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Copyright 2010 General Electric CompanyOctober 2010, UTSR
GE Perspectives – Advanced IGCC/Hydrogen Gas Turbine Development
Reed AndersonSenior Program ManagerTechnology External Programs
1. This material is based upon work supported by the Department of Energy under Award Number DE-FC26-05NT42643
2. 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.
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Copyright 2010 General Electric CompanyOctober 2010, UTSR
0 500 1000 1500 2000 2500
GTSC (FA)
New CoalIGCC or PC
Existing CoalU.S. Average
CO2 Emission Rate (lbs/MW-hr)
Coal
Natural Gas
Thermal EfficiencyIndicated (xx%)CC = Carbon Capture %
eff = 40%
eff =45%
IGCC with CCSCC% 90%
GTCC (FA)
65% 50%
References: DOE NETL; EIA; IEA and GE Energy Internal Data
eff = 33%
IGCC with CCS – Part of the Solution for the Carbon Constrained World
So What’s the Hold Up?
Impact on Emissions Technology Available
2 GE 7F Syngas Units Shipped in 2010 toDuke Edwardsport for Operation in 2012
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Copyright 2010 General Electric CompanyOctober 2010, UTSR
500
550
600
650
0% 20% 40% 60% 80% 100%
CO2 Capture %
Out
put,
MW
GEEPRI
Current Barriers – Cost & Policy• With existing technology, adding
CCS to an IGCC plant increases COE beyond what most markets are currently willing to pay.
• Uncertainty with respect to indemnity, etc. on CO2 storage
• Technology Improvements and Legislative Action on CO2 Needed
– Carbon Pricing– Storage Clarity– More efficiency & output to lower
$/kW
29%
31%
33%
35%
37%
39%
0% 20% 40% 60% 80% 100%
CO2 Capture %
HH
V Ef
ficie
ncy,
%
GEEPRI
Sources: GE Internal Study, 2007 and EPRI IGCC Design Considerations for CO2 Capture: Engineering and Economic Assessment of IGCC Coal Power Plants for near-term Deployment, 2008
Impact of CCS on Output
Impact of CCS on Efficiency
As Engineers & Scientists We Can Be A Key Part of the Solution
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Copyright 2010 General Electric CompanyOctober 2010, UTSR
Gas Turbine Technology Advancements – High Leverage, High Impact on IGCC Plant
• More efficient GT’s use less fuel, require smaller, less costly gasification systems
• Advanced GT’s could enable improved ST operation
• Advanced combustion systems requiring less diluent for NOx control enables increased efficiency levels and improved plant integration flexibility
Technology advancements in the gas turbine propagate
through the rest of the plant:
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DOE Advanced H2/IGCC GT ProgramDOE goalsPerformance:
• +2 to 3 % pts efficiency by 2010• +3 to 5 % pts efficiency (total) by 2015
Emissions:• 2 ppm NOx by 2015• Fuel flexibility – Syngas & H2
Cost:• Contribute to IGCC capital cost reduction
‘06 ‘07 ‘08 ‘09 ‘10 ‘11 ‘12 2013 - TBD‘05
Phase IConceptual
Phase IIComponent Validation & Development
Phase III(Not currently awarded)
Final Design & Field Validation
Program timeline
Key Technologies
• Combustion
• Turbine • Materials • Systems
emiss
ions
effic
ienc
you
tput
cost
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Copyright 2010 General Electric CompanyOctober 2010, UTSR
Systems Analysis and Performance Validation
• Translate Goals in to Key Plant Level, CC Level, and GT Level Parameters• Create Baseline Performance Models & Understand Gaps/Sensitivities• Quantify Benefits of Turbine Technology Improvements• Recommend Turbine Technology Design Path• Re-evaluate and Adjust Plan If Needed As Results of R&D Are Obtained
Requirements Flow-Down
IGCC Plant Level
