APGTF UK Post Combustion Carbon Dioxide Capture R&D Activities. Hans Jensen February 2008

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1 APGTF UK Post Combustion Carbon Dioxide Capture R&D Activities Hans Jensen February 2008 Statoil IPCC Fluor Statoil

2 Contents The need for CCS Post Combustion Capture R&D needs R&D activities UK universities, UK industry and Europe / Worldwide

3 Who s got the problem?

4 The problem Fossil fuels are needed! A range of analysis show that fossil fuels is likely to remain a major energy source in 2030 The introduction of renewable energy sources in the energy system will play a large role, but not large enough and soon enough In several countries nuclear power is currently not an option

5 What is Post Combustion capture (PCC)? Carbon dioxide is absorbed from the flue gas by a liquid solvent (typically aqueous amine solution) The solvent is then pumped to a desorber, where it is heated to drive off the CO 2. The regenerated solvent is then cooled and reused. Amine absorption technology has been used in the oil and gas industry for many years. Application to power station flue gas involves new challenges: much greater scale and more difficult chemistry. Capable of 90%+ CO 2 capture Relatively easy to retrofit to an existing power plant Possible to test the process on part of the flue gas stream

6 PCC Impact on Host Power Station Reduces efficiency from approx. 45% to approx. 35% Boiler Steam Turbine Generator Requires about half steam from LP turbine Energy penalty comprises steam for reboiler 45%, pumps and fans 10% and CO2 compression 45% 5% boiler losses 1% feedwater heating Condenser 43.7% condenser heat rejection 3.3% power plant auxiliaries 1% generator losses Increased capital cost Boiler Steam Turbine Generator Substantial land area Impact on flexibility High impact means that even incremental improvements can make a big difference 5% boiler losses 1% feedwater heating Condenser 23.7% condenser heat rejection Capture and Compression 25.7% 4.3% 3.3% capture capture plant power plant plant electric load auxiliaries steam 1% generator losses

7 Research Requirements Understanding and minimising costs and impact on host plant Understanding environmental issues (emissions, waste streams) Understanding process chemistry, corrosion, solvent degradation Process integration and optimisation Gas cleaning requirements Evaluating technologies Improvement in process technology / reduction in efficiency penalty Developing modelling capability Understanding implications for power plant flexibilty, grid code and commercial implications Understanding Engineering issues for retrofit Understanding implications for CCGTs Understanding regulatory and legislative requirements

8 UK Research Projects (current) Project Scope Funding Body Academic Partners Industrial Partners Casscap Amine postcombustion capture and test rig TSB (UK Govt) Imperial College RWE npower, Doosan Babcock, Scottish & Southern Energy, EdF, Scottish Power, Drax Power, Visser Smit Hanab UK Ecoscrub Hybrid / amine oxyfuel process EC Research Fund for Coal and Steel Leeds, AUTH (Greece), ISFTA (Greece) RWE npower, PPC (Greece) PhD studentships Amines chemistry, corrosion and performance, plant integration, CO 2 transport BCURA + others Imperial College, Cranfield University, Cardiff University Eon, RWE npower, Doosan Babcock and others Eco-copps Modelling of capture plant integration TSB (UK Govt) Leeds University RWE npower, BOC Linde, Doosan Babcock UK Carbon Capture &Storage Consortium Project All aspects of CO2 capture and storage including PCC UK Research Councils TSEC Aberdeen, BGS, Cambridge, Cranfield, Edinburgh, Glasgow, Heriot-Watt, Imperial, Leeds, Manchester, Newcastle, Nottingham, Plymouth Marine Lab, Reading

