1. Clean Domestic Power: Opportunities and Considerations for Utilization of Fossil Fuel
Robert Romanosky
Advanced Research Technology Manager
National Energy Technology Laboratory
February 8-10, 2010

2. Energy Contributes to Quality of Life
GDP vs. Energy Consumption
Qatar
U.S. UK
Mexico
Bahrain
South Africa
Peru
(US$ / person / yr)
GDP per Capita
Congo
Bulgaria
China
Eritrea
India
Annual Energy Consumption per Capita
(kgoe / person / yr)
Development Data Group, The World Bank. 2008; Population Division of the Department of Economic and Social Affairs of the United Nations Secretariat: IEA Statistics Division

3. Fossil Energy Continues to Dominate Supply
Energy Demand 2006
100 QBtu / Year 85% Fossil Energy
Renewables 6%
Nuclear 8%
Coal
23%
Gas
22%
Oil
41%
465 QBtu / Year
81% Fossil Energy
13%
26%
21%
34%
Energy Demand 2030
675 QBtu / Year
81% Fossil Energy
111 QBtu / Year 78% Fossil Energy
+ 45%
+ 11%
Renewables
13%
Nuclear 8%
Coal
23%
Gas
22%
Oil
34%
14% 5%
29%
30%
United States
World
Fossil Energy Continues to Dominate Supply
U.S. data from EIA, Annual Energy Outlook 2009, ARRA release ; world data from IEA, World Energy Outlook 2008

4. Challenge and Program Driver: Annual CO2 Emissions Extremely Large
Total Release in the U.S., short tons per year
Mercury
120
Sulfur Dioxide (SO2)
15,000,000
Municipal Solid Waste
230,000,000
Carbon Dioxide (CO2)
6,300,000,000
1 million metric tons of CO2:
Every year would fill a volume of 32 million cubic feet
Close to the volume of the Empire State Building
Data sources: Mercury - EPA National Emissions Inventory (1999 data); SO2 - EPA air trends (2002 data); MSW - EPA OSWER fact sheet (2001 data); CO2 - EIA AEO 2004 (2002 data)

5. Technological Carbon Management Options Pathways for Reducing GHGs -CO2
Reduce Carbon
Intensity
Improve
Efficiency
Sequester
Carbon
Renewables
Nuclear
Fuel Switching
Demand Side
Supply Side
Enhance Natural Sinks
Capture & Store
All options needed to:
Affordably meet energy demand
Address environmental objectives

6. DOE Fossil Energy Coal RD&D Platform
Goals
Approaches
Programs
Technologies &
Best Practices
< 10% increase COE with CCS (pre-combustion)
< 35% increase COE with CCS (post- and oxy-combustion)
< $400/kW fuel cell systems (2002 $)
> 50% plant efficiency, up to 60% with fuel cells
> 90% CO2 capture
> 99% CO2 storage permanence
+/- 30% storage capacity resolution
RESEARCH & DEVELOPMENT
Core Coal and
Power Systems R&D
DOE – FE – NETL
Post Combustion CO2 Capture
Oxy-Fired Combustion
Chemical Looping
UltraSupercritical Combustion
Materials & Modeling
Process Integration & Control
Demonstration & Deployment Programs
TECHNOLOGY DEMONSTRATION
Clean Coal Power Initiative
Stimulus Activities
DOE – FE – NETL
FINANCIAL INCENTIVES
Tax Credits
Loan Guarantees
DOE – LGO – IRS

7. Coal Based Power A Portfolio of Alternate Paths
Fuel Cell
Membranes
PETROCHEMICAL
PLANT
Fuels
GASIFICATION O2
water shift
selexol
IGCC
Air
AIR BLOWN IGCC
CHEMICAL
LOOPING IGCC
Chemical O2
& Carbonate
looping
Carbonate looping
CFB
USC CFB
ADVANCED CFB
Oxygen Fired CFB
or PC
MEA PC
USC PC
CO2 Capture
COMBUSTION
HYBRID

8. Fossil Energy CO2 Capture Solutions
Post-combustion (existing, new PC)
Pre-combustion (IGCC)
Oxycombustion (new PC)
CO2 compression (all)
Chemical looping
OTM boiler
Biological processes
Ionic liquids
Metal organic frameworks
Enzymatic membranes
PBI membranes
Solid sorbents
Membrane systems
ITMs
Biomass co- firing
Advanced physical solvents
Advanced chemical solvents
Ammonia
CO2 com- pression
Cost Reduction Benefit
Amine solvents
Physical solvents
Cryogenic oxygen
CO2 Capture Targets:
90% CO2 Capture
<10% increase in COE (IGCC)
<35% increase in COE (PC)
2010
2015
2020
Time to Commercialization
OTM – O2 Transport Membrane (PC)
ITM – O2 Ion Transport Membrane (PC or IGCC)

