 

sorghum **  

sugarcane 32-48 19-24 23-32 

bagasse **  ** **

sugarcane   ** 

leaves **  

hardwood 45 30 20 

softwood 42 21 26 

hybrid 42-56 18-25 21-23 

poplar **  ** **

bamboo 41-49 24-28 24-26 

switchgrass 44-51 42-50? 13-20 

miscanthus 44 24 17 

Arundo donax 31 30 21 

bioethanol N/A N/A N/A 

biodiesel N/A N/A N/A 

Coal (low rank; lignite/subbituminous) N/A N/A N/A 

Coal (high rank 

bituminous/anthracite) N/A N/A N/A 

Oil (typical distillate) N/A N/A N/A 

Fossil Fuels

Bioenergy 

Feedstocks

Liquid Biofuels 

Source: 

Jonathan Scurlock, Oak Ridge National Laboratory, Bioenergy Feedstock Development Programs. P.O. 

Box 2008, Oak Ridge, TN 37831-6407 

Note: 

N/A = Not Applicable. 

** = Data not available. 
 149

Biomass Energy Data Book: Edition 1 

Table B.2 

Chemical Characteristics of Selected Feedstocks

Heating value 

(gross, unless 

specified; GJ/t) ash (%) sulfur (%) potassium (%)

Ash melting 

temperature 

[some ash 

sintering 

observed] (C) 

corn stover 17.6 5.6   ** 

sweet 15.4 5.5 **  

sorghum **  **   ** 

sugarcane 18.1 3.2-5.5 0.10- 0.73-0.97 **

bagasse   0.15 **  **

sugarcane 17.4 7.7   ** 

leaves **   **  **

hardwood 20.5 0.45 0.009 0.04 [900] 

softwood 19.6 0.3 0.01  

hybrid 19.0 0.5-1.5 0.03 0.3 1350 

poplar **  **   ** 

bamboo 18.5-19.4 0.8-2.5 0.03-0.05 0.15-0.50 **

switchgrass 18.3 4.5-5.8 0.12 ** 1016 

miscanthus 17.1-19.4 1.5-4.5 0.1 0.37-1.12 1090 [600] 

Arundo donax 17.1 5-6 0.07  

bioethanol 28 **  <0.01 ** N/A 

biodiesel 40 <0.02 <0.05 <0.0001 N/A 

Coal (low rank; lignite/subbituminous) 15-19 5-20 1.0-3.0 0.02-0.3 ~1300 

Coal (high rank 

bituminous/anthracite) 27-30 1-10 0.5-1.5 0.06-0.15 ~1300 

Oil (typical distillate) 42-45 0.5-1.5 0.2-1.2 ** N/A 

Bioenergy Feedstocks 

Liquid Biofuels 

Fossil Fuels 

Source: 

Jonathan Scurlock, Oak Ridge National Laboratory, Bioenergy Feedstock Development Programs. P.O. 

Box 2008, Oak Ridge, TN 37831-6407 

Note: 

N/A = Not Applicable. 

** = Data not available. 
150 

Biomass Energy Data Book: Edition 1 

Table B.3 

Physical Characteristics of Selected Feedstocks 

Cellulose fiber 

length (mm)

Chopped density 

at harvest 

(kg/m3)

Baled density 

[compacted bales] 

(kg/m3)

corn stover 1.5  

sweet **  ** **

sorghum   ** 

sugarcane 1.7 50-75 **

bagasse   ** 

sugarcane ** 25-40 **

leaves   ** 

hardwood 1.2 ** **

softwood   ** 

hybrid 1-1.4 150 (chips) **

poplar   ** 

bamboo 1.5-3.2 ** **

switchgrass ** 108 105-133 

miscanthus ** 70-100 130-150 [300] 

Arundo donax 1.2  

 

(typical bulk densities or 

range given below) 

bioethanol N/A N/A 790 

biodiesel N/A N/A 875 

Fossil Fuels 

Coal (low rank; lignite/subbituminous) N/A N/A 700 

Coal (high rank 

bituminous/anthracite) N/A N/A 850 

Oil (typical distillate) N/A N/A 700-900 

 

Liquid Biofuels 

Bioenergy 

Feedstocks

Source: 

Jonathan Scurlock, Oak Ridge National Laboratory, Bioenergy Feedstock Development Programs. P.O. 

Box 2008, Oak Ridge, TN 37831-6407 

Note: 

N/A = Not Applicable. 

**  = Data not available. 
 151

Biomass Energy Data Book: Edition 1 

APPENDIX C 

ASSUMPTIONS 
152 

Biomass Energy Data Book: Edition 1 
 153

Biomass Energy Data Book: Edition 1 

APPENDIX C 

ASSUMPTIONS 

ESTIMATION METHODS FOR PRIMARY MILL RESIDUES

The forestry residue data included in this book are the same as that used in the DOE/USDA publication 

entitled “Biomass as Feedstock for a Bioenergy and Bioproducts Industry: The Technical Feasibility of a 

Billion Ton Annual Supply.” The resource estimates contained in the following tables have been 

disaggregated to states.

