u.s. department of energy biomass program€¦ · · 2013-10-18corn and grains oilseeds and...
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U.S. Department of EnergyBiomass Program
September 11, 2009
Corn and Grains
Oilseeds and Plants
Agricultural Residues
Energy Crops
Forest Resources
Industrial and Other Wastes
Existing Corn Wet Mills
Existing Corn Dry Mills
Existing Oil Seed Mills
Agricultural Residue Processing
Energy Crops Processing(Woody energy crops and
perennial herbaceous crops)
Forest Resources Processing
(Includes existing and repurposed pulp and paper
and forest product mills)
Waste Processing
Biofuels
• Cellulosic ethanol• Green gasoline• Green diesel• Green jet fuel
Biopower
Bioproducts
Chemical Intermediates:• Organic acids• 1,4-diacids• Glycerol• Sorbitol• Xylitol
(Top Value Added Chemicals From Biomass, PNNL, NREL, DOE-OBP Analytical Study, 2004 )
Feedstock Production and Logistics Biomass Conversion End Uses
Major Biomass Pathways
428
377
368
58
87
48
Million dry ton/yr
Yield assumptions: Corn: 207 bushels/acre by 2043, Energy crops: 8 dry tons/yr by 2030Fuel Yield Assumption:1.366 billion dry tons biomass at 100 gallons/ton = 136.6 billions gallons/year
1366
Conversion Technologies
Biomass Program Objectives and Goals
Biochemical– Cost of converting
feedstocks to ethanol: $1.40/gal gasoline equivalent (gge) by 2012
Thermochemical– Cost of converting woody
feedstocks to ethanol: $1.30 gge by 2012
– Cost of converting woody feedstock to hydrocarbon fuels: $1.50 gge by 2017
IntegratedBiorefineries
Infrastructure
Research & Development Demonstration & Deployment
Sustainability & Analysis
• GHG emissions• Water quality
• Land use• Socioeconomics
– Sustainable regional biomass resources: 130 million dry tons/yr by 2012
– Improved logistics systems: $50/dry ton herbaceous by 2012
– Validate integrated process technologies
• 4 commercial scale
• 8 demonstration scale
• Up to 20 pilot or demonstration scale
• In total – over $1.1 Billion DOE investment
• Predictive Modeling• International
Increase understanding of and impacts on:
Make biofuels cost competitive with petroleum based on a modeled cost for mature technology at the refinery gateForecast to be $2.60/gal gasoline equivalent by 2017
Help create an environment conducive to maximizing production and use of biofuels, 21 billion gallons of advanced biofuels per year by 2022 (EISA) (14 billion gge)
– Testing of E15 & E20 and develop biofuelsdistribution infrastructure
Feedstock Systems
Deployment Barriers and Solutions
BasicR&D
Technology Development
Commercially Viable Demo
Permitting &Engineering
Proof of Concept Construction Operation
Co
mm
issi
on
ing
First Commercial Plant Mec
han
ical
co
mp
leti
on
Att
ain
men
t o
f p
erfo
rman
ce c
rite
ria
Del
ays
in a
ttai
nm
ent
of
per
form
ance
cri
teri
a
Operation
80% / 20% 50% / 50% <50% / >50% Loan Guarantee Program/Risk Mitigation Pool
Dev
elop
men
t Cos
ts
100% / 0%
Technology Validation at pilot (1 tpd) and demo (50-
70 tpd) scales
Procurement
Private Cost-Share:OBP Cost-Share:Project Timeline:
Development Stages:Unexpected Cost:
Risk Mitigation:
Private Sector Investment(Balance Sheet, Venture, and/or Institutional)Spurred by Risk Mitigation through Validation
Loan Guarantees
R&D Platforms
Four Commercial-Scale Biorefinergy Projects: up to $ 372 million (includes ARRA)