9. Advanced PC Oxy-combustion
Challenges
Cryogenic ASUs are capital and energy intensive
Excess O2 and inerts (N2, Ar) h CO2 purification cost
Existing boiler air infiltration
Corrosion and process control
Ultra-supercritical Oxyboilers
Fireside
Wall side
Water-wall tube heat transfer
Boiler size reduced by >30%
Advanced Oxy-combustion R&D Focus
New oxyfuel boilers
Advanced materials and burners
Corrosion
Low-cost oxygen  O2 Membranes
Retrofit existing air boilers
Air leakage, heat transfer, corrosion
Process control
CO2 purification
Co-capture (CO2 + SOx, NOx, O2)
Oxygen Membranes
Current Scale: Computational modeling through 5 MWe Pilot-scale
Partners (11 projects): Praxair, Air Products, Jupiter, Alstom, B&W, Foster Wheeler, REI, SRI

10. Chemical Looping Combustion
Chemical Looping Advantages:
Oxy-combustion without an O2 plant
Potential lowest cost option for near-zero emission coal power plant <20% COE penalty
New and existing PC power plant designs
Key Challenges
Solids transport
Heat Integration
Air Reactor (Oxidizer)
CaS + 2O2  CaSO4 + Heat
Oxy-Firing without Oxygen Plant
Solid Oxygen Carrier circulates between Oxidizer and Reducer
Oxygen Carrier: Carries Oxygen, Heat and Fuel Energy
Carrier picks up O2 in the Oxidizer, leaves N2 behind
Carrier Burns the Fuel in the Reducer
Heat produces Steam for Power
Steam
Air
MBHX Ox
2000F
N2 + O2
CaS
CaSO4
Status
2010 Alstom Pilot test (1 MWe)
1000 lb/hr coal flow
1st Integrated operation
1st Autothermal Operation
Red
1700F
Fuel
CO2 + H2O
Fuel Reactor (Reducer)
CaSO4 + 2C + Heat  2CO2 + CaS
CaSO4 + 4H2 + Heat  4H2O + CaS
Key Partners (2 projects): Alstom Power (Limestone Based), Ohio State (Metal Oxide)

11. UltraSupercritical Boilers and Turbines
Current technology for USC Boilers
Typical subcritical = 540 °C
Typical supercritical = 593 °C
Most advanced supercritical = ~610 °C
USC Plant efficiency is improved to
45 to 47% HHV
Ultrasupercritical (USC) DOE goal for higher efficiency and much lower emissions, materials capable of:
760 °C (1400 °F)
5,000 psi
Oxygen firing
Meeting these targets requires:
The use of new materials
Novel uses of existing materials

12. Benefit of Higher Efficiency in Reducing CO2
(Bituminous coal, without CO2 capture)
20% reduction in CO2 corresponds with similar reductions (per MWh) in consumables including coal and limestone (reducing front-end equipment size), flue gas volume (reducing back-end and emission control equipment size), and overall emissions, water use, and waste generation
2 Percentage Point Efficiency Gain = 5% CO2 Reduction

13. Efficiency Contribution from Sensors and Controls Value Derived for an Existing Coal Fired Power Plant
1% HEAT RATE improvement
500 MW net capacity unit
$700,000/yr coal cost savings
1% reduction in gaseous and solid emissions
Entire coal-fired fleet
$300 million/yr coal cost savings
Reduction of 14.5 million metric tons CO2 per year
1% increase in AVAILABILITY
35 million kWh/yr added generation
Approximately $2 million/yr in sales 6 cents/kWh)
More than 2 GW of additional power from existing fleet
Analysis based on 2008 coal costs and 2008 coal-fired power plant fleet (units greater than 300 MW)

14. Carbon Sequestration Program Goals
Deliver technologies & best practices that provide Carbon Capture and Safe Storage (CCSS) with:
90% CO2 capture at source
99% storage permanence
< 10% increase in COE
Pre-combustion capture (IGCC)
< 35% increase in COE
Post-combustion & Oxy-combustion
Core R&D
Simulation and Risk Assessment
Pre-combustion Capture
Geologic Storage
Monitoring, Verification, and Accounting (MVA)
CO2 Use/Reuse
Global Collaborations
North America Energy Working Group
Carbon Sequestration Leadership Forum
International Demonstration Projects
Asia-Pacific Partnership (APP)
Infrastructure
Characterization
Validation
Development
Regional Carbon Sequestration Partnerships

