Hydrogen Production and Potential Non-Electricity Applications of Nuclear Energy

Transcription

1 Hydrogen Production and Potential Non-Electricity Applications of Nuclear Energy Ramesh Sadhankar July 9, 2008 Atomic Energy of Canada Ltd. Presented to WNU Summer Institute 2008, Ottawa page 1

2 Outline of Presentation Background/rationale Potential applications Current and future generation reactor capabilities Sustainability Low-temperature applications Desalination District heating High-temperature applications Hydrogen Production Hydrogen demand/supply Current production methods Hydrogen production using nuclear energy Cost of nuclear hydrogen Safety Hydrocarbon fuels from hydrogen Other process heat applications Concluding remarks 2 page 2

3 Present Generation Reactors Almost exclusively used for electricity generation Power conversion efficiency ~35% Is it possible to use waste heat to replace fossil fuel? Schematic of CANDU-6 reactor Reactor outlet 310º C, 9.9 MPa(g) Gross turbine efficiency 35.3% TH T η T H C 3 Current generation reactors are mostly water cooled Outlet temp. are relatively low for process heat applications Thermal efficiency of power conversion is low ~ 35% 2/3 rd of thermal energy is discarded to the atmosphere or a body of water If the low level heat is instead used for heating, it will improve overall efficiency, save fossil fuel and reduce GHG emission. page 3

4 Rationale Behind Non-Electricity Applications of Nuclear Energy Reducing GHG emissions by replacing fossil fuel by nuclear thermal energy Sustainability potentially abundant supply of fissile/fertile material Current thermal reactors use open (once-through) fuel cycle based on fissile U-235 Natural uranium has only 0.7% U-235 In future, symbiosis of thermal reactors and fast reactors will be able to close the fuel cycle Uranium utilization increases by more than 60 fold Thorium is more abundant than uranium (Million Tonnes) Uranium Resources Speculative Resources Known Resources Year LWR Once Through FR Introduced 2050 FR Introduced Replacement of fossil fuel by nuclear heat will significantly reduce the GHG emissions If the nuclear expansion continues with current design of reactors, the uranium resources may not be sufficient. Various studies predict years of supply from the known resources. Closing of the fuel cycle is being pursued by various international initiatives like Global Nuclear Energy Partnership (GNEP) and Generation IV International Forum (GIF). Sodium Fast Reactors have already been demonstrated before. Gas Fast Reactors are under development through GIF. Closing of the fuel cycle will guarantee virtually non-exhaustive supply of fertile and fissile material. References: Technology Road Map, Generation IV International Forum, 2002 Can Uranium Supplies Sustain the Global Nuclear Renaissance? World Nuclear Association, page 4

5 Relative Energy Potential of Canadian Natural Resources Coal 11% Natural Gas 1% Oil 5% U % Fissile Uranium Oil 0% Coal 0% Natural Gas 0% Total Uranium Uranium 100% 5 Canada is the largest producer of uranium and has the second largest proven reserve of uranium deposits only next to Australia. Canada also has substantial oil and natural gas reserves and abundant oil sands reserves. Current reactors use only U-235 isotope which is ~0.7% in the mined uranium. Even then uranium represents 83% of the total energy reserves If uranium utilization is increased 60 fold by closing the fuel cycle, the energy potential of uranium reserve will be orders of magnitude higher than other energy sources. page 5

6 Potential Nuclear Heat Applications Nuclear heat ~ 1000 C 6 Current generation reactors are capable of delivering heat between 300 and 350 C. This type of heat can be used only for low temp. applications such as desalination and district heating. In future, Generation IV reactors will operate at significantly higher temperatures, C and will make it possible to use nuclear heat directly in process industries, replacing currently used fossil fuel. This will significantly reduce GHG emissions. page 6

7 Generation IV Reactor Concepts of Generation IV International Forum Reactor Type Gas-Cooled Fast Reactor (GFR) Coolant Helium Outlet Temp. ºC 850 Neutron Spectrum Fast Lead-Cooled Fast Reactor (LFR) Lead- Bismuth Fast Molten Salt Reactor (MSR) Fluoride salts Epithermal Sodium-Cooled Fast Reactor (SFR) Sodium 550 Fast Very High- Temperature Gas Reactor (VHTR) Helium 950 Thermal Supercritical Water- Cooled Reactors Water Thermal or Fast 7 High outlet temperatures from the Gen IV reactors would allow nuclear heat to be used for process industries where the heat is currently supplied by fossil fuel Because of the high outlet temperatures, electric power generation efficiencies will be significantly higher 45-50% range. Use of thermal energy, without producing electricity will increase the overall thermal efficiency page 7