Primary Mill Residues 

Primary mill residues include bark, coarse residues (chunks and slabs), and fine residues (shavings and 

sawdust) generated at sawmills that process harvested wood. The mill residue data were downloaded by 

state and county from the U.S. Forest Service’s Timber Product Output database 

(http://www.fia.fs.fed.us/tools-data/tools/). Because primary mill residues tend to be clean, uniform, 

concentrated, and of a low moisture content, most of these materials are already used for products or 

boiler fuel at the mills. The U.S Forest Service estimates current usage by type as follows: 

• Bark – 80% used as fuel and 13% used in products 

• Coarse residues – 85% used in products and 13% used as fuel 

• Fine residues – 55% used as fuel and 42% used in products 

This leaves a very small amount (~2%) of unused primary mill material available for energy. Residues are 

also generated at secondary processing mills (e.g., millwork, furniture, flooring, containers, etc.). 

Secondary mill residue data are not collected by the U.S. Forest Service. 

ESTIMATION METHODS FOR URBAN WOOD RESIDUES

The state-level estimates provided for urban wood residues are consistent with the estimates found in the 

DOE/USDA publication entitled “Biomass as Feedstock for a Bioenergy and Bioproducts Industry: The 

Technical Feasibility of a Billion Ton Annual Supply."

Residues for MSW Landfills 

MSW consists of a variety of items ranging from organic food scraps to discarded furniture and 

appliances. Wood and yard and tree trimmings are the two sources within this residue stream that are 

potentially recoverable for energy use. The wood component includes discarded furniture, pallets, 

containers, packaging materials, lumber scraps (other than new construction and demolition), and wood 

residuals from manufacturing. McKeever (2004) estimates the total wood component of the MSW stream 

at slightly more than 13 million dry tons. About 55% of this material is either recycled as compost, burned 

for power production, or unavailable for recovery because of excessive contamination. In total about 6 

million dry tons of MSW wood is potentially available for energy. The other component of the MSW 

stream — yard and tree trimmings — is estimated at 9.8 million dry tons. However, only 1.5 million dry 

tons is considered potentially available for recovery after accounting for what is currently used and what is 

unusable.
154 

Biomass Energy Data Book: Edition 1 

Residues from Construction and Demolition Debris Landfills 

The amount of available construction and demolition residue is correlated with economic activity (e.g., 

housing starts), population, demolition activity, and the extent of recycling and reuse programs. McKeever 

(2004) estimates annual generation of construction and demolition debris at 11.6 and 27.7 million dry 

tons, respectively. About 8.6 million dry tons of construction debris and 11.7 million dry tons of demolition 

debris are considered potentially available for energy. Unlike construction residue, which tends to be 

relatively clean and can be more easily source-separated, demolition debris is often contaminated, 

making recovery much more difficult and expensive.

Reference: McKeever, D. 2004. “Inventories of Woody Residues and Solid Wood Waste in the United 

States, 2002.” Ninth International Conference, Inorganic-Bonded Composite Materials. Vancouver, British 

Columbia. October 10-13.
 155

Biomass Energy Data Book: Edition 1 

GLOSSARY 
156 

Biomass Energy Data Book: Edition 1 
 157

Biomass Energy Data Book: Edition 1 

GLOSSARY 

Alcohol - The family name of a group of organic chemical compounds composed of carbon, hydrogen, 

and oxygen. The molecules in the series vary in chain length and are composed of a hydrocarbon 

plus a hydroxyl group. Alcohol includes methanol and ethanol.

Anaerobic digestion - Decomposition of biological wastes by micro-organisms, usually under wet 

conditions, in the absence of air (oxygen), to produce a gas comprising mostly methane and carbon 

dioxide. 

Annual removals - The net volume of growing stock trees removed from the inventory during a specified 

year by harvesting, cultural operations such as timber stand improvement, or land clearing.

ASABE Standard X593 - The American Society of Agricultural and Biological Engineers (ASABE) in 

2005 produced a new standard (Standard X593) entitled “Terminology and Definitions for Biomass 

Production, Harvesting and Collection, Storage, Processing, Conversion and Utilization.” The 

purpose of the standard is to provide uniform terminology and definitions in the general area of 

biomass production and utilization. This standard includes many terminologies that are used in 

biomass feedstock production, harvesting, collecting, handling, storage, pre-processing and 

conversion, bioenergy, biopower and bioproducts. The terminologies were reviewed by many 

experts from all of the different fields of biomass and bioenergy before being accepted as part of 

the standard. The full-text is included on the online Technical Library of ASABE 

(http://asae.frymulti.com); members and institutions holding a site license can access the online 

version. Print copies may be ordered for a fee by calling 269-429-0300, e-mailing 

martin@asabe.org, or by mail at: ASABE, 2950 Niles Rd., St. Joseph, MI 49085. 

Asexual reproduction - The naturally occurring ability of some plant species to reproduce asexually 

through seeds, meaning the embryos develop without a male gamete. This ensures the seeds will 

produce plants identical to the mother plant. 

Barrel of oil equivalent - (boe) The amount of energy contained in a barrel of crude oil, i.e. 

approximately 6.1 GJ (5.8 million Btu), equivalent to 1,700 kWh. A "petroleum barrel" is a liquid 

measure equal to 42 U.S. gallons (35 Imperial gallons or 159 liters); about 7.2 barrels are 

equivalent to one tonne of oil (metric). 

