Gas Turbine Improvements Enhance IGCC Viability · Some important IGCC milestones for GE in Year...

GE Power Systemsg

Gas Turbine ImprovementsEnhance IGCC Viability

2000 Gasification Technologies ConferenceSan Francisco, California, October 8-11, 2000

Douglas M. ToddManager, Process Power PlantsGE Power Systems (GEPS) Schenectady, NY, USA

Contents

Abstract . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2Combustion/Environmental Testing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4System/Operability Design and Controls . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6Improved Ratings and Performance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11Reliability/Availability/Maintenance (RAM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12Conclusion . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13Appendix . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15

List of Figures. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15

Gas Turbine Improvements Enhance IGCC Viability

Gasification Technologies Conference, October 8-11, 2000 1

Abstract Gas turbine technology development has great-ly contributed to increased use of IGCC powerplants worldwide. Along with environmentalfactors and gasification processes, this develop-ment will continue to lead the way towardimproving performance and lowering costs.Several specific areas of development haveresulted in 24 IGCC plants currently on line orin construction:

■ Combustion/environmental testing

■ System/operability design andcontrols

■ Improved ratings and performance

■ Reliability/availability andmaintenance (RAM).

New records have been set yearly in each ofthese areas to extend the viability of IGCC tech-nology (Figure 1). This report summarizes thecurrent capabilities and discusses plans forfuture development.

Introduction Some important IGCC milestones for GE inYear 2000 include startups, new projects andtechnology improvements.

Three breakthrough startups are shown inFigure 2:

■ The Motiva-Delaware 9 ppmvd NOx,240 MW plant on Pet Coke first usedsyngas in September. This 6FA GT hasoperated at a rating 30% higher thannatural gas.

■ The Sarlux 540 MW vis breaker tarplant first used syngas on August 13th.It had already achieved 7050 hours ofoperation on distillate oil.

■ The Exxon Singapore 180 MW steamcracker bottoms plant is planned forstartup later this year. It has alreadyoperated 3000 hours on distillate oil,which is one of 42 different fuelcombinations it is designed to handleon the fly.



Single Train IGCC Plants

S107H S109H

(60 Hz) (50 Hz)

Net Output 460 MW 550 MW

Thermal Eff. 50% 50%

Vol % H2O in Exhaust

40300 10 200

1

0.8

0.6

0.4

0.2

Life Fraction

IGCCCONTROLSYSTEM

Integrated Oxygen GasifierCoalO2

Coal

Gas

N2 - 100%HighPressureAir

SeparationHX

GenGT

Supplemental Air Air Extraction0%50%

100%

Case ACase B

Case C

100%

50%0%

Integrated AirGasifier

CoalFeedStock

HotH2S

CAir

HS

Air

Ash

GT G

Steam

ToStack

Steam

ST

Eco

no

mics

Figure 1. Gas Turbine Improvements

GT30049A.ppt

Combustion

Environmental

Testing

System

Operability

Design

Improved

Ratings

Performance

Reliability

Availability

Maintainability

Total accumulated operation for GE IGCCtechnology is now more than 322,000 hours.

Four new projects have been awarded that total1995 MW, as shown in Figure 3. These plants willbe put into operation in 2003, 2004 and 2005.The Gonfreville plant is a tri-fuel/dual gas

design operating at a rating 24% above naturalgas operation. PIEMSA will operate at a rating14% higher than natural gas while simultane-ously providing partial air integration with theair separation unit (ASU). NTW uses blast fur-nace gas and distillate fuel. Three Confidential



Figure 2. Year 2000 IGCC Startups

Figure 3. New Syngas Plant Awards

Motiva Delaware

240 MW2 x 6FA

AUG 00

Sarlux

550 MW3 x 109E

AUG 00

Exxon Singapore

180 MW2 x 6FA

DEC 00

Cumulative Total

14 PLANTS

322,000 Hours

Gonfreville

400 MW

2 x 9E

PIEMSA

800 MW

2 x 9FA

NTW

45 MW

1 x 6B

Confidential

750 MW

3 x 7FA

GT30050.ppt

GT30051.ppt

7FA units will use the next generation designbased on Motiva-Delaware at a rating 8% high-er than natural gas with partial air extraction.

