Prof Mohsen Assadi Presentation

European Commission Cooperation Council for theArab States of the Gulf

Clean natural gas applications

GT & CCS

Prof. Mohsen Assadi Center for Sustainable Energy Solutions (cenSE)

Univ. of Stavanger, Norway

Workshop IAbu Dhabi, January 2012

Clean Natural Gas Workshop Clean Natural Gas Workshop –– Abu Dhabi January 2012Abu Dhabi January 2012

OutlineOutline• Balancing & backup for renewable energyBalancing & backup for renewable energy

• Clean NG applications?– NG vs. Oil and coal

NG i b k f l f i t itt t• NG main backup fuel for intermittent renewable energy

• GT & CCS technologiesSt t f th t– State of the art

• NG‐fueled power plants with CCSp p2


The energy challenge of the 21st centuryIntroduction

gy g ysecurity of energy supply

environmentenvironment economics

3


Backup & Balancing Powerp g

Wind powerWind power production

El t i itElectricity demand

4


Balancing & Backup Powerg p• Stochastic nature of renewable energy gyrequires balancing & backup power

– Fast starting– Fast starting– Load followingReliable– Reliable

– High efficiency & Low emissionsFuel flexible– Fuel flexible

– Low investment and operational costs

N t l th id l f l & G t bi th=>> Natural gas the ideal fuel & Gas turbine the preferred energy conversion technology

5


Clean Natural Gas ApplicationsClean Natural Gas Applications• NG cleaner than both Oil & Coal

– NG emits lower levels of NOx and particulate i i d i ll SO2 demissions, and virtually no SO2 and mercury

emissions.

– CO2 from combustion of coal atoms not avoidable

• NG combustion generates ca. 30% lower CO2 than Oil and Coal (CxHy)

==> NG: an important energy source in Europe!

6


European Pipeline NetworkEuropean Pipeline Network

7


NG usage in Europe 2009NG usage in Europe 2009

8


Power plant projects (MW)Power plant projects (MW)

9


Gas power plant projects 2010Gas power plant projects 2010

10


Nuclear power plant projects 2010Nuclear power plant projects 2010

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Direct use of NG• Potential for higher efficiency, avoiding

i lconversion losses– Investment in gas distribution net– Technology development for improved performanceperformance

– CCS needs to be tailor made!

NG & Bi t t ti f l• NG & Biogas as transportation fuel– Both for marine and road transportation (lower CO2 emission)

– Successive replacement of NG with Biogasp g

12


GT Technology Development

• Different optimization criteria for jet engines, simple cycle GT & CC plants

13

y

• Intelligent monitoring at component & system level


SGT-75037 MW, 40%Launched nov 2010

S h tiSchematicCompressorCombustion chamberExpander/Turbine

Compressor Combustion Expander /

Expander/Turbine

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Compressor Combustion Chamber

Expander / Turbine


Performance improvementp• Compressor

– Increased mass flow & PR, same inlet area– Active tip clearance control & improved aerodynamics– Inlet cooling / Inter‐cooling

• Combustion chamber– Efficient material cooling, reduced impact on COT– Fuel flexible DLN burnersue e b e bu e s– Stable combustion at various loads/operational conditions

• Expander/Turbine• Expander/Turbine– Improved material cooling (closed loop, steam cooling, etc)I d lif i & d d l

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– Improved component life time & reduced losses


Aero dynamic sealing cooling etcAero dynamic, sealing, cooling, etc.

16


System level considerations• Flexibility, the main issue

– Frequent starts/stops & load changes– HRSG, a key componenty p

• Combining natural circulation (low pressure section) & once through boiler design (high pressure section), reducing material thickness & inertia

– Fuel flexibility

• Intelligent monitoringArtificial intelligence based monitoring tools for– Artificial intelligence based monitoring tools for condition based maintenance

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• CCS & system integration


Technology Roadmaps and RD&DTechnology Roadmaps and RD&D• “Technology roadmaps” developed by governmental and

private sector anticipate that CO capture will be available forprivate‐sector anticipate that CO2 capture will be available for commercial deployment at power plants by 2020.

• However the plan will require aggressive and sustained• However, the plan will require aggressive and sustained efforts to advance promising concepts to commercial reality.

Th f f t t R&D ti iti i• The focus of most current R&D activities is on:

– Cost reduction rather than additional gains in the efficiency f COof CO2 capture.

– Availability of advanced CO2 capture systems for commercial rollout, and how much cheaper they will be compared to current technology.

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– Novel, lower‐cost technologies.


Status of Capture Technologyp gy• All capable of high CO2 capture efficiencies (typically about 90%),• High cost and the large energy requirements for operation• High cost and the large energy requirements for operation.• No full‐scale applications of CO2 capture on a coal or gas fired

power plantpower plant.

• Substantial research and development (R&D)T d l d i li l i h– To develop and commercialize lower‐cost capture systems with smaller energy penalties.

– To develop and testing new or improved solvents that can lower theTo develop and testing new or improved solvents that can lower the cost of current post combustion and pre‐combustion capture,

– Potential “breakthrough technologies”• Novel solvents, sorbents, membranes, and • Oxyfuel systems

19


CCS‐Technologiesg

20Source: ECN


Post‐combustion capturep

21Source: CRC


Status of Capture Technologyp gy• Post-combustion systems

– Post‐combustion CO2 capture offers the greatest near‐term potential.

– Can be used to retrofit existing power plants.power plants.

• Challenges– Installing current amine post‐combustionInstalling current amine post combustion

technology on new conventional subcritical, supercritical, and ultra‐supercritical coal‐fired power plants p p pwould:

• Increase the COE by about 80%. • Large quantity of energy required to• Large quantity of energy required to regenerate the amine solvent.