Biobased product - The term 'biobased product,' as defined by Farm Security and Rural Investment Act 

(FSRIA), means a product determined by the U.S. Secretary of Agriculture to be a commercial or 

industrial product (other than food or feed) that is composed, in whole or in significant part, of 

biological products or renewable domestic agricultural materials (including plant, animal, and 

marine materials) or forestry materials. 

Biochemical conversion - The use of fermentation or anaerobic digestion to produce fuels and 

chemicals from organic sources. 

Biodiesel - Fuel derived from vegetable oils or animal fats. It is produced when a vegetable oil or animal 

fat is chemically reacted with an alcohol. 

Bioenergy - Useful, renewable energy produced from organic matter - the conversion of the complex 

carbohydrates in organic matter to energy. Organic matter may either be used directly as a fuel, 

processed into liquids and gasses, or be a residual of processing and conversion. 

Bioethanol - Ethanol produced from biomass feedstocks. This includes ethanol produced from the 

fermentation of crops, such as corn, as well as cellulosic ethanol produced from woody plants or 

grasses.
158 

Biomass Energy Data Book: Edition 1 

Biorefinery - A facility that processes and converts biomass into value-added products. These products 

can range from biomaterials to fuels such as ethanol or important feedstocks for the production of 

chemicals and other materials. Biorefineries can be based on a number of processing platforms 

using mechanical, thermal, chemical, and biochemical processes. 

Biofuels - Fuels made from biomass resources, or their processing and conversion derivatives. Biofuels 

include ethanol, biodiesel, and methanol. 

Biogas - A combustible gas derived from decomposing biological waste under anaerobic conditions. 

Biogas normally consists of 50 to 60 percent methane. See also landfill gas. 

Biomass - Any organic matter that is available on a renewable or recurring basis, including agricultural 

crops and trees, wood and wood residues, plants (including aquatic plants), grasses, animal 

manure, municipal residues, and other residue materials. Biomass is generally produced in a 

sustainable manner from water and carbon dioxide by photosynthesis. There are three main 

categories of biomass - primary, secondary, and tertiary. 

Biomass energy - See Bioenergy. 

Biopower - The use of biomass feedstock to produce electric power or heat through direct combustion of 

the feedstock, through gasification and then combustion of the resultant gas, or through other 

thermal conversion processes. Power is generated with engines, turbines, fuel cells, or other 

equipment. 

Biorefinery - A facility that processes and converts biomass into value-added products. These products 

can range from biomaterials to fuels such as ethanol or important feedstocks for the production of 

chemicals and other materials. Biorefineries can be based on a number of processing platforms 

using mechanical, thermal, chemical, and biochemical processes. 

Bone dry - Having zero percent moisture content. Wood heated in an oven at a constant temperature of 

100°C (212°F) or above until its weight stabilizes is considered bone dry or oven dry. 

Bottoming cycle - A cogeneration system in which steam is used first for process heat and then for 

electric power production. 

Black liquor - Solution of lignin-residue and the pulping chemicals used to extract lignin during the 

manufacture of paper. 

British thermal unit - (Btu) A non-metric unit of heat, still widely used by engineers. One Btu is the heat 

energy needed to raise the temperature of one pound of water from 60°F to 61°F at one 

atmosphere pressure. 1 Btu = 1055 joules (1.055 kJ). 

Bunker - A storage tank. 

Carbon dioxide (CO2) - A colorless, odorless, non-poisonous gas that is a normal part of the ambient air. 

Carbon dioxide is a product of fossil fuel combustion. 

Closed-loop biomass - Crops grown, in a sustainable manner, for the purpose of optimizing their value 

for bioenergy and bioproduct uses. This includes annual crops such as maize and wheat, and 

perennial crops such as trees, shrubs, and grasses such as switchgrass.

Coarse materials - Wood residues suitable for chipping, such as slabs, edgings, and trimmings. 

Commercial species - Tree species suitable for industrial wood products. 
 159

Biomass Energy Data Book: Edition 1 

Conservation reserve program - CRP provides farm owners or operators with an annual per-acre rental 

payment and half the cost of establishing a permanent land cover in exchange for retiring 

environmentally sensitive cropland from production for 10 to 15 years. In 1996, Congress 

reauthorized CRP for an additional round of contracts, limiting enrollment to 36.4 million acres at 

any time. The 2002 Farm Act increased the enrollment limit to 39 million acres. Producers can 

offer land for competitive bidding based on an Environmental Benefits Index (EBI) during periodic 

signups, or can automatically enroll more limited acreages in practices such as riparian buffers, 

field windbreaks, and grass strips on a continuous basis. CRP is funded through the Commodity 

Credit Corporation (CCC). 

Cord - A stack of wood comprising 128 cubic feet (3.62 m^3); standard dimensions are 4 x 4 x 8 feet, 

including air space and bark. One cord contains approx. 1.2 U.S. tons (oven-dry) = 2400 pounds 

= 1089 kg.

Cropland - Total cropland includes five components: cropland harvested, crop failure, cultivated summer 

fallow, cropland used only for pasture, and idle cropland. 