9 RWE npower post-combustion capture strategy 2008 H1 H H1 H2 CCS tested and commercially available for H1 H2 H1 H H1 H2 H1 H H1 H2 H1 H H1 H2 H1 H H1 H2 H1 H H1 H2 Issue Phase 0 Phase 1 Phase 2 Timescale Benefits Operation Capture Constraints Transport Storage Phase 0 CTF development Chemistry of capture solvents Environmental issues Energy requirements Modelling capability for scale-up Operational capability Assess technologies 2008 Phase 1 Pilot plant 2010 Scale up capability Efficiency optimisation (e.g. heat recovery options) Availability/flexibility Materials issues Reliable operating costs 2014 Phase 2 Government funded Demonstrator FGD/SCR interface Integration with turbines Mass transfer issues Construction methods Full CCS chain (including compression)

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11 Test Programme Features 8m column height 0.07 MWe (50 kg/h CO 2 ) SO 2 and NO X pre-treatment Multiple solvent sampling locations Provision for corrosion coupons and alternative material test sites Trace gas injection Continuous analysis Test programme MEA reference tests with heat and material balances and parametric studies Alternative solvents e.g. MDEA, hindered amines and blends Validation of baseline process economics and assessment of plant flexibility Tests on different flue gases and fuels including biomass

12 Aberthaw pilot facility (2010) Key role in capability development building operational experience assisting in technical decisions for demonstration and in troubleshooting plant in early years Evaluating issues requiring longer operation a larger scale Long-term degradation of solvent Materials and corrosion Scale-up CO 2 Purity and implications for compression Performance on a real power station

13 UK Government Competition Competition launched by BERR in November 2007 Aims to be first large scale coal power station CCS scheme in the world Post combustion capture MWe (will accept staged approach) 15 year project Operational by 2014 Three consortia under consideration

14 Some PCC Pilot Plant Projects Didcot test rig European CO2 (2008) Esbjerg Pilot Plant Test Centre (2006) (Mongstad) Cato pilot Plant (2008) ENEL /ENI pilot Plant Brindisi (2009) Niederaussem Pilot Plant (2009)

15 Phase I of E.ON s broad programme to develo 2nd generation post combustion capture with Karlshamn world market leaders ongoing UK Government CCS Competition entry Kopenhage n 3,0 MW el MW el May 2008 London w. Electrabel 1MW el, 2009 Kingsnorth Wilhelmshaven Amsterdam Heyden Maasvlakte Berlin 5.5 MW el 2009/10 7MW el 2009 <1 MW el MW el 2009/10 R&D CCS-budget with a commitment of about 100 Million CCS - View from Industry: E.ON 19th September 2008 E.ON UK Seite 15

16 CESAR Project EU FP7 funded project 19 partners including power companies, OEMs, research organisations and universities Builds on findings of Castor project will use the Castor Esbjerg pilot plant to test novel amines Aims to reduce cost of capture below 15 euro / tonne Looking at novel solvents, membrane processes and environmental performance

17 International Academic Links University of Texas Research programme into all aspects of post combustion capture including energy efficiency, amine degradation, analytical techniques Supported by a number of industrial partners including UK utilities Pilot plant offers opportunity to test different amines University of Regina International Test Centre supports a range of research activities including degradation, materials performance, EOR ITC houses an amine pilot plant and University runs the Boundary Dam Pilot plant where CO2 capture using the MEA process is tested on real coal flue gas Supported by a wide range of international companies including UK utilitiies

18 Links with Technology Providers In September 2008, Doosan Babcock signed an agreement with HTC Purenergy of Canada to license the company s technology for post-combustion capture of CO 2 and will take advantage of the series of demonstration projects in which HTC Purenergy are involved. Other UK companies have been sponsoring research projects internationally Continuing dialogue between UK power companies and international technology providers such as Fluor, MHI, HTC, Cansolv etc

19 Research Requirements Understanding and minimising costs and impact on host plant Understanding environmental issues (emissions, waste streams) Understanding process chemistry, corrosion, solvent degradation Process integration and optimisation Gas cleaning requirements Evaluating technologies Improvement in process technology / reduction in efficiency penalty Developing modelling capability Understanding implications for power plant flexibilty, grid code and commercial Understanding Engineering issues for retrofit Understanding implications for CCGTs Understanding regulatory and legislative requirements Site specific research needed Limited -site specific () Limited

