12754064763.GENamtecPreCombustionCCSMay2010rev001Final

1 / AEIC2004.pptCopyright 2009 General Electric Company. All Rights Reserved. This material may not be copied or distributed in whole or in part, without

prior written permission of the copyright owner.

Opportunities in Carbon Capture & Storage.

Pre-Combustion & Carbon Capture:A Key Technology Solution for a Low Carbon Economy.

NAMTEC Conference - Harrogate UK

Terry RaddingsMay 25th 2010

Copyright 2009 General Electric Company. All Rights Reserved. This material may not be copied or distributed in whole or in part, without prior written permission of the copyright owner.



European Trends …

•Retirement of aging infrastructure

� 60% of hard coal plants >25 yr old

� 40% of thermal & nuclear >25 yr old

•Energy security a growing concern

� Reserve margins declining

� Coal & Nuclear renaissance

•Renewables transforming European power systems

•CO2 expected to be significant driver – Cluster Approach

•Smart Metering/Grids could drive consumer behaviour

Financial Crisis – Global

Not helpful but doesn’t mean

We should drop the ball !!




Fuels

Gas

Oil

Coal

Nuclear

Geothermal

Biomass

Hydro

Wind

Solar

Gas

Oil

Coal

Nuclear

Geothermal

Biomass

Hydro

Wind

Solar

Affordable, secure, reliable

flexible & environmentally responsible energy – with

multiple revenue streams

Delivery

Diverse Portfolio - But Not Just About Electricity !

Conversion

Efficiency

Reliability

Emissio

ns

Flexibility

Flexible, Affordable, Reliable & Environmentally Responsible



Increasing Demand for Fuel Gas Flexibility

Source: GE

Segment conditions

• Fuels of opportunity• Emission requirements• Climate change awareness

GE response

• Utilize 50+ years of experience in non-traditional fuels

• Extending low emissions technology

• Investing in technology for fuel flexibility0

10

20

30

40

50

60

70

80

90

100

110

0 5 10 15 20 25 30 35 40 45 50 55

Fuel Lower Heating Value, BTU/lb/1000

Mod Wobbe Index@

70F

CO

C5H12

C4H10

H2CH4

C3H8

C2H6

NG

0

10

20

30

40

50

60

70

80

90

100

110

0 5 10 15 20 25 30 35 40 45 50 55

Fuel Lower Heating Value, BTU/lb/1000

Mod Wobbe Index@

70F

CO

C5H12

C4H10

H2CH4

C3H8

C2H6

NGHigh H2

LNG Field (High C2)

Refinery

OffgasLNG Field(High Inert)

BFG/COG

O2 Blown Syngas

Air Blown Syngas

NG/LNG Wide Wobbe

Source: GE internal data



Coal power gen landscape – 2007-2016

Total CapacityAdditions (GW)

North America

30

China

472

RO Asia

77

India

94

29

West Europe

Middle East & Africa

25

East Europe & FSU

Sources: DOE-EIA,GEE PGV Forecast 11apr2006

17IGCC Drivers

• High/volatile natural gas prices – uncertainty of supply (LNG)

• Energy security/independence with large coal reserves

• Stringent environmental regulations: NOx, SO2, PM10, Hg , water consumption …

• Monetized value of emissions

• Potential of a carbon constrained world

10 Year Ave Annual

Cap Adds (GW) China 47RO Asia 8N. America 2India 9West EU 3MEA 2East EU 3Ltn America 0.9

744 Total



Sulfur

SulfurRemoval

Syngas

Slag

Gasifier

Oxygen

MarketableByproducts

• Combine Lignite with petcoke or hardcoal

• Reduce Industry dependency from Nat Gas

Mercury & Sulfur Removal

CO2 CaptureCombined Cycle Power Block – 209FB

Create integrated Refinery solutions- Hydrogen- Fischer Tropsch Liquids- Methanol- Carbon Monoxide- Higher Alcohols

IGCC possibilities – Bridging The Gap !