Cropland used for crops - Cropland used for crops includes cropland harvested, crop failure, and 

cultivated summer fallow. Cropland harvested includes row crops and closely sown crops; hay 

and silage crops; tree fruits, small fruits, berries, and tree nuts; vegetables and melons; and 

miscellaneous other minor crops. In recent years, farmers have double-cropped about 4 percent 

of this acreage. Crop failure consists mainly of the acreage on which crops failed because of 

weather, insects, and diseases, but includes some land not harvested due to lack of labor, low 

market prices, or other factors. The acreage planted to cover and soil improvement crops not 

intended for harvest is excluded from crop failure and is considered idle. Cultivated summer 

fallow refers to cropland in sub-humid regions of the West cultivated for one or more seasons to 

control weeds and accumulate moisture before small grains are planted. This practice is optional 

in some areas, but it is a requirement for crop production in the drier cropland areas of the West. 

Other types of fallow, such as cropland planted with soil improvement crops but not harvested 

and cropland left idle all year, are not included in cultivated summer fallow but are included as 

idle cropland. 

Cropland pasture - Land used for long-term crop rotation. However, some cropland pasture is marginal 

for crop uses and may remain in pasture indefinitely. This category also includes land that was 

used for pasture before crops reached maturity and some land used for pasture that could have 

been cropped without additional improvement. 

Cull tree - A live tree, 5.0 inches in diameter at breast height (d.b.h.) or larger that is non-merchantable 

for saw logs now or prospectively because of rot, roughness, or species. (See definitions for 

rotten and rough trees.) 

d.b.h. - The diameter measured at approximately breast high from the ground. 

Digester - An airtight vessel or enclosure in which bacteria decomposes biomass in water to produce 

biogas. 

Discount rate - A rate used to convert future costs or benefits to their present value. 

Downdraft gasifier - A gasifier in which the product gases pass through a combustion zone at the 

bottom of the gasifier. 

Dutch oven furnace - One of the earliest types of furnaces, having a large, rectangular box lined with 

firebrick (refractory) on the sides and top. Commonly used for burning wood. Heat is stored in the 

refractory and radiated to a conical fuel pile in the center of the furnace. 
160 

Biomass Energy Data Book: Edition 1 

Effluent - The liquid or gas discharged from a process or chemical reactor, usually containing residues 

from that process. 

Emissions - Waste substances released into the air or water. See also Effluent. 

Energy crops - Crops grown specifically for their fuel value. These include food crops such as corn and 

sugarcane, and nonfood crops such as poplar trees and switchgrass. Currently, two energy crops 

are under development; short-rotation woody crops, which are fast-growing hardwood trees 

harvested in 5 to 8 years, and herbaceous energy crops, such as perennial grasses, which are 

harvested annually after taking 2 to 3 years to reach full productivity. 

Ethanol - Otherwise known as ethyl alcohol, alcohol, or grain-spirit. A clear, colorless, flammable 

oxygenated hydrocarbon with a boiling point of 78.5 degrees Celsius in the anhydrous state. In 

transportation, ethanol is used as a vehicle fuel by itself (E100 – 100% ethanol by volume), 

blended with gasoline (E85 – 85% ethanol by volume), or as a gasoline octane enhancer and 

oxygenate (10% by volume). 

Externality - A cost or benefit not accounted for in the price of goods or services. Often "externality" 

refers to the cost of pollution and other environmental impacts. 

Feedstock - A product used as the basis for manufacture of another product. 

Feller-buncher - A self-propelled machine that cuts trees with giant shears near ground level and then 

stacks the trees into piles to await skidding. 

Fermentation - Conversion of carbon-containing compounds by micro-organisms for production of fuels 

and chemicals such as alcohols, acids or energy-rich gases. 

Fiber products - Products derived from fibers of herbaceous and woody plant materials. Examples 

include pulp, composition board products, and wood chips for export. 

Fine materials - Wood residues not suitable for chipping, such as planer shavings and sawdust. 

Firm power - (firm energy) Power which is guaranteed by the supplier to be available at all times during a 

period covered by a commitment. That portion of a customer's energy load for which service is 

assured by the utility provider. 

Fluidized-bed boiler - A large, refractory-lined vessel with an air distribution member or plate in the 

bottom, a hot gas outlet in or near the top, and some provisions for introducing fuel. The fluidized 

bed is formed by blowing air up through a layer of inert particles (such as sand or limestone) at a 

rate that causes the particles to go into suspension and continuous motion. The super-hot bed 

material increased combustion efficiency by its direct contact with the fuel. 

Fly ash - Small ash particles carried in suspension in combustion products. 

Forest land - Land at least 10 percent stocked by forest trees of any size, including land that formerly 

had such tree cover and that will be naturally or artificially regenerated. Forest land includes 

transition zones, such as areas between heavily forested and nonforested lands that are at least 

10 percent stocked with forest trees and forest areas adjacent to urban and built-up lands. Also 

included are pinyon-juniper and chaparral areas in the West and afforested areas. The minimum 

area for classification of forest land is 1 acre. Roadside, streamside, and shelterbelt strips of trees 

must have a crown width of at least 120 feet to qualify as forest land. Unimproved roads and 

trails, streams, and clearings in forest areas are classified as forest if less than 120 feet wide. 
 161

Biomass Energy Data Book: Edition 1 

Forest residues - Material not harvested or removed from logging sites in commercial hardwood and 

softwood stands as well as material resulting from forest management operations such as 

precommercial thinnings and removal of dead and dying trees. 

