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Clean Domestic Power: U.S. Opportunities and
Considerations for Utilization of Fossil Fuel
Robert Romanosky
Advanced Research Technology Manager
National Energy Technology Laboratory
March 16, 2010
2
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
Energy Contributes to Quality of Life
Eritrea
Congo
Peru
Bulgaria
Mexico
UK
Bahrain
U.S.Qatar
GD
P p
er
Cap
ita
(US
$ / p
ers
on
/ y
r)
Annual Energy Consumption per Capita
(kgoe / person / yr)
China
India
South Africa
GDP vs. Energy Consumption
100
1,000
10,000
100,000
100 1,000 10,000 100,000
3
U.S. data from EIA, Annual Energy Outlook 2009, ARRA release ; world data from IEA,
World Energy Outlook 2008
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%
Renewables
14%
Nuclear
5%
Coal
29%
Gas
22%
Oil
30%
Fossil Energy Continues to Dominate Supply
United States
World
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
Renewables
13%
Nuclear
6%
Coal
26%
Gas
21%
Oil
34%
4
Challenge and Program Driver: Annual CO2 Emissions Extremely Large
Emissions 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
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)
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
5
Technological Carbon Management OptionsPathways for Reducing GHGs -CO2
Improve
Efficiency
Sequester
Carbon
• Renewables
• Nuclear
• Fuel Switching
• Demand Side
• Supply Side
• Enhance Natural
Sinks
• Capture & Store
Reduce Carbon
Intensity
All options needed to:
Affordably meet energy
demand
Address environmental
objectives
6
DOE Fossil Energy Coal RD&D Platform
RESEARCH & DEVELOPMENT
Core Coal and
Power Systems R&D
DOE – FE – NETL
TECHNOLOGY DEMONSTRATION
Clean Coal Power Initiative
Stimulus Activities
DOE – FE – NETL
FINANCIAL INCENTIVES
Tax Credits
Loan Guarantees
DOE – LGO – IRS
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
GoalsPrograms Approaches
• Post Combustion CO2
Capture
• Oxy-Fired
Combustion
• Chemical Looping
• UltraSupercritical
Combustion
• Materials & Modeling
• Process Integration
& Control
• Demonstration &
Deployment
Programs
7
Coal Based Power
A Portfolio of Alternate PathsFuel Cell Membranes
PETROCHEMICAL PLANT
Fuels
GASIFICATION O2water shift
selexol
IGCC
water shiftselexol
Air AIR BLOWN IGCC
CHEMICAL
LOOPING IGCC
Chemical O2
& Carbonate
looping
Carbonate looping
CFB USC CFB ADVANCED CFB
O2
AirO2 Oxygen Fired CFB
or PC
MEA
PC USC PC
CO2 Capture
CO2 Capture
CO2 Capture
CO2 Capture
CO2 Capture
CO2 Capture
COMBUSTION
HYBRID
COMBUSTION
GASIFICATION
CO2 Capture
8
Fossil Energy CO2 Capture Solutions
Time to Commercialization
Advanced physical solvents
Advanced chemical solvents
Ammonia
CO2 com-pression
Amine solvents
Physical solvents
Cryogenic oxygen
Chemical looping
OTM boiler
Biological processes
Ionic liquids
Metal organic frameworks
Enzymatic membranes
Co
st
Red
ucti
on
Ben
efi
t
PBI membranes
Solid sorbents
Membrane systems
ITMs
Biomass co-firing
Post-combustion (existing, new PC)
Pre-combustion (IGCC)
Oxycombustion (new PC)
CO2 compression (all)
202020152010
OTM – O2 Transport Membrane (PC)
ITM – O2 Ion Transport Membrane (PC or IGCC)
CO2 Capture Targets:
• 90% CO2 Capture
• <10% increase in COE (IGCC)
• <35% increase in COE (PC)
9
Pulverized Coal Oxy-combustion Technology Opportunities
95% O2
PC Boiler
(No SCR)
Steam
Bag
Filter
Wet
Limestone
FGDCO2
Ash
ID FansCoal
Cryogenic
ASU Recycle
Compressor
CO2
Compression
(15 – 2,200Psia)
Power
Coal + O2 CO2 + H2OCheap OxygenOxygen Membranes
Advanced MOCReduce CO2 Recycle
Handle High Sulfur
Oxyfuel BoilersCompact Boiler Designs
Advanced Materials
Advanced Burners
Co-SequestrationRemove FGD
Compression &
Purification
MOC – materials of construction, FGD – Flue Gas Desulfurization, SCR – Selective Catalytic Reduction
10
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
Current Scale: Computational modeling through 5 MWe Pilot-scale
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)
O2-FiredAir-Fired
Heat
Flux(Btu/hr-ft2)
Division Walls
Burners
OFA Ports
Waterwalls
O2-FiredAir-Fired
Heat
Flux(Btu/hr-ft2)
Division Walls
Burners
OFA Ports
Waterwalls
Heat
Flux(Btu/hr-ft2)
Division Walls
Burners
OFA Ports
Waterwalls
Ultra-supercritical Oxyboilers
Fireside
Wall side
Water-wall tube heat transfer