Build Nat Gas fired Combined Cycle as – ‘IGCC ready’

• Petroleum Coke• Asphalt• Heavy Oil• Vacuum Residue•Others

Substitute Natural Gas• SNG

Gasification Solutions – Multiple Revenue Streams




Integrated Gasification Combined Cycle

AirSeparationSystem

GasificationSyngas Cooling

Syngas Clean-

up

Combined Cycle System

Coal

Slag

Air Air/N2

CO2

Sulfur

Hg

Cleaned FuelHeat

Electricity

O2

Five Basic Process Steps – all commercial proven



GE’s Gasifier Configurations

Quench• Hot syngas immediately quenched by direct water contact

• Syngas is warm and saturated with water… ideal for sour CO shift

• 12 to 86 barg commercial application

• Lower capital cost than RSC

• Shorter construction cycles than RSC

• Proven gasifier sizes up to nominal 900ft3

• Typical applications: chemicals, hydrogen, refinery polygen

• Hot syngas first cooled by radiant cooling before quenching

• Generates high pressure steam to ~135 barg

• Gasifier pressures to ~45barg

• Better efficiency than Quench

• Construction cycle more complex than Quench

• Proven up to nominal 1800ft3

• Typical applications: power generation, refinery polygen

Gasi

fier

Cham

ber

Radia

nt co

ole

r fo

r heat re

covery

Gasi

fier

Cham

ber

Quench

Quench

RSC

Images not to scale



Launch units shipping in 2010

7F & 9F Syngas turbine

• Performance:

– Simple cycle: 7F - *232MWe, 9F – *310MWe

– 207F Syngas: *680MW

– 209F Syngas: *920MW

• Key features:

– Air extraction available to support to process island and plant operations

– Ability to operate on syngas as a high H2 fuel

– Combustion system with extensive field validation

– Increased mass flow for higher output

– Proven syngas hot gas path materials

– Natural gas and co-fire operation available

* Variable depending on project specifics



9F Syngas Features

Axial

Exhaust

Leveraging >1000 “F Class” Gas Turbine Fleet >32M Fired Hours Experience

197 x 9FA Units in Service >8M hours

Enhanced Increased Area S1N

Mark VIeControl System

Mark VIeControl System

Cold End

Drive

FA Compressor Blading with FA+e AeroFA Compressor & Turbine

9FA+e HGP

Nat Gas Fired CCGT in 1st Phase but key components IGCC Ready

•HRSG – Built for process integration•Generators - Built for IGCC duty •Steam turbine – Built for IGCC operating envelope