Forest health - A condition of ecosystem sustainability and attainment of management objectives for a 

given forest area. Usually considered to include green trees, snags, resilient stands growing at a 

moderate rate, and endemic levels of insects and disease. Natural processes still function or are 

duplicated through management intervention. 

Fossil fuel - Solid, liquid, or gaseous fuels formed in the ground after millions of years by chemical and 

physical changes in plant and animal residues under high temperature and pressure. Oil, natural 

gas, and coal are fossil fuels. 

Fuel cell - A device that converts the energy of a fuel directly to electricity and heat, without combustion. 

Fuel cycle - The series of steps required to produce electricity. The fuel cycle includes mining or 

otherwise acquiring the raw fuel source, processing and cleaning the fuel, transport, electricity 

generation, waste management and plant decommissioning. 

Fuel treatment evaluator (FTE) - A strategic assessment tool capable of aiding the identification, 

evaluation, and prioritization of fuel treatment opportunities. 

Fuelwood - Wood used for conversion to some form of energy, primarily for residential use. 

Furnace - An enclosed chamber or container used to burn biomass in a controlled manner to produce 

heat for space or process heating. 

Gasohol - A mixture of 10% anhydrous ethanol and 90% gasoline by volume; 7.5% anhydrous ethanol 

and 92.5% gasoline by volume; or 5.5% anhydrous ethanol and 94.5% gasoline by volume. There 

are other fuels that contain methanol and gasoline, but these fuels are not referred to as gasohol. 

Gas turbine - (combustion turbine) A turbine that converts the energy of hot compressed gases 

(produced by burning fuel in compressed air) into mechanical power. Often fired by natural gas or 

fuel oil. 

Gasification - A chemical or heat process to convert a solid fuel to a gaseous form. 

Gasifier - A device for converting solid fuel into gaseous fuel. In biomass systems, the process is referred 

to as pyrolitic distillation. See Pyrolysis. 

Genetic selection - Application of science to systematic improvement of a population, e.g. through 

selective breeding. 

Gigawatt - (GW) A measure of electrical power equal to one billion watts (1,000,000 kW). A large coal or 

nuclear power station typically has a capacity of about 1 GW. 

Grassland pasture and range - All open land used primarily for pasture and grazing, including shrub 

and brush land types of pasture; grazing land with sagebrush and scattered mesquite; and all 

tame and native grasses, legumes, and other forage used for pasture or grazing. Because of the 

diversity in vegetative composition, grassland pasture and range are not always clearly 

distinguishable from other types of pasture and range. At one extreme, permanent grassland may 

merge with cropland pasture, or grassland may often be found in transitional areas with forested 

grazing land. 

Greenhouse effect - The effect of certain gases in the Earth’s atmosphere in trapping heat from the sun. 
162 

Biomass Energy Data Book: Edition 1 

Greenhouse gases - Gases that trap the heat of the sun in the Earth’s atmosphere, producing the 

greenhouse effect. The two major greenhouse gases are water vapor and carbon dioxide. Other 

greenhouse gases include methane, ozone, chlorofluorocarbons, and nitrous oxide. 

Grid - An electric utility company’s system for distributing power. 

Growing stock - A classification of timber inventory that includes live trees of commercial species 

meeting specified standards of quality or vigor. Cull trees are excluded. When associated with 

volume, includes only trees 5.0 inches in d.b.h. and larger. 

Habitat - The area where a plant or animal lives and grows under natural conditions. Habitat includes 

living and non-living attributes and provides all requirements for food and shelter. 

Hardwoods - Usually broad-leaved and deciduous trees. 

Heat rate - The amount of fuel energy required by a power plant to produce one kilowatt-hour of electrical 

output. A measure of generating station thermal efficiency, generally expressed in Btu per net 

kWh. It is computed by dividing the total Btu content of fuel burned for electric generation by the 

resulting net kWh generation. 

Heat transfer efficiency - useful heat output released / actual heat produced in the firebox. 

Heating value - The maximum amount of energy that is available from burning a substance. 

Hectare - Common metric unit of area, equal to 2.47 acres. 100 hectares = 1 square kilometer. 

Herbaceous - Non-woody type of vegetation, usually lacking permanent strong stems, such as grasses, 

cereals and canola (rape). 

HFCS - High fructose corn syrup. 

Higher heating value - (HHV) The maximum potential energy in dry fuel. For wood, the range is from 

7,600 to 9,600 Btu/lb (17.7 to 22.3 GJ/t). 

Horsepower - (electrical horsepower; hp) A unit for measuring the rate of mechanical energy output, 

usually used to describe the maximum output of engines or electric motors. 1 hp = 550 footpounds per second = 2,545 Btu per hour = 745.7 watts = 0.746 kW 

Hydrocarbon - A compound containing only hydrogen and carbon. The simplest and lightest forms of 

hydrocarbon are gaseous. With greater molecular weights they are liquid, while the heaviest are 

solids. 