The technology for each of these plants hasbeen developed step by step in cooperationwith other industry suppliers. This illustrateshow IGCC is a technology partnership ratherthan a simple grouping of GT, ASU, and gasi-fier equipment.

Combustion/Environmental TestingThe core of an IGCC design is based on combustion development through laboratorytesting. As the critical orifice in the plant, thecombustor must be designed for a wide rangeof operating conditions with backup and co-firing fuels. It also has to meet ever tighteningenvironmental requirements. Experimentingwith these parameters in the field can be verycostly because they can affect all the relatedtechnologies, as shown in Figure 4. This datawas created in 1990 at the request of Shell andEPRI and shows that typical gasifier syngas out-let constituents are not suitable for meeting

today's NOx requirements. It also shows thatdilution of the syngas with nitrogen, water,CO2 or combinations can meet the desiredoperating conditions. Note that the diluentquantities needed are equal or greater thanthe quantities of syngas. This means the result-ant flow in the combustor may be eight timesthat of a natural gas machine.

Figure 5 shows the typical can annular combus-tor. Current production has evolved to anincreased diameter standard that allows a widerrange of fuel constituents and co-firing capabil-ity. An individual combustor can be tested at fullflow, temperature, and pressure for any syngasexpected by the gasification system. In manycases there is also a field test at startup to tunethe multiple cans and confirm the results of lab-oratory testing. These machines require a start-up fuel because of the dangers of starting onhydrogen based fuels. This allows many plantsto operate on backup fuel earlier, which consid-erably reduces interest costs on construction.The dual fuel capability has been developedinto a co-firing feature so users can design



Figure 4. GE “F” Combustor Testing

Full Load NOx at 15% O2

• Simulated Coal Gas

• 2550 F/1400 C CombustorExit Temperature

100 150 200 250 300

4,000 5,000 6,000 7,000 8,000 9,000 10,000 11,000

1000

100

10

1

N2

H20

C02

LHV, kJ/m3

LHV, Btu/SCF

vs Heating Value

NO

x, P

PM

VD

• Over 20 Years Experience Testing Low Btu Fuels

• First Plant Commissioned 1984

• 11 Units Currently Operating on Synthetic Gas

• 13 Additional Units Scheduled to Start 2000-2005

• Machines Include 6B, 7EA, 9E, 9EC, 6FA, 7FA, and 9FA

GT23090A.ppt

plants for larger power output than can beobtained with syngas alone.

The numerous projects shown on Figure 6 indi-cate the wide flexibility developed to date forplants using syngas. Hydrogen varies from 8.6%to 61% while other constituents vary widely withair-blown versus oxygen-blown syngas. The tophalf of the chart shows the constituents from the

gasifier while the bottom half shows the diluentsneeded to meet emission or power augmenta-tion requirements. By combining this combus-tion technology with output enhancement capa-bility, plants can determine the most optimumand economic mix of diluents. The ability to usenitrogen economically is derived from elevatedpressure ASU improvements and can be very



Figure 5. 6FA IGCC Multi-Nozzle Combustion System

Figure 6. Syngas Comparison

Natural Gas

Steam

Endcover

CombustionCasing

Transition Piece(Differs For 9FA)

Flowsleeve

Fuel Nozzles

Stage 1 Nozzle(Nozzle Box For Test)

BlendedFuel

Emissions Sample

Combustion Liner

T/C Rake Location

Dynamic PressureLocations

GT30025A.ppt

GT26111A.ppt

Same System Design for 6FA, 7FA, 9FA & 9EC

important in obtaining flat ratings at high ambi-ents. Many of these plants produce co-productsfrom the syngas and the GT must be able toaccommodate the resultant tail gas.

We have completed testing for hydrogen-onlyand CO-only fuel to complete the combustionmap. The H2-only case is based on removal ofCO as CO2 for Enhanced Oil Recovery (EOR)or sequestration and allows CO2-free powerplants. Figure 7 indicates that ratios of 50/50

hydrogen/nitrogen can have very low NOxcapability as well as enhanced output in amodern IGCC. With this new combustiontechnology it may be possible to use IGCC forCO2-free plants at about 15% extra cost.

