Coal to Liquids (CTL): An Overview
Rio de Janeiro March 2007
Dr. Dan Driscoll Project Manager Gasification and Fuels Division
National Energy Technology Laboratory Interest Drivers for CTL
“Addicted to oil” – State of the Union address 2006 US petroleum imports in 2005 exceeded $250 billion 35% of energy consumption is from Oil 1 Daily world consumption is 84 million bbl/d – 20% higher than 1995 – expect 120 M by 2030 World vehicle ownership at 700 M; – double by 2030 to 1.5 billion; – developing countries to triple 96% of all energy used for transportation – largest demand for oil World oil supplies could peak between 2016 and 2037 2 Oil resources not equitably distributed globally; coal more wide spread Concerns in: Energy security and Economic Development Oil availability supply issues Infrastructure difficulties Coal remains the most abundant fossil fuel in the world. Products produced from oil can be made from coal. Outside Activities: National Coal Council Report (March 2006) identified capacity to support production of 2.6 million bpd of liquid fuels from coal by 2025. See www.NationalCoalCouncil.org Southern States Energy Board Report (July 2006) called for aggressive federal investment in CTL incentives “to encourage the private sector to step forward on a massive scale.” See www.AmericanEnergySecurity.org DOD Air Force Request for Interest in Military Alternative Fuels
1Ref: World Coal Institute Report “Coal-to-Liquids” November 2006 2Ref: Hirsch, Robert, et, al., “Peaking of World Oil Production: Impacts, Mitigation, & Risk Management”, NETL, February 2005 U.S. Dependence on Foreign Oil Oil Reserves Saudi Arabia 21% Canada 14% Iran 10% Iraq 9% Kuwait 8% U.A.E. 8% Venezuela 6% Russia 5% Libya 3% Nigeria 2% U.S. 2%
Rate of Use U.S. 25% Japan 7% China 7% Germany 3% Russia 3% The United States uses India 3% more oil than the next Canada 3% Brazil 3% five highest-consuming S. Korea 3% nations combined. France 3% Mexico 3% 0% 5% 10% 15% 20% 25% Updated July 2005. Source: International Energy Annual 2003 (EIA), Tables 1.2 and 8.1-O&GJ. Canada’s reserves include tar sands. U.S. Energy Sources
% of U.S. % of Total Electricity U.S. Energy Energy Source Supply Supply Oil 3 39 Natural Gas 15 23 Coal 51 22 Nuclear 20 8 Hydroelectric 8 4 Biomass 1 3 Other Renewables 1 1 Why Coal? Coal Reserves are Abundant
Years Supply at Current Production Rates
Provides over half 300 Nation’s electricity Abundant domestic 200 Western reserves 100 Eastern Low, relatively stable prices 0 Coal Oil Gas U. S. Coal Resources Are Widely Distributed Delineation of U.S. Coal Resources and Reserves
Sufficient reserve to meet projected demand for electricity and up to 4MMBPD CTL industry for over 100 years
1 ton of coal produces 2 barrels of liquid
Source: EIA Coal Reserves Data 1997 http://www.eia.doe.gov/cneaf/coal/reserves/chapter1.html#chapter1a.html Coal-to-Liquids – Rationale
U.S. economy requires a reliable supply of liquid fuels for national security and economic stability. Oil refineries operating at > 90% capacity, refining capacity highly concentrated in Gulf Coast Rising oil prices and imports, moratoriums for off-shore drilling Increasing concern about terrorism/natural disasters on petroleum supply chain.
Coal-derived liquid fuels can supplement oil-based fuels and moderate fuel price increases. Coal to Liquids Technologies Conversion Technologies: Direct Liquefaction (Bergius Hydrocracking) Indirect (Gasification + Fischer-Tropsch) Liquefaction.
Direct Liquefaction - Dormant in the U.S. but being actively pursued in China. The Shenhua project in Inner Mongolia will bring a full scale single train, 20,000 BPD commercial unit into production in 2008 using Headwaters technology.
