Energyplexes: Coal Gasification for Co-producing Hydrogen, Electricity and Liquid Fuels

1. Energyplexes: Coal Gasification for Co-producing Hydrogen, Electricity and Liquid Fuels Kei Yamashita a, b, Leonardo Barreto a a Environmentally Compatible Energy Strategies (ECS) International Institute for Applied Systems Analysis (IIASA) b Tokyo Electric Power Company (TEPCO) IEW, Laxenburg, June 24, 2003

2. Outline • The role of energyplexes • Results of literature survey and case studies • Hydrogen production from coal with CO2 capture • Co-production of hydrogen and electricity from coal • Co-production of liquid fuels and electricity from coal • Final remarks and further work

3. Energyplexes • Integrated clean, multi-fuel, multi-product systems • They enable poly-generation, or co-production, strategies and may facilitate CO2 captureefficiently and economically • Feedstock flexibility might improve energy security - less reliant on a single primary energy source • Product flexibility might increase the capability of energy-services companies to response to possible changes surrounding the energy industry • Syngas-based energyplexes could be attractive

4. Syngas Related Energy Conversion Syngas can be generated from a variety of feedstocks and can be transformed into a number of chemicals and/or energy carriers

5. Objective of study (IIASA/TEPCO collaboration) • To examine - Technologies which may enable co-feeding or co-production strategies - Potential benefits and disadvantages they may offer in the global energy system - Roles of these technologies in a transition to a long-term sustainable energy system • Initial focus on coal-based co-production technologies (hydrogen and electricity / liquid fuel and electricity) • Some strategic aspects and illustrative system configurations are highlighted

6. Hydrogen Production from Coal Conventional system (Coal PSA) with/without CO2 capture Membrane-based system (Coal Mem) with CO2 capture

7. Hydrogen Production from Natural Gas (reference system) Steam methane reforming from natural gas (NG PSA) with/without CO2 capture - well-established and least expensive at the present

8. Main Assumptions for H2 production cost calculation Natural gas price 3.1 US$(2000)/GJ (HHV basis) Coal price 1.3 US$(2000)/GJ (HHV basis) Annual capital charge rate 0.15 Capacity factor 0.9 for gas-fired plants 0.8 for coal-fired plants Electricity price 4 US$ cents(2000)/kWh for purchasing and selling CO2 disposal cost 5 US$(2000)/tCO2 a 100-km pipeline and a 2-km deep injection well

9. Estimated Hydrogen Production Costs

10. Co-production of hydrogen and electricity from coal with CO2 capture Coal Input = 100 (HHV basis)

11. Cost Estimation for Co-production of hydrogen and electricity Hydrogen production cost = Investment cost + Feedstock cost + O&M cost + CO2 disposal cost – Co-produced electricity sales Annual capital charge rate 0.15 Capacity factor 0.8 CO2 disposal cost 5 US$(2000)/tCO2

12. Co-produced Electricity value

13. Estimated Production Costs of Hydrogen from co-production systems

14. Co-production of F-T liquids and electricity from coal

15. Production Costs of Co-produced F-T liquidsversus CO2 emissions

16. Co-production of methanol and electricity from coal

17. Production Costs of Co-produced Methanol versus CO2 emissions

18. Final Remarks • Co-production schemes using coal gasification could become attractive especially when natural gas price exceeds a given level. • Membrane-based hydrogen production from coal might be promising. • Coal-derived F-T liquids and methanol seem more expensive than conventional fuels such as petroleum diesel even if the credits of co-product sales are received. • CO2 capture and storage appears to be an important prerequisite for coal-based hydrogen and liquid fuels

19. Further Work • Biomass-based energyplexes • A full-chain analysis from resource extraction to end-use applications • Identify the role of these schemes in a transition to a long-term sustainable energy system

20. Thank you very much!