Typical NOx emissions are shown in Figure 8.It is unfortunate that not all regulatory agen-cies give credit for IGCC plants’ excellentemission characteristics for heavy/solid fuels,preferring to treat them as GT plants.Fortunately, individual localities can makethat distinction. We must become sophisticat-ed in resolving this issue so that Best Available

Control Technology (BACT) can beaddressed for the type of feedstock ratherthan as a generic GT plant. For instance, NOxemissions from Motiva-Delaware using PetCoke should have a lower BACT than a heavyoil plant due to the extra effect of higher CO2illustrated in the original 1990 data.

Figure 9 summarizes recent combustion devel-opments that are contributing to the success-ful startups and improved viability of IGCC.

System/Operability Design andControlsSystem design of an IGCC has become a teameffort in order to optimize the whole plantrather than an individual component. Variousteams of suppliers and EPCs have contributedsignificantly to the continued improvements.GE has worked on both air-blown and oxygen-blown systems, as shown in Figure 10. Most ofthe recent efforts have concentrated on oxy-gen due to the large size of plants and particu-larly the co-production of chemical products.



Video Capture of FlameStructure - 85-90% H2

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. N2, N2 + H20

LHV, kJ/m3

4,000 5,000 6,000 7,000 8,000 9,000 10,000 11,000

Figure 7. NOx vs. Equivalent Calorific Value for Several Fuel Compositions

NO

x@

15%

O2,

ppm

vd

GT30052A.ppt

To achieve optimal results for each systemshown in Figure 10 we can design a differenttype of air integration. Tampa Polk is designedfor air side integration at 0%, which means noair extraction to the ASU but full nitrogenreturn to the GT. PIEMSA is designed for par-tial integration where some air is extracted for

the ASU. Sierra Pacific is designed for full inte-gration where all air for the ASU is extracted.

Various gasifiers require from 11% to 20% ofthe GT air flow for full air integration. TheIGCC combustor is designed to extract up to20% on Model F machines without affecting thecooling air. For systems such as GTL that



Figure 8. Typical NOx Emissions from IGCC Plants

Figure 9. Combustion Technology Development

MOTIVA - First Pet Coke Appli. With 9 ppm NOx

Exxon - 1st St. Cracker Bottoms With 25% Wobbe Var.Air - First Air-Blown Tail GasOxygen - Variety of Syngas

Hydrogen Combustion for Reduction of CO2 Mixtures of BFG, COG, Nat. Gas

Operating

Cool WaterPSI - WabashTampa - PolkTexaco - El DoradoStar - DelawareSarlux - Italy

Predicted

Sierra Pacific - PinonExxon - SingaporeGonfrevilleConfidentialPIEMSA

NOx PPMVD @15%02

25<25<25<259 - 15<30

<42 (<9 Thermal)42359 - 1530

GT24333A.ppt

GT26116A.ppt

IGCC

IRCC Steel

GTL

require more air, a medium air extraction(MAE) system at 37% is available. For E levelmachines a high air extraction (HAE) systemat 50% is being designed. Overall IGCC opti-mization for a specific site depends upon theoperating requirements and the fuel type todetermine the kind of air side integration tobe used, if any. In the larger plants we arefinding that operability can be enhanced withpartial air integration by reducing the size ofASU compressors.

Mixed fuel operation or co-firing has becomean important operating mode to enhance eco-nomics. It was first used at the Texaco ElDorado IGCC plant in Kansas where the gasifi-er was only a third of the size of the plant elec-trical load. Since starting in 1996 the El DoradoGT has performed at better than 97% poweravailability. Many later plants such as ExxonSingapore, Gonfreville and PIEMSA also havethis feature. For a dual gas design the operabil-ity standard is in the 70/30% range. However,



Figure 10. GE IGCC Systems

Figure 11. IGCC Mixed Fuel Capability

GT24127A.ppt

BKGT25004D.ppt

there is a new system used for Exxon Singaporecapable of operating in the 90/10% range, asshown in Figure 11. Mixed fuel operation cangenerally be accommodated down to 20% load.For a dual fuel syngas/distillate machine thedistillate can be controlled down to 10% whilethe syngas is generally used in the 70% range.