Inner Mongolia Coal Liquefaction Plant Schematic, China 2006 Direct Coal Conversion Projects
Originally developed in Germany in 1917 Used to produce aviation fuel in WWII US spent $3.6 billion on DCC from 1975-2000 Headwaters Technology licensed to China in 2002
Lawrenceville, NJ Catlettsburg, KY Inner Mongolia, China 3 TPD (30 bpd) 250 – 600 TPD 4,200 TPD (1,800 bpd) (17,000 bpd) Direct Coal Conversion to Liquid Fuels
H2S, NH3, COx
Methane Make-up Recycled H 2 Gas Recovery & Ethane H2 Treatment LPG
Hydro- Coal + Coal Gasoline treating Refining Catalyst conversion Diesel Fuel Unit H-Donor Slurry
Slurry Fractionation Heavy Vacuum Gas Oil
Solvent Ash Reject Deashed Oil Deashing Gasifier Unconverted Coal Direct Conversion
Advantages Disadvantages Conceptually simple process High aromatic content Produces high-octane gasoline Low-cetane number diesel More energy efficient than indirect conversion Potential water and air (i.e. more fuel / BTUs emissions issues produced per ton of coal) Fuels produced are not a Products have higher good environmental fit energy density for the U.S. market (BTU/gallon) than May have higher indirect conversion operating expenses than indirect conversion Indirect Coal Conversion
Originally developed in Germany in 1923 (Franz Fischer and Hans Tropsch) Used to produce diesel fuel during WW-II Currently used to produce liquid fuels and chemicals in South Africa Example of Prior Large Scale US-based Facilities World Large Scale Facilities
Brownsville, TX 7,000 bpd GTL Plant
• Designed by HRI (Headwaters predecessor) • First commercial use of High Temp. FT • Operated 1950-55 • Shut down when oil price dropped due to Secunda, South Africa Middle East oil discoveries. 150,000 bpd Indirect Coal Conversion Coal Petcoke Biomass Oxygen/ etc Steam Catalyst
C H FT Product Gasification & H2 + CO Fischer-Tropsch x y Liquids Gas Cleaning Syngas Synthesis Separation & & Wax Upgrading
Steam Tail Gas Sulfur, Water Ultra-Clean CO2 & Liquid Fuels and Ash Oxygenates & Chemical Feedstocks Steam Electric Power Generation
Electricity Gasification- A Versatile Source of Fuels
Oxygen Extreme Conditions: .1,000 psig or more .2,600 Deg F .Corrosive slag and H2S gas
Coal, Products (syngas) biomass, CO (Carbon Monoxide) Gas pet. coke H2 (Hydrogen) Clean-Up [CO/H2 ratio can be adjusted] Before By-products Product H2S (Hydrogen Sulfide) Use CO2 (Carbon Dioxide) Slag (Minerals from Coal) Water Coal Gasification Chemistry
2C (coal) + ½O2 + H2O = 2CO + H2
Simultaneous Three Body Collisions are Unlikely Multiple Bi-Molecular Interaction Mechanism in Effect
C + O2 = CO2
C + CO2 = 2CO
C + ½O2 = CO
C + H2O = CO + H2
C + 2H2 = CH4 Gasifiers GE Energy ConocoPhillips KBR Shell Siemens (Chevron-Texaco) E-Gas Transport SCGP (GSP/Noell) Reactor
Slurry-feed Dry-feed Comparison of Gasifier Characteristics
Moving Bed Fluidized Bed Entrained Transport (Lurgi & BGL) (U-Gas & HTW) Flow Flow (GE, Shell, (KBR) E-Gas, Siemens) Ash Cond. Dry Slagging Dry Agglomerate Slagging Dry
Coal Feed ~2in ~2in ~1/4 in ~1/4 in ~ 100 Mesh ~1/16in
Fines Limited Better Good Better Unlimited Better than dry ash Coal Rank Low High Low Any Any Any
Gas Temp. (°F) 800-1,200 800-1,200 1,700-1,900 1,700-1,900 >2,300 1,500-1,900 Oxidant Req. Low Low Moderate Moderate High Moderate
Steam Req. High Low Moderate Moderate Low Moderate
Issues Fines and Carbon Conversion Raw gas Control Hydrocarbon liquids cooling carbon & inventory carryover Products from Syngas
Clean Electricity Gasification Clean Syngas and Gas Gas H2, CO, CO2 Cleaning Turbine Stationary Fuel Cells H2 Separation Building Shift Reaction of H CO2 for Blocks Methanation 2 for CO + H2OH2 + CO2 from CO Sequest CO + 3H CH + H O 2 Chemical 2 4 2 ration Industry Fischer- Tropsch or Methanol Synthesis H2 2nH2 + nCO (- CH2-)n + nH2O
Methane CO + 2H2 CH3OH (SNG) Transportation Fuels Fuel Cell Vehicle Fischer-Tropsch (F-T) Technology
0 CO(g) + 2H2(g) (CH2)n(l) + H2O(g) ΔH = -165kJ/mol
The water produced combines with CO in the water-gas shift reaction to form H2 and CO2
0 CO(g) + H2O(g) (CO2)(g) + H2(g) ΔH = - 41.2kJ/mol
The overall F-T reaction is therefore described as follows:
0 2CO(g) + H2(g)(-CH2-)n(l) + CO2(g) ΔH = -206 kJ/mol
Another approach to liquid fuels via synthesis gas is methanol production.