Combined Cycle Level
Gas/Steam Turbine Level
Capability Flow-Up
GA
SIFIERG
ASIFIER
RG
CR
GC
CG
CC
GC
SCR
UB
BER
SCR
UB
BER
CO
2 SHIFT
CO
2 SHIFT
SYNG
AS H
T
FW H
EATER
SYNG
AS H
T
FW H
EATER
AC
ID G
AS
Absorber
AC
ID G
AS
Absorber
AC
ID G
AS
Rem
ovalA
CID
GA
SR
emoval
CO2Sulfur
Air SeparationUnit
Gas Turbine Generator
Gas Turbine Generator
Steam Turbine Generator
HRSG
HRSG
BALANCE OF PLANT AUXILIARIES (COAL PREP, COOLING SYSTEM, UTILITIES)
Air Extraction
COAL
COAL
O2
O2
Water
Water
Air
RawSyngas
RawSyngas
Clean
Syngas
SLAG
SLAG
EXH
EXH
STEAM
STEAM
PROCESS
STEAM
N2
Syngas Fuel
O2
GA
SIFIERG
ASIFIER
RG
CR
GC
CG
CC
GC
SCR
UB
BER
SCR
UB
BER
CO
2 SHIFT
CO
2 SHIFT
SYNG
AS H
T
FW H
EATER
SYNG
AS H
T
FW H
EATER
AC
ID G
AS
Absorber
AC
ID G
AS
Absorber
AC
ID G
AS
Rem
ovalA
CID
GA
SR
emoval
CO2Sulfur
Air SeparationUnit
Gas Turbine Generator
Gas Turbine Generator
Steam Turbine Generator
HRSG
HRSG
BALANCE OF PLANT AUXILIARIES (COAL PREP, COOLING SYSTEM, UTILITIES)
Air Extraction
COAL
COAL
O2
O2
Water
Water
Air
RawSyngas
RawSyngas
Clean
Syngas
SLAG
SLAG
EXH
EXH
STEAM
STEAM
PROCESS
STEAM
N2
Syngas Fuel
O2
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Copyright 2010 General Electric CompanyOctober 2010, UTSR
Estimated Project Benefits: Current Status
• Line of Sight to Program Efficiency Goal (+ 3 to 5 pts)
• NOx emissions of 2ppm
• CO2 emissions reductionconsistent with 90%Carbon Capture and Storage (CCS) Level
• CCS Cost Penalty Neutralized ($/kW basis)
NOTES: Values assume use of Advanced Combustion System and SCR GT Technology
% C
hang
e in
Pla
nt C
ost
No CCS CCS
CCS Penalty
Program TechnologyImprovements
Base
2010
2015
Base CCS
2010 CCS
2015 CCS
GT Technology
% C
hang
e in
Pla
nt C
ost
No CCS CCS
CCS Penalty
Program TechnologyImprovements
Base
2010
2015
Base CCS
2010 CCS
2015 CCS
Efficiency
Cost
GT Technology
Plan
t Effi
cien
cy H
HV
No CCS CCS
CCS Penalty
Program TechnologyImprovements
base
2010
2015
Base CCS
2010 CCS
2015 CCS
GT Technology
Plan
t Effi
cien
cy H
HV
No CCS CCS
CCS Penalty
Program TechnologyImprovements
base
2010
2015
Base CCS
2010 CCS
2015 CCS
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NG H2
BaselineNozzle
ImprovedNozzle
NG H2
BaselineNozzle
ImprovedNozzle
Combustion Challenges
NOx
Flashback
Dynamics
Fuel Flexibility
Entitlement (perfectly premixed) NOx Data
0.75
2.75
4.75
6.75
Tflame (°F)
NO
x @
15%
O2 (
ppm
vd)
~~
2ppm
target range
NaturalGas 100%
H2
Syngas
C-Free SG+ N2
NaturalGas 100%
H2
Syngas
C-Free SG+ N2
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Copyright 2010 General Electric CompanyOctober 2010, UTSR
Combustion Development
• Simple & Combined Cycle
• Part load to Full Load
Gas TurbineFull Can Scale Nozzle Scale
• NG / Syngas / High H2
• Combustor Performance
• NG / Syngas / High H2
• Emissions, Dynamics, Lean Blow Out
• Modeling & Design
• Entitlement Data
• Concept Characteristics
• Fundamental Research
Technology Basics 2010 Focus
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Copyright 2010 General Electric CompanyOctober 2010, UTSR
TEXIT [°F]
NO
x @
15%
O2 [
ppm
vd]
Entitlement - High N2 in Fuel
Single Nozzle - High N2 in Fuel
Full Can - Low N2 in Fuel
Full Can - High N2 in Fuel Target R
ange
• Extensive Modeling & Testing at Component Scale
• Best Concepts Carried Forward for Full Can Multi Nozzle Testing
• Single digit NOx emissions at F-Class + temperatures and pressures
• Promising operability and dynamics on hydrogen, natural gas, and syngas
• 60+ hours operation, multiple 6-hour blocks at full load
• Next Steps• Further optimize, scale up, and address
manufacturability, reliability, durability, etc.