Idle cropland - Land in cover and soil improvement crops, and cropland on which no crops were planted. 

Some cropland is idle each year for various physical and economic reasons. Acreage diverted 

from crops to soil-conserving uses (if not eligible for and used as cropland pasture) under federal 

farm programs is included in this component. Cropland enrolled in the Federal Conservation 

Reserve Program (CRP) is included in idle cropland. 

Incinerator - Any device used to burn solid or liquid residues or wastes as a method of disposal. In some 

incinerators, provisions are made for recovering the heat produced. 

Inclined grate- A type of furnace in which fuel enters at the top part of a grate in a continuous ribbon, 

passes over the upper drying section where moisture is removed, and descends into the lower 

burning section. Ash is removed at the lower part of the grate. 
 163

Biomass Energy Data Book: Edition 1 

Incremental energy costs - The cost of producing and transporting the next available unit of electrical 

energy. Short run incremental costs (SRIC) include only incremental operating costs. Long run 

incremental costs (LRIC) include the capital cost of new resources or capital equipment. 

Independent power producer - A power production facility that is not part of a regulated utility. 

Indirect liquefaction - Conversion of biomass to a liquid fuel through a synthesis gas intermediate step. 

Industrial wood - All commercial roundwood products except fuelwood. 

Joule - Metric unit of energy, equivalent to the work done by a force of one Newton applied over a 

distance of one meter (= 1 kg m2/s2). One joule (J) = 0.239 calories (1 calorie = 4.187 J). 

Kilowatt - (kW) A measure of electrical power equal to 1,000 watts. 1 kW = 3412 Btu/hr = 1.341 

horsepower. See also watt. 

Kilowatt hour - (kWh) A measure of energy equivalent to the expenditure of one kilowatt for one hour. 

For example, 1 kWh will light a 100-watt light bulb for 10 hours. 1 kWh = 3412 Btu. 

Landfill gas - A type of biogas that is generated by decomposition of organic material at landfill disposal 

sites. Landfill gas is approximately 50 percent methane. See also biogas. 

Levelized life-cycle cost - The present value of the cost of a resource, including capital, financing and 

operating costs, expressed as a stream of equal annual payments. This stream of payments can 

be converted to a unit cost of energy by dividing the annual payment amount by the annual 

kilowatt-hours produced or saved. By levelizing costs, resources with different lifetimes and 

generating capabilities can be compared. 

Lignin - Structural constituent of wood and (to a lesser extent) other plant tissues, which encrusts the cell 

walls and cements the cells together. 

Live cull - A classification that includes live cull trees. When associated with volume, it is the net volume 

in live cull trees that are 5.0 inches in d.b.h. and larger. 

Logging residues - The unused portions of growing-stock and non-growing-stock trees cut or killed by 

logging and left in the woods. 

Megawatt - (MW) A measure of electrical power equal to one million watts (1,000 kW). See also watt. 

Mill/kWh - A common method of pricing electricity in the United States. Tenths of a U.S. cent per kilowatt 

hour. 

Mill residue - Wood and bark residues produced in processing logs into lumber, plywood, and paper. 

MMBtu - One million British thermal units. 

Moisture content - (MC) The weight of the water contained in wood, usually expressed as a percentage 

of weight, either oven-dry or as received. 

Moisture content, dry basis - Moisture content expressed as a percentage of the weight of oven-dry 

wood, i.e.: [(weight of wet sample - weight of dry sample) / weight of dry sample] x 100 

Moisture content, wet basis - Moisture content expressed as a percentage of the weight of wood asreceived, i.e.: [(weight of wet sample - weight of dry sample) / weight of wet sample] x 100 
164 

Biomass Energy Data Book: Edition 1 

Monoculture - The cultivation of a single species crop. 

Net present value - The sum of the costs and benefits of a project or activity. Future benefits and costs 

are discounted to account for interest costs. 

Nitrogen fixation - The transformation of atmospheric nitrogen into nitrogen compounds that can be 

used by growing plants. 

Nitrogen oxides (NOx) - A product of combustion of fossil fuels whose production increases with the 

temperature of the process. It can become an air pollutant if concentrations are excessive. 

Noncondensing, controlled extraction turbine - A turbine that bleeds part of the main steam flow at 

one (single extraction) or two (double extraction) points. 

Nonforest land - Land that has never supported forests and lands formerly forested where use of timber 

management is precluded by development for other uses. (Note: Includes area used for crops, 

improved pasture, residential areas, city parks, improved roads of any width and adjoining 

clearings, powerline clearings of any width, and 1- to 4.5-acre areas of water classified by the 

Bureau of the Census as land. If intermingled in forest areas, unimproved roads and nonforest 

strips must be more than 120 feet wide, and clearings, etc., must be more than 1 acre in area to 

qualify as nonforest land.) 

Nonattainment area - Any area that does not meet the national primary or secondary ambient air quality 

standard established by the Environmental Protection Agency for designated pollutants, such as 

carbon monoxide and ozone. 

Nonindustrial private - An ownership class of private lands where the owner does not operate woodusing processing plants. 

Old growth- Timber stands with the following characteristics; large mature and over-mature trees in the 

overstory, snags, dead and decaying logs on the ground, and a multi-layered canopy with trees of 

several age classes. 