15. National Atlas Highlights - 2008
U.S. Emissions ~ 6 Billion Tons CO2/yr all sources
~ 2 Billion Tons CO2/yr coal-fired power plants
Saline Formations
North American CO2 Storage Potential
(Billion Metric Tons)
Oil and Gas Fields
Unmineable Coal Seams
Sink Type
Low
High
Saline Formations
3,300
12,600
Unmineable Coal Seams
160
180
Oil & Gas Fields
140
Hundreds of Years Storage Potential
Conservative Resource Assessment
Available for download at

16. Demonstration & Deployment Programs
Reduce risk and promote adoption of new technology at large scales
Clean Coal Power Initiative (CCPI)
Industrial Carbon Capture & Sequestration (ICCS)
FutureGen

17. PPII & CCPI Demonstration Projects Locations & Cost Share
Project Locations for ICCS Area 1
Carbon Capture and Storage from Industrial Sources
Archer Daniels Midland; Industrial Power & Ethanol; Saline, DOW Alstom Amine, Decatur, IL
Air Products, H2 Production; EOR, BASF’s aMDEA
Port Arthur, TX;
Battelle, Boise White Paper Mill, Basalt,
Fluor Econamine Plus, Washington
C6 (Shell); H2 Production; Saline, ADIP-X Amine, Solano, CA
Conoco Phillips; IGGC- Petcoke; Depleted NG/EOR, Selexol, Sweeny, TX
Praxair; H2 for Refinery; EOR, VPSA,
Texas City, TX
Texas Energy; Petcoke Gasification (H2, MeOH & NH3); EOR, Rectisol,
Beaumont, TX
Cemex,; Cement; EOR & Saline,
RTI Dry Carbonate Odessa, TX
Leucadia Energy; SNG from petcoke; EOR, Rectisol, Mississippi
Leucadia Energy; Methanol; EOR, Rectisol,
Lake Charles, LA
Project Location
Industry Type / Product
Sequestration Type
CO2 Capture Technology
Univ. of Utah; Ammonia & Cement; EOR & Saline, Dehydration,
Coffeyville, KS
Wolverine, CFB Power; EOR, Hitachi Amine, Rogers City, MI
PPII & CCPI Demonstration Projects Locations & Cost Share
Emission Control
Fuel
Advanced Power Systems
Excelsior Energy
Mesaba Energy Project
$2.16B – Total
$36M – DOE
Wisconsin Electric
TOXECON Multi-pollutant Control
$53M – Total
$24.9M – DOE
NeuCo (Baldwin)
Integrated Optimization Software
$19M – Total
$8.6M – DOE
NeuCo (Limestone)
Mercury Specie &
Multi-pollutant Control
$15.6M – Total
$6.1M – DOE
CONSOL
Greenidge Multi-pollutant Control
$32.7M – Total
$14.3M – DOE
Southern Company
IGCC-Transport Gasifier
$2B – Total
$294M – DOE
Basin Electric
Postcombustion CO2 Capture
$287M – Total
$100M – DOE
HECA
Commercial Demo of Advanced
IGCC w/ Full Carbon Capture
~$2.8B – Total
$308M – DOE
Awarded
In Negotiation
Complete
Great River Energy
Lignite Fuel Enhancement
$31.5M – Total
$13.5M – DOE
AEP
Post Combustion CO2 Capture
$668M – Total
$334M – DOE
Southern Company Services
Post-combustion CO2 Capture
$295M – DOE
Summit TX Clean Energy
~$1.9B – Total
$350M – DOE 17

18. FutureGen Objectives
Establish technical, economic & environmental viability of “near- zero emission” coal-fueled plant by 2015
Validate DOE goals
(ref. Report to Congress, dated March 2004):
Sequester >90% CO2 with potential for ~100%
>99% sulfur removal; <0.05 lb/MMBtu Nox; <0.005 lb/MMBtu PM; >90% Hg removal
Prototype 275 MWe coal-based power plant of the future sized to:
Utilize utility-scale (7FB) gas turbine
Adequately stress saline geologic formation
Integrate full-scale CCS operations
Serve as potential test facility for emerging technologies

19. FutureGen Potential “Proving Ground” for Emerging Technology
Fuel Cells
Carbon
Sequestration
FutureGen
Gasification with Cleanup Separation
System
Integration
Optimized Turbines
H2 Production

20. Conclusions
The U.S. power generation industry is at a critical juncture
Demand, resources, workforce, reliability, regulation, grid integrity, transmission, etc.
Competing demands for reliable, low-cost energy and climate change mitigation appear incongruent
Uncertainty of regulatory outcomes and rising costs impact industry’s willingness to commit capital investment, endangering near-term production capacity
The U.S. must foster new processes that address conflicting energy objectives simultaneously
Our nation’s dependence on liquid fuel from foreign resources will continue to remain high for the near term

21. Office of Fossil Energy www.fe.doe.gov
Contact Information
Robert R. Romanosky
NETL
Office of Fossil Energy