A tri-fuel dual gas system is being used for theGonfreville plant. This 90/10 system incorpo-rates a single fuel nozzle for natural gas opera-tion and splits the fuel flow into all six nozzlesin each combustor on the syngas side of thebumpless transfer zone. Figure 12 shows the fuelsystem, inert and main air purge systems for thisplant. Both nitrogen and air from the compres-sor discharge (CPD) are used to purge duringvarious operating modes. This system also hasthe 90/10 capability. In keeping with the GTpackaging concept the complete system is mod-ularized as shown on Figure 13. This particularmodule was shipped to Exxon Singapore.

Many studies have determined that NOx bene-fits as well as power augmentation benefits canbe realized by using diluents to lower the heat-ing value of the syngas. GE has chosen to injectnitrogen in the combustor in the same mannerused for steam injection rather than mix it withthe fuel. In this manner the nitrogen pressurecan be lower than the syngas pressure and thefuel control valves can be reduced to half sizesince they are controlling only the fuel.Combinations of N2 and moisture are fre-quently the most cost effective, considering theaero limitations in a standard GT for additionalflow. Figure 14 compares several methods ofmoisturization. The amount of water saturationis generally limited by the low-level heat avail-able and varies widely by gasifier type. Severalrecent systems have chosen to moisturize thenitrogen.

Another area of concern to the operator is themethod of overall plant control. IGCCs can be



Figure 12. Tri-Fuel Dual Gas SystemGT30000A.ppt

designed to follow the gasifier and use only thesyngas fuel that is made. They also can bedesigned to meet electrical load demand eitherby forcing the gasifier to follow the demand orby co-firing the backup fuel. The latter is morefrequently used. A part of the design normallyincorporates a GT simulation for the benefit ofthe team. This study of startup and shutdown

modes and ambient effects at the beginning ofthe plant design is crucial. Many componentsneed to be designed for conditions other thanthe “Guarantee Point” to provide flexibility andeconomics. Cost of Electricity (COE) or thecombined products on an annual kW/hrs basisis helpful in producing the best proformaresults.



Figure 13. Auxgas Module – Isometric View

Figure 14. Moisturization AlternativesGT23091A.ppt

SyngasSaturator

SimplifiedNitrogenSaturator

• Layout Shown is forModule CurrentlyUnder Constructionfor theExxon/SingaporeProject

GT30002A.ppt

Improved Ratings and PerformanceFor natural gas machines, normal GT full loadoperation over the ambient range follows airdensity and falls off considerably at high ambi-ents. We can counteract this with IGCC designsand frequently design the system to utilize thefull winter capability, even at 90°F / 32°C. Themost illustrative example is the 9EC machinewhich produces 150 MW at high ambient onnatural gas and 215 MW at the same high ambi-ent in an IGCC design. This ratio of 43% extrapower in the GT is partially diminished byplant auxiliaries but can be a major influenceon the IGCC viability. Figure 15 demonstratesthe physics of this benefit.

Natural gas fuel provides 2% of the flowthrough the turbine as compared to syngas at16% flow due to the lower heating value. Thisallows the turbine to make more power, gener-ally an increase of 20%, when fired to the sametemperature. The mechanical capability of aspecific turbine and its surge margin require-ment limit this capability differently for eachmachine setting a specific maximum output.

For GE units this is usually the torque limitwhich was originally designed for some verylow ambient. If the syngas flow raises the GTabove its maximum capability at an averageambient, inlet guide vanes are closed to restrictair and therefore output. As ambient increases,these guide vanes are opened to hold maxi-mum output until the guide vanes are fullyopen. That ambient point is called the breakpoint in the curve. Above that the output fallsoff. For Tampa Polk, the break point is 90°F /32°C. We are constantly endeavoring to removelimits and expect to make even more improve-ments in the next generation IGCCs.

An important new system developed over thepast year incorporates the latest GT improve-ments for a High Efficiency Quench (HEQ)design. This plant incorporates all of the fea-tures developed from previous plants andincludes an additional output enhancement ofan expander turbine in the fuel system. It pro-duces an additional 4% output. GE now has theability to supply this expander and incorporateit into the plant guarantees.