Eight Small-Scale 10% of Commercial Scale Biorefine ry Projects: up to $275 million
Up to 10-20 more pilot and or demonstration scale p rojects out of $480 ARRA solicitation
Biorefinery Projects funded by the Office of the Biomass Program
Pacific Ethanol Biochemical Wheat Straw/Corn Stover (Boardman, OR)
Blue FireBiochemicalMunicipal Solid Waste(Fulton, MS)
PoetBiochemicalCorn Stover(Emmetsburg, IA)
LignolBiochemicalWood Residues(CO)
AbengoaBiochemical/ThermoAg Waste, Switchgrass(Hugoton, KS)
NewPageThermochemicalWood Chips(Wisconsin Rapids, WI)
Range FuelsThermochemicalWood Chips(Soperton, GA)
KeyCompanyProcess Feedstock(Location)
Flambeau RiverThermochemicalWood Chips(Park Falls, WI)
RSEBiochemicalPulp extract
(Old Town, ME)
AlltechBiochemicalCorn Cob(KY)
MascomaBiochemical
Wood (Kinross, MI)
VereniumBiochemicalBagasse, Energy Cane(Jennings, LA)
MethodologyTopic Selection, Project & Program Review Processes
Planning
Program Implementation
Program Analysis and Evaluation
Biomass Technical Advisory Committee Annual Reports (2002 – 2008)Vision for Bioenergy and Biobased Products in the U.S. (2002, 2006)Roadmap for Bioenergy and Biobased Products in the U.S. (2002, 2007)Breaking the Biological Barriers (2005)Breaking the Thermochemical Barriers (2007)National Algal Biofuels Roadmap (TBD – 2009)Request for Information (Feedstock Logistics 2008)
Competitive Solicitation�USDA-DOE Joint Solicitation (2002 – 2009)�Commercial-Scale Biorefineries (2007) ($372M)�Demonstration-Scale Biorefineries (2008) ($275M)�Enzyme Cost Reduction (2008) ($34M)�Ethanologen Cost Reduction (2007) ($23M)�Syngas Clean Up (2008) ($7M)�Universities (2008) ($4M)�Pyrolysis (2009) ($9M)�Feedstock Logistics (2009) ($21M)
Labs�Core Research�Technology Validations
Stage Gate ReviewsExternal Biennial Peer Review (2009)*
Steering CommitteeNeal Gutterson Mendel TechnologiesJay Keller Sandia National Labs, SC ChairRoger Prince ExxonMobilLiz Marshall World Resources InstituteJohn May Stern Brothers (Financial)Terri Jaffoni Cargill (Retired)Susan Schoenung Bechtel R&D (Retired), SC Co-Chair
*8 Academics participate as reviewers
Budget Formulation
Feedback Loop
Biomass Program BudgetFiscal Years 2005 to 2010
†Figures are adjusted for SBIR, STTR, and rescission (if applicable)‡Note, Biofuels Infrastructure project funding ($19.8M) was appropriated through Integration of Biorefinery Technologies B&R Code*Requested; earmarks yet to be determined and rescission unknown
$89.9M‡
$0
$50
$100
$150
$200
$250
$300
FY11*FY10*FY09FY08FY07FY06FY05
Mill
ions Earmarks
Cellulosic Ethanol Reverse Auction
Large Scale Biopower
Analysis and Sustainability
Integration of BiorefineryTechnologiesProducts Development
Biochemical Platform R&D
Thermochemical Platform R&D
Feedstock Infrastructure
$231.8M
$292.2M
$275.8M
$45.3M$35.3M
$194.6M
$46.8M$43.1M
$1.8M$192.8M
$80.6M
$190.7M$85.1M
$78.0M$214.2M
$230.2M
$89.9M
Earmarks
Cellulosic Ethanol Reverse Auction
Large Scale Biopower
Analysis and Sustainability
Integration of BiorefineryTechnologiesProducts Development
Biochemical R&D
Thermochemical R&D
Feedstock Infrastructure
Directed
Discretionary
$0
$100
$200
$300
$400
$500
$600
$700
$800
ARRAFY10
Mill
ions
CollaborationsProgram Partners and Key Stakeholder Relationships
Biomass Program FundingFY2009: $217 Million