= Main DifferenceCombustion System: Proven IGCC MNQC



GE Syngas Experience by Application

Type COD MW

Power

Block Application Integration Gasifier Fuel

Coal IGCC ExperienceIGCC 1984 120 107E Power Steam GE Coal

IGCC 1996 350 209E Cogen Steam ZVU Coal

IGCC 1996 70 6B Cogen/ MeOH Steam GSP Coal

IGCC 1996 250 107FA Power Steam E-Gas Pet Coke

IGCC 1996 250 107FA Power Steam/N2 GE Coal-Pet Coke

Refinery IGCC Experience

Refinery 1996 40 6B Cogen Steam/Air/N2 GE Pet Coke

Refinery 1997 120 206B Cogen/H2 Steam Shell/Lurgi Oil

Refinery 2000 550 3x109E Cogen Steam GE Visbreaker Tar

Refinery 2000 180 2-6FA Cogen Steam/N2 GE Pet Coke

Refinery 2000 173 2-6FA Cogen None GE Oil

Refinery 2009 160 2-7EA Cogen Steam Shell Asphaltene

Refinery 2009 253 2-9E Cogen N2 Shell Oil

Steel Experience

Steel 1996 520 3x109E Cogen None Steel Mill BFG/COG/LDG

Steel 2001 180 1x109E Cogen None Steel Mill BFG/COG/LDG

Steel 2003 50 106B Cogen None Steel Mill BFG/COG

Steel 2008 450 9x106B Power None Steel Mill BFG/COG

Steel 2008 174 1x109E Cogen None Steel Mill COREX



GE High Hydrogen Experience

Project / Site GT Model No. Units Fuel Gas Features

Georgia Gulf, US MS7001EA 3 Blend Methane+50% H2

Vresova, CZ MS9001E 2 IGCC 46.8% H2

Fawley, UK MS9001E 1 RFG ~50% H2

Geismer, US MS6001B 1 PG Up to 80% H2

Refinery, US MS6001B 1 RFG 12% to 50% H2

Petro Chem., Korea MS6001B 1 PG up to 95% H2

Refinery, Inter. MS5001P 1 RFG 60% H2, propane

Reutgerswerke, GER MS3002J 1 PG 60% H2

Tenerife, Spain MS6001B 1 RFG ~70% H2

Cartagena, Spain MS6000B 1 RFG 66% H2

San Roque, Spain MS6000B 2 RFG 70% H2

IGCC=Syngas Gas; RFG=Refinery Gas; PG=Process Gas; TG=Tail gas

Project / Site GT Model No. Units Fuel Gas Features

Antwerpen, Belguim MS6000B 1 RFG 78% H2

Puertollano, Spain MS6000B 2 RFG Up to 60% H2

La Coruna, Spain MS6000B 1 RFG Up to 52% H2

Rotterdam, NL MS6000B 1 RFG 59% H2

Schwarze Pumpe, GER MS6000B 1 IGCC 62% H2

Milazzo, ITA MS5001P 1 RFG 30% to 50% H2

Ref., India MS5001P 1 RFG 50% H2

Paulsboro, US MS5001P 2 RFG 20% to 60% H2

NUP MS3002J 1 TG ~60% H2

Donges, France GE10 1 RFG 76% H2

Refinery, Jordon PGT10 1 RFG 82% H2 MS9001E

MS6001B



F-Class Hydrogen Experience

PSI

Wabash

Tampa

Polk

Exxon

Singapore

Valaro

Delaware

Turbine 7FA 7FA 2x6FA 2x6FA

H2 (% vol) 24.8 37.2 44.5 32.0

CO 39.5 46.6 35.4 49.5

CH4 1.5 0.1 0.5 0.1

CO2 9.3 13.3 17.9 15.8

N2+Ar 2.3 2.5 1.4 2.2

H2O 22.7 0.3 0.1 0.4

LHV BTU/ft3

209 253 241 248

kJ/m3

8,224 9,962 9,477 9,768

Tfuel F/C 570/ 300 700/ 371 350/ 177 570/ 299

H2/CO Ratio 0.63 0.80 1.26 0.65

Diluent Steam N2 Steam H2O/ N2

Equiv BTU/ft3

150 118 116 150

kJ/m3

5,910 4,649 4,600 5,910



References: DOE NETL; EIA; IEA and GE Internal Data

Carbon footprints of fossil power

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 %

IGCC with CCS

CC% 90%

GTCC (FA)

65% 50%

33%η

45%η 40%η

0 250 500 750 1000

CO2 Emission rate (kg/MW-hr)



Hydrogen Fuel Experience

Diffusion-flame MNQC Modeling

0

100

200

300

400

500

600

700

800

0 10 20 30 40 50 60 70 80 90 100

Percent Hydrogen

BT

U/s

cf

of

Fu

el

Process

Gases

IGCC

Gases

MNQC H2Testing

0

100

200

300

400

500

600

700

800

0 10 20 30 40 50 60 70 80 90 100

Percent Hydrogen

BT

U/s

cf

of

Fu

el

Process

Gases

IGCC

Gases

MNQC H2Testing

Reference: GE Internal data



Full Scale Syngas Combustor

SG

Diluent

NG

Detailed CFD Models of IGCC MNQC Nozzle

To Turbine Nozzles

Air Extraction

Air from Compressor

Liner

Flow Sleeve

Transition Piece

Fuel Nozzle

N2/Steam

Syngas

Natural Gas/ Syngas

MNQC Syngas Combustor



Simplified Extended Turndown SystemSimplified Extended Turndown System

40

% Load

100

0 40 60 100

% Split

100 60 40 0 % Syngas

Mix Permitted(Allowable Splits)

