IEAGHG Work on Gas CCS

Transcription

1 IEAGHG Work on Gas CCS John Davison Project Manager IEA Greenhouse Gas R&D Programme (IEAGHG) Natural Gas CCS Networking Meeting London, 30 th -31 st May 2013

2 Overview Background on IEAGHG IEAGHG s study on costs of natural gas CCS Comparison of costs of gas and coal CCS IEAGHG s future work on natural gas CCS

3 IEA Greenhouse Gas R&D Programme (IEAGHG) A Multilateral Technology Initiative established in 1991 by the International Energy Agency Based at Cheltenham, UK Aim: To provide information on the role that technology can play in reducing greenhouse gas emissions from use of fossil fuels. Objective, independent, policy relevant but not policy prescriptive Focus on CCS Activities: Studies and reports (>250) Research Networks and Conferences: (Post and Oxy-combustion, GHGT, Solid Looping, Risk, Monitoring, Modelling, Wells, Social Research) Facilitating R&D and demonstrations eg Weyburn; Summer School; peer reviews.

4 IEAGHG Membership

5 Natural Gas CCS Study Techno-economic assessment study Undertaken by Parsons Brinckerhoff, x 450MW e NGCC plant Post combustion capture MEA MEA + exhaust gas recycle Advanced solvent Pre-combustion capture Integrated plant Non-integrated plant with intermediate hydrogen storage

6 Plant Layout CO 2 capture plant CCGT (2x450MW) CO 2 compressor Stripper Absorber Direct contact cooler HRSG Gas turbine

7 Thermal Efficiency

8 Efficiency Reduction for Capture

9 Capital Cost 2011 N th -of-a-kind EPC costs Excluding owner s costs and interest during construction

10 Cost of Electricity 35% cost increase for CCS NOAK 2011 costs 8% discount rate 25 year plant life Base load operation 6/GJ (LHV) gas price 10/t CO 2 stored 10/t CO 2 emission cost

11 Cost of Electricity Breakeven CO 2 emission cost 70/t CO 2 emission cost required for the no capture cost of electricity to match the proprietary solvent CCS cost

12 NGCC Daily Load Variation UK generation data, 1 st May 2013 (NETA)

13 NGCC Annual Load Duration Curve UK data, 2012 (Elexon)

14 Cost of Electricity 50% capacity factor 90/t CO 2 emission cost Note: The plants have low marginal operating costs during the times when the owner chooses not to operate them, e.g about 50/MWh for the proprietary solvent case. NOAK 2011 costs 8% discount rate 25 year plant life 6/GJ (LHV) gas price 10/t CO 2 stored

15 Cost of Electricity with CCS NOAK 2011 costs 8% discount rate 25 year plant life 10/tonne CO 2 stored No CO 2 emission cost 6/GJ natural gas

16 Cost of Electricity with CCS NOAK 2011 costs 8% discount rate 25 year plant life 10/tonne CO 2 stored No CO 2 emission cost 6/GJ natural gas 2.5/GJ coal

17 Cost of Electricity with CCS NOAK 2011 costs 8% discount rate 25 year plant life 10/tonne CO 2 stored No CO 2 emission cost 6/GJ natural gas 2.5/GJ coal

18 Cost of Electricity with CCS Higher gas price NOAK 2011 costs 8% discount rate 25 year plant life 10/tonne CO 2 stored No CO 2 emission cost 8/GJ natural gas 2.5/GJ coal

19 On-going and Future Studies Relevant to Natural Gas Oxy-combustion turbines Adsorption of CO 2 from natural gas Post combustion capture flowsheet improvements Process control strategies for post combustion capture Energy storage and CCS Review of shale gas GHG footprint

20 Oxy-Combustion Turbines Independent assessment of performance and cost Commercial processes (CES, NET Power) Academic cycles (Graz, Matiant etc.) Review development status Identify major areas of technical uncertainty and risk Sensitivity to performance and cost of key components Outline assessment of plant operability and flexibility Integration with coal gasification Integration with industrial applications, oil and gas production etc. Utilisation of waste heat Applications where a compact plant is an advantage Use of natural gas which contains CO 2

21 CO 2 Capture in Gas Production Sleipner; 9% CO 2, Around 1 Mt/y CO 2 captured Snøhvit; 5-8% CO 2 Around 0.7 Mt/y CO 2 captured Gorgon; 14% CO 2, Around Mt/y CO 2 captured In Salah; up to 10% CO 2 Around 1.2 Mt/y CO 2 captured

22 Adsorption for CO 2 Capture in Gas Natural Production Techno economical evaluation of adsorption processes for CO 2 capture in natural gas production Design considerations for offshore and onshore production and CO 2 quality requirement for EOR / EGR / Storage Evaluate feasibility of advanced adsorbents such as Zeolites, Activated carbons, Calcium oxides, Hydrotalcites, Supported amines, Metal-organic framework (MOF)

23 Post Combustion Capture Flowsheet Improvements Performance and cost assessment (gas and coal plants) Inter-heated stripper, split flow processes, vapour recompression, multi-pressure stripping, heat integration options Trade off between efficiency and increased capital cost and complexity

24 Process Control Strategies for Post Combustion Capture Identify different operation regions and controlled variables in normal, part load and upset conditions. Develop control strategy for optimal operation of CO 2 capture processes Evaluation of the process performance improvements and costs from different control strategies

25 Energy Storage and CCS Review of energy storage technologies Implications of energy storage for operational requirements of CCS plants (ramp rates, capacity factors etc.) Assessment of opportunities to include energy storage and energy demand management in CCS plants Expand on earlier IEAGHG work Hydrogen storage Oxygen storage Integration with renewables storage technologies, e.g. electrolysis

26 Summary CCS in a gassy world is an interest for IEAGHG s members New gas CCS studies are underway and planned CCS in industry is also a major interest A study on costs of CCS at an NGCC has been completed Base load electricity cost increases by c35% Cost of abatement is c 70/t CO 2 Important to look at gas CCS in the context of future energy systems CCS in a renewables world is an interest for IEAGHG s members

27 Thank you