Project Performers• National Laboratories• Industry & Academic Project Partners
DOE Internal Collaboration
• Other EERE Program Offices • Office of Science• Office of Fossil Energy• Office of the Chief Financial Officer• Loan Guarantee Office
Federal CollaborationBiomass R&D Board: DOE, USDA, EPA, OFEE, NSF, DOI, OSTP, DOT, DOC, DOD, Treasury
Interagency Working Groups:
• Feedstock Production• Feedstock Logistics• Conversion• Infrastructure• Sustainability• Environmental, Safety, and Health
Non-Federal Collaboration• Biomass R&D Technical Advisory
Committee • Regional Biomass Energy Feedstock
Partnerships• International Energy Agency• State, Local, and International
Governments• Trade Associations, Nongovernmental
Organizations
Biomass Program Partners Organization Chart
• NREL• INL• ORNL• ANL• PNNL• SNL
National Labs27%
Systems Integration, Analysis & Evaluation
11%
Industry60%
University2%
$0.00
$0.50
$1.00
$1.50
$2.00
$2.50
$3.00
1 2 3 4 5
Min
imu
m C
on
vers
ion
Pro
cess
ing
Co
st o
f Eth
an
ol
Pro
du
ctio
n, $
/ga
llon
ga
solin
e (
20
07
$)
Opearting Costs
Capital Costs
Prehydrolysis/treatment
Enzymes
Saccharification &Fermentation
Distillation & SolidsRecovery
Balance of Plant
Biochemical Conversion/Enzymatic HydrolysisCost of ethanol production, $/gallon gasoline
$2.57 $2.42
$1.37
* Conversion costs represented in the figure above are based on conversion of corn stover and equate to an Minimum Gasoline Selling Price $2. 22 in 2012.
$2.67
2005 SOT
2007 SOT
2009Proj
2012Proj
2012Proj
2009 2012
Minimum Ethanol Selling Price ($/gge) $3.58 $2.22
Feedstock Contribution ($/gge) $1.12 $0.86Conversion Contribution ($/gge) $2.42 $1.37Yield (Gallon/dry ton) 78% 90%Technical ProjectionsFeedstockFeedstock Cost ($/dry ton) $57.50 $50.90PretreatmentSolids Loading (wt%) 30% 30%Xylan to Xylose 80% 90%Xylan to Degradation Products 8% 5%
Ammonia Loading (mL of 30wt% per L hydrolyzate) 50 25%
Hydrolyzate solid-liquid separation yes noXylose Sugar Loss 2% 1%Glucose Sugar Loss 1% 0%EnzymesEnzyme Contribution ($/gal EtOH) $0.52 $0.18Saccharification & FermentationToal Solids Loading (wt%) 20% 20%
Combined Saccharification & Fermentation Time (d) 7 3Corn Steep Liquor Loading (wt%) 1% 25%Overall Cellulose to Ethanol 85% 85%Xylose to Ethanol 80% 85%Minor Sugars to Ethanol 40% 85%
Conditioning
$1.37
Pretreatment
ResidueProcessing
ProductRecovery
Conditioning
EnzymeProduction
Co-fermentationOf C5 & C6
Sugars
EnzymaticHydrolysis
Ethanol
By-Products
Hybrid Saccharification & Fermentation - HSF
FeedProcessing& Handling
Reduction of sugar loss 13% (2005) to 1% (2012)
Xylan to Xylose76% (2005) to 85% (2012)
Minor sugars fermented (40%)
Thermochemical Conversion/GasificationCost of ethanol production, $/gallon gasoline
$(0.50)
$-
$0.50
$1.00
$1.50
$2.00
$2.50
$3.00
2005 State ofTechnology
2007 State ofTechnology
2009 Projection 2012 Projection 2012 Projection
Min
imum
Con
vers
ion
Pro
cess
ing
Cos
t of
Eth
anol
, $/
gallo
n ga
solin
e (2
007$
s)
Opearting Costs
Capital Costs
Feed Handling and Drying
Gasification
SynGas Cleanup &Conditioning
Fuels Synthesis
Product Recovery andPurification
Balance of Plant
$2.82 $2.82
$1.96
$1.28
* Conversion costs represented in the figure above are based on conversion of woody feedstocks and equate to an Minimum Gasoline Sellin g Price $2.38 in 2012.