CO(g) + 2H2(g) CH3OH(l)
Methanol can be used directly or converted into gasoline through a process such as the Mobil process using zeolite catalysts.
*With Fe-based Catalysis Anderson Schultz Flory Distribution Indirect Conversion
The liquid products from indirect conversion process are zero sulfur, near zero aromatic hydrocarbons. Minimal refining needed to produce ultra-clean diesel or jet fuel. Carbon dioxide produced during indirect conversion can be captured for subsequent storage. Indirect conversion plants can co-produce electric power to improve process economics. If hydrogen is the preferred fuel in the future, these plants may be easily reconfigured to produce fuel cell grade hydrogen SASOL in South Africa has two large, indirect coal conversion facilities (SASOL II and III) that currently produce about 150,000 BPD of liquid fuels. Indirect Conversion
Advantages Disadvantages
Ultra-clean products Conceptually more Well suited for CO2 capture complex than direct conversion Well suited for electric power co-production Less efficient fuel production than direct May have lower operating expenses than Produces low-octane direct conversion gasoline Fewer BTUs per gallon than direct conversion products Comparison of Typical Direct and Indirect Liquefaction Final Product Slate Direct Indirect
Distillable product mix 65% diesel 80% diesel 35% naphtha 20% naphtha
Diesel cetane 42-47 70-75
Diesel sulfur <5 ppm <1 ppm
Diesel aromatics 4.8% <4%
Diesel specific gravity 0.865 0.780
Naphtha octane (RON) >100 45-75
Naphtha sulfur <0.5 ppm Nil
Naphtha aromatics 5% 2%
Naphtha specific gravity 0.764 0.673 Hybrid Conversion
A hybrid conversion facility is basically a direct and indirect conversion facility built next to one another. The products of the direct and indirect conversion trains complement each other and can be blended to produce high quality diesel and gasoline. Headwaters Technology Innovation has conducted a feasibility study for a 60,000 bbl/d hybrid plant to be built in the Philippines by private and government entities. Hybrid Coal Conversion Concept
Indirect Raw ICL Products Coal conversion Gasification (Fischer-Tropsch)
CO2 FT Tail Gas
Water/gas Shift Product Hydrogen H2 Refining & Final Recovery Blending Products
H2
Coal Direct Coal conversion Raw DCL Products Plants Under Consideration in the United States
Key Planning
Engineering Summary of CTL Projects in United States
State Developers Coal Type Capacity (bpd) Status
AZ Hopi Tribe, Headwaters Bituminous 10,000 – 50,000 Planning
MT DKRW Energy (Roundup, MT) Sub-bituminous/lignite 22,000 Planning
MT State of Montana Sub-bituminous/lignite 10,000 – 150,000 Planning
ND Headwaters, GRE, NACC, Falkirk Lignite 40,000 Planning
OH Rentech, Baard Energy Bituminous 2 plants, 35,000 each Planning
WY DKRW Energy (Medicine Bow, WY) Bituminous 11,000 Planning
WY Rentech Sub-bituminous 10,000 – 50,000 Planning
IL Rentech, (East Dubuque, IL)* Bituminous 2,000 Engineering Unidentified IL Bituminous 50,000 Planning Alexander County (Cairo, IL)
IL American Clean Coal Fuels Bituminous 25,000 Planning
PA WMPI Anthracite 5,000 Planning
WV AEP Mountaineer Bituminous 10,000 Planning
WV Mingo County Bituminous 10,000 Planning
MS Rentech Coal/petcoke 10,000 Planning
LA Synfuel Inc. Lignite Not available Planning
* will also co-produce fertilizer. CTL Pilot Plants in the United States
State Owner Capacity (bpd) Status
Colorado Rentech 10 – 15 Operational in 2007