Open-loop biomass - Biomass that can be used to produce energy and bioproducts even though it was 

not grown specifically for this purpose. Examples of open-loop biomass include agricultural 

livestock waste, residues from forest harvesting operations and crop harvesting. 

Organic compounds- Chemical compounds based on carbon chains or rings and also containing 

hydrogen, with or without oxygen, nitrogen, and other elements. 

Other forest land - Forest land other than timberland and reserved forest land. It includes available forest 

land, which is incapable of annually producing 20 cubic feet per acre of industrial wood under 

natural conditions because of adverse site conditions such as sterile soils, dry climate, poor 

drainage, high elevation, steepness, or rockiness. 

Other removals - Unutilized wood volume from cut or otherwise killed growing stock, from cultural 

operations such as precommercial thinnings, or from timberland clearing. Does not include 

volume removed from inventory through reclassification of timberland to productive reserved 

forest land. 

Other sources - Sources of roundwood products that are not growing stock. These include salvable 

dead, rough and rotten trees, trees of noncommercial species, trees less than 5.0 inches d.b.h., 

tops, and roundwood harvested from non-forest land (for example, fence rows). 
 165

Biomass Energy Data Book: Edition 1 

Oxygenate - A substance which, when added to gasoline, increases the amount of oxygen in that 

gasoline blend. Includes fuel ethanol, methanol, and methyl tertiary butyl ether (MTBE). 

Particulate - A small, discrete mass of solid or liquid matter that remains individually dispersed in gas or 

liquid emissions. Particulates take the form of aerosol, dust, fume, mist, smoke, or spray. Each of 

these forms has different properties. 

Photosynthesis - Process by which chlorophyll-containing cells in green plants concert incident light to 

chemical energy, capturing carbon dioxide in the form of carbohydrates. 

Pilot scale - The size of a system between the small laboratory model size (bench scale) and a full-size 

system. 

Poletimber trees - Live trees at least 5.0 inches in d.b.h. but smaller than sawtimber trees. 

Present value - The worth of future receipts or costs expressed in current value. To obtain present value, 

an interest rate is used to discount future receipts or costs. 

Primary wood-using mill - A mill that converts roundwood products into other wood products. Common 

examples are sawmills that convert saw logs into lumber and pulp mills that convert pulpwood 

roundwood into wood pulp. 

Process heat - Heat used in an industrial process rather than for space heating or other housekeeping 

purposes. 

Producer gas - Fuel gas high in carbon monoxide (CO) and hydrogen (H2), produced by burning a solid 

fuel with insufficient air or by passing a mixture of air and steam through a burning bed of solid 

fuel. 

Public utility commissions - State agencies that regulate investor-owned utilities operating in the state. 

Public utility regulatory policies act - (PURPA) A federal law requiring a utility to buy the power 

produced by a qualifying facility at a price equal to that which the utility would otherwise pay if it 

were to build its own power plant or buy power from another source. 

Pulpwood - Roundwood, whole-tree chips, or wood residues that are used for the production of wood 

pulp. 

Pyrolysis - The thermal decomposition of biomass at high temperatures (greater than 400° F, or 200° C) 

in the absence of air. The end product of pyrolysis is a mixture of solids (char), liquids 

(oxygenated oils), and gases (methane, carbon monoxide, and carbon dioxide) with proportions 

determined by operating temperature, pressure, oxygen content, and other conditions. 

Quad: One quadrillion Btu (10^15 Btu) = 1.055 exajoules (EJ), or approximately 172 million barrels of oil 

equivalent. 

Recovery boiler - A pulp mill boiler in which lignin and spent cooking liquor (black liquor) is burned to 

generate steam. 

Refractory lining - A lining, usually of ceramic, capable of resisting and maintaining high temperatures. 

Refuse-derived fuel - (RDF) Fuel prepared from municipal solid waste. Noncombustible materials such 

as rocks, glass, and metals are removed, and the remaining combustible portion of the solid 

waste is chopped or shredded. RDF facilities process typically between 100 and 3,000 tons of 

MSW per day. 
166 

Biomass Energy Data Book: Edition 1 

Reserve margin - The amount by which the utility’s total electric power capacity exceeds maximum 

electric demand. 

Residues - Bark and woody materials that are generated in primary wood-using mills when roundwood 

products are converted to other products. Examples are slabs, edgings, trimmings, sawdust, 

shavings, veneer cores and clippings, and pulp screenings. Includes bark residues and wood 

residues (both coarse and fine materials) but excludes logging residues. 

Return on investment- (ROI) The interest rate at which the net present value of a project is zero. 

Multiple values are possible. 

Rotation - Period of years between establishment of a stand of timber and the time when it is considered 

ready for final harvest and regeneration. 

Rotten tree - A live tree of commercial species that does not contain a saw log now or prospectively 

primarily because of rot (that is, when rot accounts for more than 50 percent of the total cull 

volume). 

Rough tree - (a) A live tree of commercial species that does not contain a saw log now or prospectively 

primarily because of roughness (that is, when sound cull, due to such factors as poor form, splits, 

or cracks, accounts for more than 50 percent of the total cull volume) or (b) a live tree of 

noncommercial species. 