20% ExtraOutput

Gen

Natural Gas 2%

Syngas16%

Air - 100%

Gas Turbine

NG Exhaust 102%

SG Exhaust 116%

Gas Turbine Output vs Ambient Temperature

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

7FA/9FACurrent Torque/IGCC Limit

Near Future Torque Limit

-20 -10 0 10 20 30 40

Ambient Temp. (Deg. C)

Syngas

7FA

(MW

e)

9FA

(MW

e)

7FA/9FA - Natural Gas

40

Figure 15. IGCC Output Enhancement with Gas Turbine AdvancesGT30053A.ppt

-20 -10 0 10 20 30 40

When added together, these output enhance-ments have been the major contributor to thesignificant plant cost reductions we are seeingin recent bids.

Reliability/Availability/Maintenance(RAM)Cost of Electricity is affected by RAM perform-ance in a manner similar to plant cost and fuelefficiency. Generally, RAM performance isimproved during the design stage by incorpo-rating lessons learned in previous plants. GTsuppliers can do some of this based on theirexperience in other fields but it is very impor-tant to have IGCC experience. Figure 16 showsover 322,000 hours of modern experience,including some machines that have accumulat-ed over 24,000 hours of syngas experience. Thelessons learned have been reported before andincorporated in all current designs. The Tampaplant has reported that power availability is run-

ning at 96%. The fleet leader is El Dorado,which has a power availability average of 97%for the last 4 years.

From this experience GE has concluded, “ASyngas CC can have the same performance as aNatural Gas CC,” as shown in Figure 17. To real-ize this same performance, several specific con-ditions need to be met by the supplier.Experience has shown that higher hydrogencontent, which produces more water, and theincreased flow of syngas tend to increase metaltemperatures in the hot gas path. GE has devel-oped a control system to mitigate this effect bylowering firing temperature to maintain metaltemperatures consistent with natural gasmachines. On this basis we have been willing toprovide Long Term Service Agreements(LTSA) at a cost basis similar to natural gasmachines along with availability guarantees.Many current IGCC plants have found this to bea cost effective way to make IGCC viable.



GE Company Proprietary

SyngasStartDate

Cool WaterPSITampaTexaco El DoradoSierra PacificSUV VresovaSchwarze PumpeShell PernisISE / ILVAFife EnergyMotiva DelawareSarluxPiombinoExxon Singapore

107E7FA

107FA6B

106FA209E6B

2x6B3x109E

6FA2x6FA3x109E109E

2x6FA

120262250

40100350

40120540

80240550150180

5/8411/959/969/96-

12/969/96

11/9711/96

-8/008/00

10/00-

27,00021,00022,00022,100

063,00026,00039,60098,200

01,0003,000

00

---

17,10025,000

1,500-

17,9003,200

10,500- -

4000

1,0004,0004,570

-- -

3,400---

4,00010,500

- 3,000

Customer

Totals 322,900

Type MW Hours of Operation

Syngas N.G. Dist.

GT25677L .ppt

October 2000

Figure 16. GE Syngas Hours of Operation

GT25677L.ppt

Conclusion In summary, current production gas turbinescan be used for IGCC applications but somemodifications are desirable to enhance theIGCC economics.

Figure 18 lists the types of modifications normal-ly considered up front.

Gas turbine improvements have come fromoperation in many applications and from indus-try competition. In addition, specific attentionto IGCC needs in an emerging market has gen-erated a host of new technology needed forIGCC viability. When combined with the sametype of efforts by ASU, cleanup, and gasification

technologies, we can see an exciting trend.Figure 19 quantifies one version of these tech-nologies since 1994. Heat rate improvements of15% and plant cost improvements of 26% havebeen achieved. More important, however, is an18% reduction in COE with room for furtherreductions. This trend of improvements andcost reductions can be applied to the industry asa whole.

As shown in Figure 20, we now count 24 plantsand 6752 MW capacity. Our fast growing experi-ence base, along with at least 10 more plants inthe bidding stage, demonstrate that IGCCpower plants are a viable and welcome develop-ment in the field.