Headwaters New Jersey Up to 30 Operational Incorporated
Oklahoma Syntroleum 70 Shutdown – 9/06
Oklahoma ConocoPhillips 300 – 400 Shutdown Existing and Potential CTL Projects
Ref: from Headwaters Inc. J.N. Ward Senate Briefing 1-19-07 Summary of CTL World-Wide Country Owner/Developer Capacity (bpd) Status
South Africa Sasol 150,000 Operational
South Africa Sasol 80,000 Planning
China Shenhua 20,000 (initially) Construction – Operational in 2007
China Lu’an Group ~3,000 to 4,000 Construction
China Yankuang 40,000 (initially) 180,000 planned Construction
China Sasol JV (2 studies) 80,000 (each plant) Planning
China Shell/Shenhua 70,000 – 80,000 Planning
China Headwaters/UK Race Investment Two 700-bpd demo plants Planning
China Siemens -- Planning
India Oil India Ltd Pilot plant Operational & 2nd Planned
Indonesia Pertamina/Accelon ~76,000 Construction
Australia Anglo American/Shell 60,000 Planning
Philippines Headwaters 50,000 Planning
New Zealand L&M Group 50,000 Planning Coal to Liquids Developments
Coal to Liquids
China CTL plants move ahead • China’s Shenhua and Ningxia CTL Cheap feedstock: ~$5/bbl plants could cost between $5B to $7B, up from $6B, and consume Labor and other direct cost: 15MM to 19MM tpy of coal. ~$15/bbl • Sasol in talks with two US firms and is US CTL plant activity somewhat busy improving its processes to offset stalled rising costs Developers seeking financing • DKRW is seeking financing for its Reduce capex/opex $2.75B Medicine Bow, WY plant Optimum logistics between cheap using GE gasifier and Rentech FT low-rank feedstocks and markets reactor Sasol estimates CTL plant ranges • US CTL plant costs from $1.2 billion from $60Kb/d to $80K/b/d for 50K-b/d to $3 billion with MT small plant at and 80K-b/d plant, respectively $1.5B up to $8B for larger plants.
www.SYNGASRefiner.com Zeus Development Corp
Source - Cornitius, 2006, “The Impacts of Synfuels on World Petroleum Supply”, presented at 2006 EIA Energy Outlook and Modeling Conference. DOE CTL Research Activities ICRC – ($5M): Produce gallon/barrel quantities of FT liquids from coal-derived syngas with Cobalt-based catalysts to be further processed into No. 2 diesel for small-scale testing as ultra-clean transportation fuel, evaluated as fuel for specialized vehicles for the military, and tested as feed to a reformer to produce hydrogen. Status: Negotiating with two partners to produce lab and large scale quantities of FT liquids from "live" coal-derived synthesis gas.
Lab Scale CSTR
Nikiski AK FT Plant DOE CTL Research Activities
Headwaters Technology Innovation Group (HTIG) – ($4.2M): Produce barrel quantities of coal-derived liquids using Iron-based FT synthesis in PDU-scale reactor. Investigate primary and secondary wax/catalyst separation, hydrotreating and hydrocracking of neat FT liquid products, and hydrogen yield from product reforming. Status: PDU planned at the Gas Technology Institute’s (GTI) facility in Des Plaines, IL. PDU fabrication and operation proposed to be done by HTIG. HTIG will utilize their hydocracking facility to upgrade raw FT wax products. WMPI-Gilberton (DOE CCPI Project)
Gasify anthracite waste (4,700 tons/day) to produce syngas using high pressure oxygen-blown gasifiers.
Co-produce electric power (41MW) and steam together with 5,000 barrels per day of synthetic hydrocarbon liquid fuels via FT synthesis.
A Shell gasifier and RectisolTM process removes contaminants from the plant’s effluent and concentrates CO2 for sequestration.