• Approximately 30% energy penalty to compress the CO to pipeline

• Environmental Impacts of Atmospheric Emissions from A i b d P t C b ti

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compress the CO2 to pipeline conditions.

Amine‐ based Post‐Combustion


Post‐combustion• Retrofit possible

C b li d i d d t f t f l t– Can be applied independent of type of plant

• Based on chemical absorption– Used previously, but not for large scale carbon capture from power plants

• Efficiency penalty in range of >10%• Improvement potential

– Solvents: lower energy consumption and degradation– System integration: improved heat management and reduced parasitic losses

– CO2 recirculation: higher CO2 partial pressure in exhaust gas

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Post‐combustion capture baselineMain contributions of the research work‐PostC

Post‐combustion capture baseline•Chemical amine solvent absorption‐stripping process

• ~30% energy penalty• ~80% capital cost increase• ~80% higher COE (€100/ton CO )(€100/ton‐CO2)

• ~95% more water

CO2compression

Aux.10%

Steam stripping

loss70%

compression20%

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Net electric efficiency (%)

?

49,48w/ PC CO2 capture NGCC Ref.

58,3

45 47 49 51 53 55 57 59

25


Exhaust gas recirculationgWhy?

Natural Gas

CO2

• To reduce the flow rate of exhaust gases to be treated

• To increase the CO2HRSG CO2 Capture

UnitAir

Cleaned Exhaust

GG

To increase the CO2concentration

Liquid H2O

Exhaust Gas Recirculation (EGR)

Benefits• Reduced reboiler duty >>net efficiency 7.0

7.5

8.0

MEA (30 wt%)CO2 capture rate 90%Lean loading 12.6D b 1 86 bReduced reboiler duty net efficiency

increase by ~1%‐point

But… 5.5

6.0

6.5

ler d

uty (GJ/ton

CO2) Desorber pressure 1.86 bar

Simulated in CO2Sim

• Additional blower• Increased water cooling requirement of ~50MW 3 5

4.0

4.5

5.0

Specific reb

oil

no EGR

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50MWth3.0

3.5

0 5 10 15 20 25 30

CO2 concentration (mol%)

with EGR


Pre‐combustion capturep

27Source: CRC


Status of Capture Technologyp gy• Pre‐combustion systems (IGCC

power plants)power plants)• The carbon contained in the

syngas is captured beforesyngas is captured before combustion and power production occur– COE for an IGCC power plant

without CCS > PC power planCOE i b 40% t t– COE increases by 40% to capture CO2 (SelexolTM process)

– 20% energy penalty (capturing and compressing) for 90% CO2 in pre‐combustion IGCC applications

GE’s IGCC with CCS System

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Pre‐combustion• Applicable only to gaseous fuel

Requires gasification of liquid and solid fuels– Requires gasification of liquid and solid fuels

– ASU needed for O2‐drivengasification (high CO2 partial pressure in fuel gas)pressure in fuel gas)

• Results in a hydrogen rich fuel– major technology development for H2 fueled GT for IGCC

• Efficiency penalty in range of >10%y p y g• Improvement potential

ASU higher efficiency/lower energy demand– ASU: higher efficiency/lower energy demand

– System integration and control: improved heat management and reduced parasitic lossesmanagement and reduced parasitic losses

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ConfigurationgGasification, Syngas Cooling & Scrubbing

Water Gas Shift (WGS)Acid Gas Removal (AGR)

Water Gas Shift (WGS)

Air Separation Unit (ASU)

bi

HRSG

30CO2 Compression

Gas Turbine


Oxy‐Fuel combustiony

31Source: CRC


Status of Capture Technologyp gy• Oxy-fuel combustion system

– High potential for a significant reduction in capture costs compared with current state‐of the‐art amine scrubbing.

Challenges:• the capital cost and energy consumption

for a ASU to produce oxygen• boiler air infiltration (mainly N ) excess• boiler air infiltration (mainly N2), excess

O2 contaminating in the CO2sequestration stream

• Construction of a new supercritical oxy‐Coal combustion power plant equipped with a commercially available ASU:y– Increase in COE by about 60% and have a

25% energy penalty compared with a new supercritical air‐fired, coal‐based

European Energy Forum

32

new supercritical air fired, coal based power plant without CO2 capture


Oxy‐fuel combustionOxy fuel combustion• Major GT‐technology development required

– Combustion

– Turbomachinery (compressor/expander)– Turbomachinery (compressor/expander)

• Heat exchanger (exhaust gas condenser) • Oxygen separation crucial

ASU (cryogenic)– ASU (cryogenic)

– Chemical Looping Combustion (CLC)

– Membrane

• Potential for lower efficiency penalty (<10%)Potential for lower efficiency penalty (<10%)

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Holistic Approach, for an integrated solutiono st c pp oac , o a teg ated so ut o

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The way forwardThe way forward• Feasibility study aiming at identification and evaluation of

h i l bili ipartners technical capabilities:– Test facilities: lab scale, bench scale, pilot scale, full scale– Tools for design analysis evaluation monitoring etc– Tools for design, analysis, evaluation, monitoring, etc. – Deliverable: Assessment report to EU‐GCC as base for future projects

• Setting up a feasibility study project• Setting up a feasibility study project– Developing & submitting a project proposal

h l b l d l l• Project setup with lab scale and pilot plant– Using existing research infrastructure in Europe

Tools and method validation for a full scale plant analysis– Tools and method validation for a full scale plant analysis

• A new large scale project with “real plan” demonstration in GCC i ?

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GCC region ?

European Commission Cooperation Council for theArab States of the Gulf

Name: Mohsen AssadiEmail: [email protected]: 0047 45224698

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Prof Mohsen Assadi Presentation