20 Conclusions Coal is likely to be a necessary part of the fuel mix needed for power generation at least until 2030 and action is required from industry to address GHG emissions A range of capture options is available for fossil-fired plant but all require further R&D investment and assessment Transportation of CO 2 is possible by on-shore or off-shore pipe line or by specially adapted tankers CO 2 storage is possible but a number of technical and legal obstacles need to be overcome CCS needs to be recognised in the EU ETS to encourage development More confidence is needed with CCS so risks can be better understood, the regulatory regime is smoothed and requirements for new plant are understood Public acceptability is a critical issue

21 Visit us on our web-site: RWE Group Research & Development RWE Research Forschung & Development & Entwicklung Contact me:

22 Back up slides

23 ECO-Scrub Concept Project 39 month project funded by EC Research Fund for Coal and Steel, co-ordinated by RWE npower in collaboration with three universities, two research institutes and three utilities from five EU member states Enhanced combustion with oxygen and scrubbing either no recirculation or partial recirculation of flue gas with replacement of some air by oxygen reduces volume of flue gas enhances CO 2 concentration of flue gas Output of simulations for a lignite-fired power plant Reference case Retrofit Case (oxyfuel) Several potential benefits potential for net reduction of operating cost due to increased capture efficiency (opex) potential for slight reduction in size of post-combustion capture plant (capex) reduced-cost retrofit option or potential for savings in new plant through advanced combustion optimisation and reduced boiler size may also be able to reduce size of SCR plant no issues with air inleakage Retrofit Case (postcombustion) Retrofit Case (ECOS- Scrub) Gross electric power MWe Gross electrical efficiency % Net electric power MWe Net electrical efficiency % Pumps (electric) MWe CO2 compressors (electric) MWe Fans and compressors (electric) MWe Reboiler duty MWth O2 in secondary air % vol Data courtesy of CERTH/ISFTA, National Technical University of Athens

24 Post-combustion capture at Didcot Specification Treat 33% of 0.5 MW CTF flue gas Carbon dioxide removal using MEA o 1 tonne per day (>85%) SO 2 and NO X pre-treatment Multiple solvent sampling locations Provision for corrosion and alternate material test sites Test programme Comparison of energy requirements for range of solvents Compatibility with bio-mass Testing different flue gas compositions. Parametric tests of solvent loading and desorption temperature and pressure. Alternative solvents e.g. MDEA, hindered amines Validation of baseline process economics and assessment of plant flexibility

25 Overview of oxyfuel programme Safety handling and storage of O 2 and CO 2 CTF Studies Flame detection issues (higher moisture and CO 2 may affect UV and IR absorption) Safety of mixing oxygen/co 2 Flame stability Safety Safe switch-over the oxyfuel combustion Safety of staff with CO 2 / and flue gas leaks Purging for safety Air leakage Optimum recycle ratio Air heater design Optimisation of mixing strategy (where to add oxygen (PA/SA/TA or overfire air etc.) Process Development Gas recirculation Oil burner operation on oxyfuel Flexibility - start-up/shutdown limited by air separation unit so cold-start on air Selection of coals (optimise purchasing) Use of biomass Furnace slagging Furnace Corrosion Fouling Fuel Issues NO X chemistry not well understood) Heavy metal recycling and ash composition Burner design Carbon burnout Optimisation Heat transfer (radiative/convective properties) Regulation issues CO 2 purity limits for oxyfuel Desktop Pre-investment issues compared with post-combustion capture Studies Required footprint for retrofit (e.g. air separation unit)

26 Schematic of CTF

27 Amine Test Rig Process Flow Diagram

28 What is an Amine? Ammonia (NH3) in which one or more hydrogen atoms have been replaced by organic groups. Monoethanolamine MEA or 2-aminoethanol C2H7NO or NH2.CH2.CH2OH H H N OH Methyldiethanolamine (MDEA) HO CH 3 N OH