Oxygen Membranes
Boiler size
reduced by >30%
AirCH4, CO, H2
CO2, H2O
''
O
'
O
2
2
P
PlnFlux
1000oC, 1832 F
3-5 psig~ 500 psig
O2-
e-
O2 + 4e- → 2O
2-
AirCH4, CO, H2
CO2, H2O
''
O
'
O
2
2
P
PlnFlux
1000oC, 1832 F
3-5 psig~ 500 psig
O2-
e-
O2 + 4e- → 2O
2-
Partners (11 projects): Praxair, Air Products, Jupiter, Alstom, B&W, Foster Wheeler, REI, SRI
11
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
Key Partners (2 projects): Alstom Power (Limestone Based), Ohio State (Metal Oxide)
Status
2010 Alstom Pilot test (1 MWe)
1000 lb/hr coal flow
1st Integrated operation
1st Autothermal Operation
Red1700F
Ox2000F
CaS
Air
Fuel CO2 + H2O
CaSO4
MB
HX N2 + O2
Steam
Fuel Reactor (Reducer)CaSO4 + 2C + Heat 2CO2 + CaS
CaSO4 + 4H2 + Heat 4H2O + CaS
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
12
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 materials1600150014001300120011001000900
40
42
44
46
48
Temperature (°F)
Pla
nt
Th
erm
al E
ffic
ien
cy (%
)
3500 psi
5500 psi
Birks and Ruth
13
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
14
Efficiency Contribution from Sensors and ControlsValue 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
500 MW net capacity unit
• 35 million kWh/yr added generation
• Approximately $2 million/yr in sales (@ 6 cents/kWh)
Entire coal-fired fleet
• More than 2 GW of additional power from existing fleet
COAL
35,700 MMBtu/yr
$70 million/yr
@$2/MMBtu
500 MW10,200 Btu/kWh
POWER
3.5 billion kWh/yr
@ 80% capacity
factor
Gaseous
Emissions
Solid Waste
Analysis based on 2008 coal costs
and 2008 coal-fired power plant fleet
(units greater than 300 MW)
15
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
Infrastructure
Characterization
Validation
Development
Regional Carbon Sequestration Partnerships
Global Collaborations
North America Energy Working Group
Carbon Sequestration Leadership Forum
International Demonstration Projects
Asia-Pacific Partnership (APP)
16
North American CO2 Storage Potential
(Billion Metric Tons)
Sink Type Low High
Saline Formations 3,300 12,600
Unmineable Coal Seams 160 180
Oil & Gas Fields 140 140
Available for download at http://www.netl.doe.gov/publications/carbon_seq/refshelf.html
U.S. Emissions ~ 6 Billion Tons CO2/yr all sources
~ 2 Billion Tons CO2/yr coal-fired power plants
Hundreds of
Years
Storage
Potential
National Atlas Highlights - 2008
Saline Formations
Oil and Gas Fields Unmineable Coal Seams
Conservative
Resource
Assessment
17
Demonstration & Deployment Programs
• Clean Coal Power Initiative
(CCPI)
• Industrial Carbon Capture
& Sequestration (ICCS)
• FutureGen
Reduce risk and promote adoption of new
technology at large scales
18
PPII & CCPI Demonstration ProjectsLocations & Cost Share
Emission Control
Fuel
Advanced Power
Systems
Excelsior EnergyMesaba Energy Project
$2.16B – Total$36M – DOE
Wisconsin ElectricTOXECON 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
CONSOLGreenidge Multi-pollutant Control
$32.7M – Total$14.3M – DOE
Southern CompanyIGCC-Transport Gasifier
$2B – Total$294M – DOE
Basin ElectricPostcombustion CO2 Capture
$287M – Total$100M – DOE
HECACommercial Demo of Advanced
IGCC w/ Full Carbon Capture~$2.8B – Total$308M – DOE
Awarded
In Negotiation
Complete
Great River EnergyLignite Fuel Enhancement
$31.5M – Total$13.5M – DOE
AEPPost Combustion CO2 Capture
$668M – Total$334M – DOE
Southern Company ServicesPost-combustion CO2 Capture
$668M – Total$295M – DOE
Summit TX Clean EnergyCommercial Demo of Advanced
IGCC w/ Full Carbon Capture~$1.9B – Total$350M – DOE
Project Locations for ICCS Area 1Carbon 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 TechnologyUniv. of Utah; Ammonia &
Cement; EOR & Saline, Dehydration,
Coffeyville, KS
Wolverine, CFB Power; EOR, Hitachi Amine,
Rogers City, MI
19
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
20
FutureGen
Gasification with Cleanup Separation System
Integration
CarbonSequestration
Optimized Turbines
Fuel Cells
H2 Production
FutureGenPotential “Proving Ground” for Emerging Technology
21
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
22
NETLwww.netl.doe.gov
Contact Information
Office of Fossil Energywww.fe.doe.gov
Robert R. Romanosky
304-285-4721
Robert.romanosky@netl.doe.gov
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