Roundwood products - Logs and other round timber generated from harvesting trees for industrial or 

consumer use. 

Salvable dead tree - A downed or standing dead tree that is considered currently or potentially 

merchantable by regional standards. 

Saplings - Live trees 1.0 inch through 4.9 inches in d.b.h. 

Saturated steam- Steam at boiling temperature for a given pressure. 

Secondary wood processing mills - A mill that uses primary wood products in the manufacture of 

finished wood products, such as cabinets, moldings, and furniture. 

Shaft horsepower - A measure of the actual mechanical energy per unit time delivered to a turning shaft. 

See also horsepower. 

Silviculture - Theory and practice of controlling the establishment, composition, structure and growth of 

forests and woodlands. Sound dead - The net volume in salvable dead trees. 

SRIC - Short rotation intensive culture - the growing of tree crops for bioenergy or fiber, characterized by 

detailed site preparation, usually less than 10 years between harvests, usually fast-growing 

hybrid trees and intensive management (some fertilization, weed and pest control, and possibly 

irrigation). 

Stand - (of trees) A tree community that possesses sufficient uniformity in composition, constitution, age, 

spatial arrangement, or condition to be distinguishable from adjacent communities. 

Steam turbine- A device for converting energy of high-pressure steam (produced in a boiler) into 

mechanical power which can then be used to generate electricity. 

Superheated steam - Steam which is hotter than boiling temperature for a given pressure. 
 167

Biomass Energy Data Book: Edition 1 

Surplus electricity- Electricity produced by cogeneration equipment in excess of the needs of an 

associated factory or business. 

Sustainable- An ecosystem condition in which biodiversity, renewability, and resource productivity are 

maintained over time. 

Synthetic ethanol - Ethanol produced from ethylene, a petroleum by-product.

Therm - A unit of energy equal to 100,000 Btus (= 105.5 MJ); used primarily for natural gas. 

Thermochemical conversion - Use of heat to chemically change substances from one state to another, 

e.g. to make useful energy products. 

Timberland - Forest land that is producing or is capable of producing crops of industrial wood, and that is 

not withdrawn from timber utilization by statute or administrative regulation. Areas qualifying as 

timberland are capable of producing more than 20 cubic feet per acre per year of industrial wood 

in natural stands. Currently inaccessible and inoperable areas are included. 

Timber Product Output Database Retrieval System (TPO) - Developed in support of the 1997 

Resources Planning Act (RPA) Assessment, this system acts as an interface to a standard set of 

consistently coded TPO data for each state and county in the country. This set of national TPO 

data consists of 11 data variables that describe for each county the roundwood products 

harvested, the logging residues left behind, the timber otherwise removed, and the wood and 

bark residues generated by its primary wood-using mills. 

Tipping fee - A fee for disposal of waste. 

Ton, Tonne - One U.S. ton (short ton) = 2,000 pounds. One Imperial ton (long ton or shipping ton) = 

2,240 pounds. One metric tonne(tonne) = 1,000 kilograms (2,205 pounds). One oven-dry ton or 

tonne (ODT, sometimes termed bone-dry ton/tonne) is the amount of wood that weighs one 

ton/tonne at 0% moisture content. One green ton/tonne refers to the weight of undried (fresh) 

biomass material - moisture content must be specified if green weight is used as a fuel measure. 

Topping cycle - A cogeneration system in which electric power is produced first. The reject heat from 

power production is then used to produce useful process heat. 

Topping and back pressure turbines - Turbines which operate at exhaust pressure considerably higher 

than atmospheric (noncondensing turbines). These turbines are often multistage types with 

relatively high efficiency. 

Transmission- The process of long-distance transport of electrical energy, generally accomplished by 

raising the electric current to high voltages. 

Traveling grate- A type of furnace in which assembled links of grates are joined together in a perpetual 

belt arrangement. Fuel is fed in at one end and ash is discharged at the other. 

Turbine - A machine for converting the heat energy in steam or high temperature gas into mechanical 

energy. In a turbine, a high velocity flow of steam or gas passes through successive rows of 

radial blades fastened to a central shaft. 

Turn down ratio- The lowest load at which a boiler will operate efficiently as compared to the boiler’s 

maximum design load. 

Waste streams - Unused solid or liquid by-products of a process. 
168 

Biomass Energy Data Book: Edition 1 

Water-cooled vibrating grate - A boiler grate made up of a tuyere grate surface mounted on a grid of 

water tubes interconnected with the boiler circulation system for positive cooling. The structure is 

supported by flexing plates allowing the grid and grate to move in a vibrating action. Ashes are 

automatically discharged. 

Watershed - The drainage basin contributing water, organic matter, dissolved nutrients, and sediments to 

a stream or lake. 

Watt - The common base unit of power in the metric system. One watt equals one joule per second, or 

the power developed in a circuit by a current of one ampere flowing through a potential difference 

of one volt. One Watt = 3.412 Btu/hr. See also kilowatt. 

Wheeling - The process of transferring electrical energy between buyer and seller by way of an 

intermediate utility or utilities. 

Whole-tree harvesting - A harvesting method in which the whole tree (above the stump) is removed. 

Yarding - The initial movement of logs from the point of felling to a central loading area or landing.