100% Syngas Allowed

100% NG Allowed

NOx (ppmbv)252525

90

10

30

70 % Natural Gas

Shaded: MixNot Permitted

Indicative onlyIndicative only



Development Lab Testing

Greenville, SC

• Full pressure, temperature, and

flow

• Fuel blending capability for H2,

N2, CO, CO2, CH4, and H2O

• Identical combustor hardware to

engine

• Dynamics, emissions, ignition,

full and part load

characterization

• Full combustor characterization

prior to field start-up

MNQC Syngas Test Stand

MNQC Syngas Combustor Development

Combustion development



1.0

10.0

100.0

1000.0

100 150 200 250 300

LHVeq, Btu/SCF*

Equivalent Heating Value = Heating Value of

Mixture of Syngas and Injected Steam

50 - 95% H 2 By Volume, Bal. N 2 , N 2 + H 2 0

LHV, kJ/m

NO

x @

15

% O

2p

pm

vd

1.0

10.0

100.0

1000.0

100 150 200 250 300

LHVeq, Btu/SCF*

Equivalent Heating Value = Heating Value of

Mixture of Syngas and Injected Steam

50 - 95% H2

By Volume, Bal. N 2 , N 2 + H 2 0

LHV, kJ/m 3*

NO

x @

15

% O

2p

pm

vd

MNQC H2 combustion testing

Video capture of flame structure - 85-90% H2




H2- Syngas MNQC Emissions Mapping




Combustion

Products

Fuel

LHV

Btu/lb

LHV

Btu/scf

Density

lb/scf

Mass

Ratio

N2/Fuel

H2O

% Vol

100% H2 [1] 51,495 273.5 0.0053 --- 16.94

50% H2/50% N2 3,457 137.0 0.0396 13.90 12.30

Typical IGCC Syngas 4,671 249.3 0.0534 -- --

Syngas Post-Dilution

(N2 to 15ppm NOx)1,776 114.6 0.0645 1.63 6.01

NG DLN 20,500 900.0 0.0472 -- 8.30[1] Hypothetical only -- would not be fired at 100% H2

Typical Fuel Properties

Fuel CharacteristicsFuel Characteristics



Maintaining GT Output on Syngas FuelsMaintaining GT Output on Syngas Fuels

Gen

Syngas

12%

Air - 100%

SGGas Turbine

SG Exhaust

126%

Diluent

20%Air - 6% Gas Turbine Output vs. Ambient Temperature

0 20 40 60 80 100Ambient Temp. (Deg. F)

7FA Torque Limit

7FB Torque Limit

-20 -10 0 10 20 30 40

Ambient Temp. (Deg. C)

Syngas + Diluent

7FA - Natural Gas

Outp

ut

Additional IGCC Output

Gas Turbine Output vs. Ambient Temperature

0 20 40 60 80 100Ambient Temp. (Deg. F)

7FA Torque Limit

7FB Torque Limit

-20 -10 0 10 20 30 40

Ambient Temp. (Deg. C)

Syngas + Diluent

7FA - Natural Gas

Outp

ut

Additional IGCC Output

Gen

Hydrogen

2%

Air - 100%

H2Gas Turbine

SG Exhaust

124%

Diluent

22%

Air - 0%

Un-shifted Syngas

Hi H2-Low C Shifted Syngas



Objective

IGCC & CCS combustion landscape

GE PG7321FB-H2

Cleaner

energy

from

coal

Approach Capability

IGCCwithCarbon capture

Advanced

Separation

& Gasification

Technology

• High-H2 GT fleet

• Successful operation

• Diffusion flame

• Diluent for NOx

• Advanced pre-mix combustion

• ITM Membranes -O2, CO2, H2

• DOE program

Today

Future

Pre-mix combustion



Global research footprint

Bangalore, India

4 global research centers

Niskayuna, New York Munich, Germany

Shanghai, China

Global research driving advanced power generation solutions

Highlights

• 2,600 research employees

(nearly 1,000 PhDs)

• 27,000 GE technologists

worldwide

• $5.7B technology spend

• 1,400+ patents issued

in 2006



GE and Schlumberger

• May 28: alliance agreement announced

• To accelerate the use of “cleaner coal”technology

• GE: Experience in IGCC, carbon capture

• Schlumberger: Geologic storage expertise and capabilities for site selection, characterization & qualification

• Technical & commercial certainty for moving forward with coal-based power generation



GE Energy’s Technology Enablers

Redefining our Energy Portfolio around Cleaner Energy Solutions.

Reduced Fossil Emissions +Efficient CCGT

Gas Reciprocating Engines

Environmental Services

Efficient Steam Turbine

IGCC – on it’s own

CO2 Capture – on it’s own

Integrated solutions for Clean Coal Technology ( IGCC) +CCS+EOR

Integration – Cleaner with Greener

Zero Emissions

Nuclear

Large Hydro

Next Gen Reactor

Nuclear waste

Energy Storage

Grid Integration & Mini-GridsNext Gen

Emerging

Commercial

Renewables

On/Offshore WindSmall Hydro /Refurbishment

Biomass

Geothermal

Larger Offshore Wind

Photovoltaics

Hydro Standard Plant

Waste Gasification

Fuel Cells

Hydrogen

Biofuels

Ocean Energy

“Cleaner” “Greener”

Greener Buildings

Energy Culture



Summary• Shifting Generation Mix & Fuel Landscape

• Gas Turbines and IGCC enablement

• Bridge the gap – IGCC Ready

• H2 and Syngas Experience

• Polygeneration

• Carbon Capture Capability

• Ongoing R&D - DOE H2 Turbine Program etc…

• Future of IGCC and CCS capabilities

• Team up – Infrastructure- Cluster Approach


Documents

12754064763.GENamtecPreCombustionCCSMay2010rev001Final