Benefits- If successful, technology may be applied throughout the U.S. enabling reclamation of coal wastes into high- Shell SCGP Gasifier cetane diesel fuel. Hydrogen from Coal Research
Coal can also serve as a source for pure hydrogen fuel
Liquid production with subsequent reforming Ethanol (higher alcohols)
2CO + H2 = H3CH2COH + H2O
Direct separation Advanced membrane systems Hydrogen “filter” Water Gas Shift (WGS) Membrance reactors LSU/Clemson/ORNL/ConocoPhillips
Catalytic process for the synthesis of ethanol from coal-derived syngas Current yields – 5% Target yield – 45% (95% selectivity, 3 year life)
surfactant RCuRhh shell core shell
Steam/O2 heat
Catalyst FFeCoe shell core
Coal intentionalintentional gaps “gaps” in in shell shell to to 23.2-5 nm nm provideprovide Rh Co--FeCu interfaces interfaces
C2H5OH CoreFigure 4-shell. Core-shellnanostructured nanostructured catalystscatalysts particles: Fe core-Rh shell particles: Fe core-Rh shell. Gas Separation from Shifted Syngas (Conventional Technology)
H CO2 2 • Low Pressure •Cryogenics Chemical Solvents (Large-Scale, (MEA, DEA) High Cost) • High Pressure Converted • Pressure Swing Syngas: Absorption Physical Solvents (Dimethylether of (Limited to Modest Polyethylene Glycol, H2 Temperatures) Methanol) H20 • Membrane Systems (Chemical Damage • Hybrid Solvents CO2 Purisol, Sulfinol from H2S, Limited Temp. Tolerance) Gas Separation from Shifted Syngas (Advanced Applications)
H2 CO2 •Advanced •Advanced Membrane Membrane Systems Systems Converted Organic/Inorganic (High and Low Syngas: Proton & Mixed Temp) Conducting •Low Temperature H Porous/Dense Hydrate 2 Formation H20 Homogeneous/ Processes Asymmetric CO2 Membrane-Based Hydrogen Separation
Micro Porous Dense Metallic
Desired flux ~ 300 ft3/ft2-hr at 100 psi Dense Ceramic delta P Research Topics Membrane materials and fabrication with Optimum diffusivity, flux, resistance, tolerance to impurities, temperature, 99.99% pressure. purity and Large-scale production, cost. Defect control and management cost Fundamental knowledge base 2 Mass transport, selectivity, kinetics <$100/ft Membrane reactors Seals, synergy versus challenges Water-Gas-Shift Membrane Reactor Concept
- WGS Reaction: CO + H2O CO2 + H2 Pure - High-T operation for favorable kinetics Hydrogen - Membrane removes H2 to “shift” unfavorable equilibrium to produce more H2.
Synthesis Gas... High Pressure CO (H2, CO2, CO, Pressure CO2 plus H2O) (Ready for Sequestration) Hydrogen Separation Membrane Projects
EltronEltronResearch,Research, Inc Inc Scale up H2 separation ceramic NETL Intramural R&D Scale up H2 separation ceramic membranemembrane for for FutureGen FutureGen and and choose choose Using high pressure hydrogen test membranemembrane system system configuration configuration.. facility to verify contractor results. SelectivitySelectivity = = 99.999%+ 99.999%+ Tested Eltron membrane at 400° C DemonstratedDemonstrated 1000 1000psipsideltadelta P, P, 270 270 for ~ 30 hrs. psipsipermeatepermeate pressure pressure 1111 months months continuous continuous operation operation in in simulatedsimulatedsyngassyngas Demonstrated large-scale wafer flux of Demonstrated3 2 large-scale wafero flux of 100100 ft ft3/hr/ft/hr/ft2 atat 100 100psipsiatat 420 420oC.C. BegunBegun design design and and construction construction of of 1.3 1.3 #/day H2 separation facility to obtain #/day H2 separation facility to obtain engineeringengineering data. data.