Figure 17. Syngas – Reliability/Availability/Maintenance

Figure 18. Gas Turbine Modifications for IGCC

Lif

e F

ract

ion

GT30023B.ppt

GT30054B.ppt

• IGCC Combustion System• Off-Base Syngas Fuel Control / N2 Purge Module Including Syngas

Stop & Control Valves and Gas Detectors• Syngas Fuel Piping: On-Base and Connection to Syngas Module• Nitrogen Injection Skid• Fire and Hazardous Gas Protection• Air Extraction and Control Skid• Steam Injection For NOx Control on Backup Fuel• Combustion System Lab. Verification Testing• Larger Stage 1 Nozzle• Mark VI Unit Controls• Control & Protection System Additions• Accessory System / Enclosure Design for Syngas

Syngas Combined Cycle Can Have Same Performance as Natural GasCombined Cycle

• Need Automatic FuelSwitch/Nitrogen Purge

• Need Clean Syngas

• Reduced Firing Temp toMaintain Design Metal Temp/100% Life



1994 9F HEQ 1999 9H HEQ1997 9FA HEQ 1999 9H HR Oil

50%

60%

70%

80%

90%

100%

Heat Rate Total Installed Cost Cost of Electricity

GT30055A.ppt

Figure 19. Economic Impact of HEQ IGCC Design Study Improvements

Customer C.O. Date MW Application Gasifier

SCE Cool Water - USALGTI - USADemkolec - NetherlandsPSI/Destec - USATampa Electric - USATexaco El Dorado - USASUV - Czech.Schwarze Pumpe - GermanyShell Pernis - NetherlandsPuertollano - SpainSierra Pacific - USAISAB - ItalyAPI - ItalyMOTIVA - DelawareSarlux/Enron - ItalyEXXON - Singapore

Bio Electrica - ItalyFIFE - ScotlandEDF - TotalFIFE Electric - ScotlandNihon Sekiyu - JapanIOC ParadipConfidentialPIEMSA

1984198719941995199619961996199619971998199819992000200020002000

20012001200320032004200420042004

120160250260260

40350

40120320100500250240550180

12120400400350180750800

Power/CoalCogen/CoalPower/CoalRepower/CoalPower/CoalCogen/Pet CokeCogen/CoalPower/Methanol/LigniteCogen/H2/OilPower/Coal/Pet CokePower/CoalPower/H2/OilPower/H2/OilRepower/Pet CokeCogen/H2/OilCogen/H2/Oil

Power/BiomassPower/SludgePower/ H2/Cogen/OilPower/Coal/RDFPower/OilPower/Pet CokePower/Pet CokePower/H2/Oil

Texaco - O2Destec - O2Shell - O2Destec - O2Texaco - O2Texaco - O2ZUV - O2Noell - O2Shell - O2Prenflow - O2KRW - AirTexaco - O2Texaco - O2Texaco - O2Texaco - O2Texaco - O2

Lurgi - AirBGL - O2Texaco - O2BGL - O2Texaco - O2Shell - 02Texaco - 02Texaco - 02

6752

Figure 20. ICCC Penetration

GT30055A.ppt

GT25747H.ppt

Appendix

List of FiguresFigure 1: Gas Turbine Improvements

Figure 2: Year 2000 IGCC Startups

Figure 3: New Syngas Plant Awards

Figure 4: GE "F" Combustor Testing

Figure 5: 6FA IGCC Multi-Nozzle Combustion Systems

Figure 6: Syngas Comparison

Figure 7: NOx vs. Equivalent Calorific Value for Several Fuel Compositions

Figure 8: Typical NOx Emissions from IGCC Plants

Figure 9: Combustion Technology Development

Figure 10: GE IGCC Systems

Figure 11: IGCC Mixed Fuel Capability

Figure 12: Tri-Fuel Dual Gas System

Figure 13: Auxgas Module – Isometric View

Figure 14: Moisturization Alternatives

Figure 15: IGCC Output Enhancement with Gas Turbine Advances

Figure 16: GE Syngas Hours of Operation

Figure 17: Syngas – Reliability/Availability/Maintenance

Figure 18: Gas Turbine Modifications for IGCC

Figure 19: Economic Impact of HEQ IGCC Design Study Improvements

Figure 20: ICCC Penetration



Gas Turbine Improvements Enhance IGCC Viability · Some important IGCC milestones for GE in Year...

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