$1.28
2009 2012
Minimum Ethanol Selling Price ($/gge) $3.42 $2.38
Conversion Contribution ($/gge) $1.98 $1.30
Ethanol Yield (gal EtOH/dry ton) 61.5 71.1Mixed Alcohol Yield 72.5 83.7Technical ProjectionsFeedstockFeedstock Cost ($/dry ton) $58.20 $50.70GasificationRaw Syngas Yield (lb/lb dry feed) 0.82 0.82Raw Syngas Methane (dry basis) 15% 15%Gasifier Efficiency (LHV) 76.1% 76.1%
Tar Reformer (TR) Exit CH4 (dry basis) (mole %) 3% 1%
TR Light CH 4 Conversion (%) 50% 80%TR Benzene Conversion (%) 90% 99%TR Heavy HC/Tar Conversion (%) 97% 99%Sulfur Level in Clean Gas (as H 2S) (ppmv) 50 50
Fuels SynthesisPressure (psia) 1500 1500Single Pass CO Conversion (%CO) 40.0% 50%Overall CO Conversion (%CO) 40.0% 50%
Selectivity to Alcohols (%C)) 80.0% 80.0%
Synthesis Gas Clean-up & Conditioning
FeedProcessing& Handling
Heat &
Power
Gasification
Indirect
Gas Cleanup
High TempSeparation
Gas Conditioning
Collection/Fractionation
Fuel Synthesis
Upgrading
Benzene Conversion 70% (2005) to 99%
(2012)
CO Conversion 40% (2005) to 50% (2012)
Products
Major Technology PlatformThermochemical Conversion/Pyrolysis
0
0.4
0.8
1.2
1.6
2017 Projection
Min
imum
Con
vers
ion
Pro
cess
ing
Cos
t of
Fue
l $/g
allo
n et
hano
l (20
07$s
)
Capital Costs
OperatingCostsNatural Gas
Catalysts andChemicalsUtilities
Fixed Costs
Financial
$1.56
* Conversion costs represented in the figure above are based on conversion of woody feedstocks to a hydrocarbon fuel (57% diesel, 43% g asoline) and equate to an Minimum Fuel Selling Price of $2.04 in 2017.
Numbers are primarily based on literature and bench scale data.
$1.56
FeedProcessing& Handling
Heat &
PowerPyrolysis Bio-Oil
StabilizationBio-Oil
Upgrading
65 lbs wet oil per 100 lbs dry woody
feedstock
65 gal fuel per ton woody feedstock
Fuel Synthesis
Products
Potential Technology Breakthroughs
Feedstocks
*Genetic sequencing, marker-aided breeding, and full deployment of agricultural biotechnology leads to increased feedstock yield, tolerance to stresses, and reliability of feedstock production systems.
Full realization of the Advanced Uniform-Format Solid Feedstock Supply System, which achieves a large-scale commodity and leads to a cellulosic feedstock supply in a standardized format that meets biorefinery standards.
*Algae feedstocks have the potential to increase the amount of non-food biomass above and beyond the potential of lignocellulosics.
Conversion
*Consolidated bioprocessing allows for significant capital cost reductions and process efficiencies by combining the hydrolysis and fermentation into a single microorganism or consortium of compatible microorganisms.
*Direct secretion of products (i.e., hydrocarbon fuels or lipid intermediates) that are not water/media miscible allow for efficient use of feedstocks and nutrient inputs.
Catalyst characterization and lifetime experiments enables significant capital cost reductions and the development of robust and efficient catalysts.
Advanced conversion technologies to utilize wet biomass and hydrothermal liquefaction such as wet gasification can reduce the capital costs associated with drying feedstocks.
* Relevant to Office of Science
Barriers to Speed and Scale
DOE cost share; streamline the NEPA process; assist in developing parallel technology solutions
Pilot and Demonstration Scale Biorefineries: financing uncertainty, NEPA process
Complete intermediate blends testing by Summer 2010; expansion of advanced biofuels R&D; focus on power & products
Near-term: Ethanol Blends; Long-term: Move to hydrocarbon fuels & power
R&D on GHG impacts, indirect land use, & carbon, nitrogen, phosphorus, & water fluxes; watershed-scale field trials
Public Acceptance – Sustainability
R&D on pre-treatment, cost-effective enzymes, pyrolysis oil upgrading, catalyst durability, etc.
Conversion technology breakthroughs
R&D on advanced feedstocks & logistics systems at scale that can support commercial biorefineries (for cellulosic & algal feedstocks)
Feedstock availability & logistics systems
Full implementation of BCAP; policy that values carbon & other environmental services; passage of RPS
Policy: partial implementation of BCAP, lack of monetization of benefits, no Renewable Portfolio Standard, etc.