Cross-section of an electro-deposited alloy catalyst film on a metal membrane at Eltron Research Hydrogen Separation Membrane Projects
Gas Technology Institute ArgonneArgonne National National Lab Lab .Develop dense cermet membrane. . Develop novel reactor using dual- .Develop dense cermet membrane. phase non-porous membranes. ..MicrostructuralMicrostructuralevaluationevaluation of of series series 3e3e membrane membrane after after exposure exposure to to . Constructed HTHP test unit. simulatedsimulated coal coal gas gas revealed revealed . Fabricated two membrane types seriousserious deterioration deterioration after after 1100 1100 hours. . One type had selectivity ~2000 hours. for H S over CO2. ANL membrane 2 fabrication . Another type showed CO2 flux up to 0.02 ccSTP/cm2/min with Southwest Research Institute selectivity over He. Southwest Research Institute GTI supported ..DevelopDevelop thin thin dense dense self self-supported-supported membrane tube PdPd-Cu-Cu alloy alloy membrane. membrane. Oak Ridge National Lab 2 ..FormationFormation of of 110 110 in in2 membranesmembranes . Develop ceramic porous << 5 5 micrometers micrometers thick. thick. membrane. 3 2 . .Best H2 flux 242 ft3 /hr/ft2 at 20 psi Demonstrated fabrication for 1 .Best H2o flux 242 ft /hr/ft at 20 psi atat 400 400oC.C. meter tubes. SWRI . Completed single-gas tests membrane showing potential for high selectivity. WGS Reactor/Hydrogen Separation Membrane Projects
Media & Process Technology . Construct commercially-ready AspenAspen Products Products Group Group membrane reactor for CO2 •Develop•Develop a a robust robust WGS WGS membrane membrane reactor using contaminant-tolerant, capture with low parasitic energy. reactor using contaminant-tolerant, . Achieved complete conversion of highlyhighly active active WGS WGS catalyst catalyst and and Pd/Cu coated Ta membrane. CO and concentration of CO2 in Pd/Cu coated Ta membrane. single-stage WGS-MR at low •Demonstrated•Demonstrated that that a a low low-cost-cost nanosized WGS catalyst is active shift-T and stoichiometric nanosized WGS catalyst is active steam/CO ratio. andand stable stable in in 300 300-500C-500C range. range. •Fabricated•Fabricated 26 26 tubular tubular membranes membranes . Superior performance and costs withwith different different catalyst catalyst coatings coatings and and relative to program goals. layerlayer thicknesses thicknesses •Demonstrated•Demonstrated high high H H2permeabilitypermeability in presence of H S and2 water. in presence of H22S and water. WGS Reactor/Hydrogen Separation Membrane Projects
United Technologies, Corp. University of Wyoming/WRI . Identify Pd-Cu tri-metallic alloy . Develop an improved monolithic membranes with high stability and WGS catalyst and a vanadium hydrogen permeation: synthesize alloy hydrogen separation S and Cl tolerant WGS catalyst. membrane. . Two materials selected for further study with dopants G5 and J6, respectively. . Thermodynamic solubility predictions selected composition range of 1.0 to 1.5 % for the G5 alloy. Permeation projected to exceed B2 bcc Pd-Cu. . Nine candidate WGS catalysts were prepared and analyzed; six were selected for testing. FT Fuels - Domestic Fleet Tests
Fleet test in Washington D.C Fleet test in Denali National in September 2004. Park summer 2004.
Natural Gas Derived FT Fuels
Synthesis gas-derived clean fuels. Air Force Approach
Conduct demonstration on B-52/TF33 ground/flight
Define next steps for systematic approach to certification of new fuels Rationale for B-52 Testing
Decision to use B-52 for demo supported by: Safety 8 Engines Ability to isolate test fuel and feed only 2 engines TF33 non-afterburning, less complex, subsonic flight envelope
Aircraft Available Target aircraft selected to retire (no impact to test or operational fleet)
Successful Demonstrations: Two engine test - 9/2006 Eight engine test with mixed jet fuel/FT fuel – 12/2006 Request for Information Synthetic Fuel
DESC Request for Information (RFI) Issued May 30, 2006 Closed August 10, 2006 (initially set for July 31, 2006) Responses received – 28 total (22 interested in production)