Combustion Development Status
Full Can Testing
NOx Emissions vs. Temperature
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Turbine System Goals
Increasing firing temp and output– Enable advanced materials &
coating in IGCC/H2 environment– Increased mass flow
Advanced turbine technology– Reduced cooling flows– Reduced leakage/purge flows– Advanced aerodynamics for improved
turbine efficiency
Aero
MechHT
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Turbine Aero & Heat Transfer Development
Cooling Flow Reduction:• Develop & validate advanced cooling schemes
Leakage & Purge Flow Reduction:• Develop & validate improved seal designs
• Optimize flow geometries to minimize hot gas ingestion
Aerodynamics:
• Improve CFD accuracy & validate turbine aero efficiency improvements provided by new technology
Aero Rig Test Parts
Advanced Film Cooling Hole Shapes
AdvancedDiffuser Shaped
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Baseline Improved
Hybrid RotatingCascade Rig & CFD
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Location on Component
Film
Eff
ecti
vene
ss
New Design
Existing (Baseline) Design
Heat Transfer Development Status
Achieved target flow reductions for Round 1 Technologies• Airfoil film cooling• Transition Piece to Stage 1 Nozzle• High Pressure Packing• Angel Wing
Jugular experiments completed for Round 2 Cooling Technologies• Entitlement supports targeted improvement levels
Advanced Film Cooling
TP/S1N Seal
Effe
ctiv
e A
rea
OriginalImproved
Effe
ctiv
e A
rea
Original Improved
TP/S1N Seal
TP/S1N Seal Parts
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Aerodynamic Development Status
Turbine Aero Validation RigTest Setup & Results
Turb
ine
Effic
ienc
y
Turbine Exit Mach Number
IGCC
Prediction
Data
Natural Gas
Turb
ine
Effic
ienc
y
Turbine Exit Mach Number
IGCC
Prediction
Data
Natural Gas
• First round rig testing completed
• Turbine aerodynamics
• Diffuser aerodynamics
• Stable, repeatable performance, consistent with engine experience
• Results to date support projected performance improvement –preparing for next round of testing
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Copyright 2010 General Electric CompanyOctober 2010, UTSR
Advanced Materials (Coatings)Goals
• Enable higher temperature operation for increased efficiency and output
• Address unique conditions associated with IGCC environment, validate durability
Overall Approach• Characterize the environment and devise
representative laboratory tests• Benchmark degradation of baseline TBC’s
and Bond Coats• Develop new coatings • Downselect to best performers• Evaluate best performing TBC’s and BC’s
Challenges & Risks• Target conditions beyond current experience
Thermal Shock Test
Field Hardware Inspection
Optimized Coating
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Copyright 2010 General Electric CompanyOctober 2010, UTSR
• Reproduced damage modes seen on IGCC field hardware
• Many architectures evaluated over 2+ rounds of optimization
• Performance improvement demonstrated at targeted operating temperatures
• Down selections made to final TBCsand bond coats
Microstructural Evolution of TBCAfter Accelerated Isothermal Exposure
Baseline 8YSZ New TBC
Advanced Materials (Coatings) Status
50 μm
Cr-Ni-Co rich scale
Alumina particles
Ti rich needles
Cr-Ti rich particles
Chromium sulfides
Cr-Ti rich scale
50 μm50 μm50 μm
Cr-Ni-Co rich scale
Alumina particles
Ti rich needles
Cr-Ti rich particles
Chromium sulfides
Cr-Ti rich scale
50 μm
Cr-Ni-Co rich scale
Alumina particles
Ti rich needles
Cr-Ti rich particles
Chromium sulfides
Cr-Ti rich scale
50 μm50 μm50 μm
Cr-Ni-Co rich scale
Alumina particles
Ti rich needles
Cr-Ti rich particles
Chromium sulfides
Cr-Ti rich scale
Field Hardware Inspection Results
Resistance to Sulfidation
0
1
2
3
4
5
6
(baseline) A B C D E(Prime)
Modified CoNiCrAlY + X
Resi
stan
ce to
Sul
fidat
ion
Atta
ck
Sulfidation Resistance Test Results
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• Evaluate integrated system rig test data for down selected TBCs/BCs
• Generate design quality data
• Process optimization
Prelinimary Design Curves
Cycles for a given hot time
FCT Design Curves
Rig Test Setup
Spray DiagnosticsFor Improved
Coating Quality
Advanced Materials (Coatings) Next Steps
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Copyright 2010 General Electric CompanyOctober 2010, UTSR
Summary
• GE building on successful field operational experience for gas turbines in IGCC and high Hydrogen fuel applications
• GE offering IGCC product today, including carbon capture technologies
• GE working with DOE on gas turbine technology advances for future IGCC products with CCS.
•Higher efficiency, lower cost, lower emissions
• Technical Challenges Remain for Future Designs Universities play a critical role in the gas turbine technology R&D process
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Copyright 2010 General Electric CompanyOctober 2010, UTSR
AcknowledgementsGE would like to extend a special thanks to the US Department of Energy National Energy Technology Laboratory and the following individuals for their past and continued support on the DOE/GE High Hydrogen Program:
Rich Dennis
Turbine Technology ManagerOffice of Fossil EnergyUS DOENational Energy Technology Laboratory
Robin Ames
Project ManagerPower Systems DivisionU.S. Department of EnergyNational Energy Technology Laboratory