Fix loan guarantee program to include biofuelsPioneer Plants: no process guarantees, financing uncertainty, no fixed price agreements, etc.
DOE SolutionBarriers
BACK-UP SLIDES
Market Barriers• Lack of cellulosic feedstock market• High capital and production costs • Inadequate feedstock, distribution, and end-
use infrastructure• NEPA delays• Ethanol blend wall• Impacts of economic downturn• Fluctuating petroleum prices
Remaining Needs• Create a single definition of “biomass” that would
apply retroactively• Support EPA RFS implementation• Make DOE/USDA loan guarantee programs more
customer friendly• Implement the USDA Biomass Crop Assistance
Program on a fast-track basis• Allow use of blends between E10 and E85• Accelerate FFV fleet penetration• Create and expand tax credits (investment tax
credit, Farm Bill production tax credit)
Technical Barriers• Collection equipment not optimized for cellulosic
feedstocks• Difficult to access and extract cellulosic energy
content• Lack of proven replicable production pathways• Lack of fully integrated large-scale systems
Steps Taken
• EISA and Farm Bill help establish a market demand for cellulosic biofuels
• Cost-shared biorefinery projects will help validate approaches
• Aim to increase extraction efficiency• DOE testing potential effects of higher ethanol
blends on vehicles and other engines• Recovery Act funding for R&D of advanced
biofuels beyond ethanol and biodiesel and for expansion of infrastructure for higher ethanol blends
Barriers to Speed and Scale of Technology
Project Management Center FY09 Activities
• Planning– Collaboratively plan FOAs with HQ, SI, Labs
• Budget Formulation– Detailed analysis of Project Budget needs & “mortgages”
• Program Implementation– Develop & Issue Funding Opportunity Announcement
(FOAs)– Conduct Merit Review– Negotiate awards– Oversight and Management of resulting projects
• Program Analysis and Evaluation– Work with SI to update Project Management Plan and
quarterly report templates – project plans and progress tied to Program goals, barriers, and milestones.
– Conduct Gate assessment reviews– Plan and implement WBS Area peer reviews with HQ
and SI
7
Pathways
“Outputs”
200 +
Projects
“Milestones”
1
Bioindustry
“Outcomes”
Project
Status
Vision
Status
Mission
Status
Pathway
Status
• May 5, 2009 Presidential Memorandum – Biomass Intera gency Working Group– High level with EPA, USDA, and DOE
• Develop Biofuels Industry• Coordinate Interagency Policy
• Biomass R&D Act of 2000 (amended by legislation)– Biomass Research & Development Board
• Biofuels Interagency Working Groups– Biomass Technical Advisory Committee
• Bioenergy Research Centers– Joint BioEnergy Institute (LBNL)– Bioenergy Science Center (ORNL)– Great Lakes BioEnergy Research Center (Univ. of WI)
• U.S. Feedstock Partnerships– Regional Feedstocks Partnerships– Council on Sustainable Biomass Production
• Global Partnerships– International Energy Agency– Conservation International– Global Bioenergy Partnership
Key Strategic Relationships
Recovery Act Funding and InitiativesBiomass R&D and Demonstration Projects - $800 Million in Funding
$480M Pilot and Demonstration-Scale BiorefineriesValidate technologies for integrated production of advancedbiofuels, products, and power to enable financing and replication.10 to 20 awards for refineries to be operational within 3 years:
Up to $25M for each pilot-scale projectUp to $50M for each demonstration-scale project
$176.5M Commercial-Scale BiorefineriesIncrease in funding for prior awards; two or more projectsExpedite construction; accelerate commissioning and start-up
$110M Fundamental Research$20M: Integrated Process Development Unit
$5M: Sustainability research with the Office of Science$35M: Advanced Biofuels Technology Consortium
$50M: Algal Biofuels Consortium to accelerate demonstration
$20M Ethanol Infrastructure ResearchOptimize flex-fuel vehicles operating on E85Evaluate impacts of intermediate blends on conventional vehiclesUpgrade existing infrastructure for compatibility with E85
$13.5M NREL Integrated Biorefinery Research Facility: expand the pretreatment capacity