Objectives RFI PART I: Short-Term Objective (through 2011) Identify responsible potential sources of synthetic fuel meeting the Fischer-Tropsch DRAFT specification Determine feasibility of 200M USG requirement 100M USG Air Force 100M USG Navy RFI PART II: Long-Term Objective (past 2011) Investigate long-term prospects for the manufacture and supply of aviation synthetic fuels on a larger scale Aviation Alternative Fuels Roadmap Aviation Alternative Fuels Roadmap The commercial sector and government must work together to promote/embrace alternative fuels to secure supply availability, to minimize price volatility, to improve operational and to explore the potential to reduce environmental impact. ….. Adopted 5/24/06 by AIA/ATA/FAA sponsored workshop with DOE, DoD and NASA stakeholders Follow-up meeting Oct 23-24, 2006 to further define Roadmap Profile of a Coal-to-Liquids (CTL) Plant Capacity: 40,000 bpd (13.2 million bpy) LPG: 2,700 bpd (7%) Naphtha: 12,100 bpd (30%) Diesel: 25,200 bpd (63%) Capital cost: $3.6 billion Annual revenue: $1 billion Coal consumption: 8.6 million tpy Production cost with 0% IRR: $44/bbl fuel ($35/bbl crude oil equivalent) Production cost with 15% IRR: $60/bbl fuel ($48/bbl crude oil equivalent) CTL plant employment: 250 people Land area: 480 acres Make-up Water: 25,000 gpm (36,000 acre-feet per year)
CO2 recovery: 8,000 to 25,000 tpd (depending on level of recovery) Ref: Headwaters Inc. J.N. Ward Senate Briefing 1-19-07 CTL Projected Cost
Crude Oil Total Sequester RSP Power Equivalent Capital Capital Cost Total Coal Cost Capital/ RSP O&M/ RSP Coal/ Credit $/DB ($10 Configuration Plant Size Cost MM$ $/DB Input (TPD) $/DB DB DB DB $35.6/MWh Total $/DB Premium)
Capture Ready 20000 BPD 1772 80,500 10,772 NA 32 13 19 -2 62 52 w/Sequestration 20000 BPD 1772 80,500 10,772 4 32 13 19 -2 66 56
Capture Ready 50000 BPD 3737 67,900 26,930 NA 27 14 19 -3 57 47 w/Sequestration 50000 BPD 3737 67,900 26,930 4 27 14 19 -3 61 51
Deployment Strategy EIA WOP Costs & Benefits Reference Case Incentive – Guaranteed Price Floor $55/DB for 20,000 BPD plants Total Incentive Cost: ~$6 Billion $45/DB for 50,000 BPD plants Total Capital Investment : $49BB 9 20,000 BPD plants Incremental Employment: 125,000 9 50,000 BPD plants - Mining 10,000 3 bituminous, 3 sub-bituminous, 3 lignite - Construction 22,500 All plants w/90% carbon capture & - Plant Operation 7,200 - Indirect 85,350 sequestration 2005 $49.70 Construct 3 plants/year 2015 $43.00 Incremental Coal Production: 94MM TPY - start 2008 2030 $49.19 630,000 BPD production by 2025 - first production on line 2011 Barriers to Creation of a Significant U.S. Industry
Economic Risk World oil price volatility is the single greatest impeding the deployment of CTL facilities; petroleum industry capital drawn to higher profit producing crude oil E&P
Technical Uncertainty Although plant components have been operated at commercial scale, the efficient integration of advanced coal gasification with advanced F-T synthesis technologies poses significant risk
Needed Incremental Investment CTL facilities will require the use of large quantities of coal in Infrastructure driving a significant expansion of the U.S. coal mining industry; current railroads and railcars are inadequate to handle projected increases coal demand; additional barge capacity will likely be required; mine mouth plants coal-fuel plants will need pipeline connects
Ready Availability of Critical Multiple CTL plants built concurrently worldwide will create Materials, Resources and Skills competition for critical process equipment, engineering, labor skills and materials
Environmental Concerns As a carbon-rich fossil fuel, coal releases large quantities of carbon dioxide when converted into fuels and power which must be economically controlled A Path Forward…
Build and Operate a few Pioneer Plants Subsidize the completion of 3 to 5 front-end engineering design studies Facilitate “Early Commercial Learning Experience” Identify barriers to process improvement and cost reduction Develop a greater understanding of the issues surrounding carbon capture, transport, sequestration, monitoring and verification of permanent storage
Initiate a Program of Targeted Research Build a comprehensive R&D plan built on barriers derived from actual operation of pre-commercial sized plants
Investigate Financial Incentives Tax Credits (EPACT 2005 Section 1307) Loan Guarantees Guaranteed Price Floors
Formulate and test F-T fuels for early commercial markets DOD, Clean Cities, Northeast Home Heating Oil Reserve
Involve, Coordinate, and Exchange Information with Interested Foreign Governments Coal to Liquids Summary
Coal is a viable alternative feedstock for the production of liquid fuels and hydrogen Development of a U.S. CTL industry could help mitigate the risks of an energy crisis. Proactive development of a CTL industry can be accomplished by industry lead with government support due to high risks involved. CTL can capture carbon for sequestration Convincing demonstrations and multi-agency joint national implementation plan could be a first step. DOE well positioned to produce, test, and certify liquid fuels produced from coal. Benefits are measured in the billions of dollars. Visit Our Websites
Fossil Energy website: www.fe.doe.gov NETL website: www.netl.doe.gov