8 Low-Temperature Applications Desalination District Heating 8 page 8

9 Water Desalination - Issues 1/3 rd of world s population (1.7 billion) live in water scare areas estimated 2.4 billion by 2025 UN target By 2015, reduce the population unable to access safe drinking water to half of that in the year % of the water on earth is accessible for direct human use 70% of the planet is covered with water Fresh water 2.5% of the total 70% of the fresh water is frozen in polar ice caps rest in soil moistures or deep aquifers Desalination is a solution but energy intensive 7 22 kwh/m 3 electrical plus thermal - depending on the process (distillation, RO or combination) Natural gas is the most common fuel GHG emissions Affordability and availability 9 page 9

10 Nuclear Water Desalination Nuclear power a sustainable source of energy for desalination 150 reactor years of experience Largest desalination plant ( m 3 /d) coupled with BN350 fast reactor operated until 1999 in Aktau, Kazakhstan for 26 years Four plants ( m 3 /d) in Japan with combined 125 reactor-years India building a demonstration plant (6 300 m 3 /d) IAEA activities International Nuclear Desalination Advisory Group Collaborative Research Projects on nuclear desalination Developed a computer code (DEEP) for economic evaluation Coupling of desalination plant to nuclear reactor Avoid cross contamination by radioactivity Limit the desalination load to a fraction of total power output Alternate source of energy in case of nuclear reactor shutdown 10 page 10

11 Nuclear Desalination Projects Evaporators at Akatu, Kazakhstan Operating plant, Ohi, Japan Hybrid desalination plant, India 11 page 11

12 Water Desalination Challenges and Issues Disparity: Nuclear technology, infrastructure not available in many countries that have scare water resources Public perception: fear of radioactive contamination Socio-environmental aspects: location of nuclear plant, effect on marine environment 12 References: 1. B.M.Misra; Role of nuclear desalination in meeting the potable water needs in water scarce areas in the next decades, Desalination 166 (2004) IAEA website page 12

13 District Heating In northern countries, space and water heating represents a major energy consumption and it is largely supplied by fossil fuel In Canada commercial and residential sector account for 30% of energy consumption 60% of which is for space and water heating Using nuclear heat presents opportunity for CO 2 reduction District heating infrastructures exist in some major cities in Eastern Europe, Russia and FSU republics as well as some major cities in the West Toronto, Helsinki etc. supplied by fossil fuel The only nuclear powered district heating network is still operating in Refuna district in north central region of Switzerland Heat supplied from Beznau power plant two 350 MWe PWRs More than 2200 users 80 MWth load 31 km primary distribution network Replaces tons of heating oil per year Reduces CO 2 emission by tons per year Requires heat at relatively low temperature ~ 80 C 13 Apart from commercial and residential sector, there is also a need for space heating in industrial sectors. In Canada, greenhouses are extensively used for growing vegetables. Bruce A nuclear power station provides heat to a number of agribusinesses located in the energy park. page 13

14 District Heating Issues, challenges Locating new nuclear plants near urban areas Public perception final product is delivered to consumers directly Preventing radioactive contamination Intermediate heat transfer equipment Economics Cost competitive with current methods Consider modular reactors Combined Heat and Power (CHP) Seasonal demand only in winter Coupling load following, outages of nuclear plant, effects of transients, coupled dynamics of electricity production 14 References Generation IV Roadmap Crosscutting Energy Products R&D Scope Report, Issued by the Nuclear Energy Research Advisory Committee and the Generation IV International Forum, December 2002 Non-Electric Applications of Nuclear Energy, IAEA-TECDOC-923, (Proceedings of an Advisory Group Meeting Held in Jakarta, Indonesia, November 1995), IAEA, Vienna, January page 14

15 High-Temperature Applications Hydrogen Production through watersplitting Heat for process industries 15 page 15

16 Hydrogen Demand and Supply Current hydrogen production World ~ 45 million t/a US ~ 9-11 million t/a Canada ~ 3 million t/a Hydrogen used for chemical production is mixed with other gases Ammonia Hydrogen + Nitrogen Methanol Hydrogen + Carbon monoxide World Demand Hydrogen - the energy carrier for the future Hydrogen has potential to replace fossil fuel and significantly reduce GHG emissions Demand is expected to grow in both industrial and transportation sectors Upgrading of bitumen is a major use for hydrogen in Canada 16 page 16

17 Hydrogen Demand - Transportation Sector There is a strong incentive for alternative fuel for vehicles as the oil production and prices peak Hydrogen Fuel Cell Vehicles (FCV) - several challenges Performance improvement Cost reduction affordability Infrastructure for hydrogen storage and transport Codes and standards safety public perception Plug-In Hybrid Vehicles (PHEV) are being considered as an alternative for near-term deployment Uncertain if FCV or PHEV will dominate in the medium and/or long-term affects hydrogen demand 17 page 17

18 Global Hydrogen Demand Global Energy Technology Strategy Program (GTSP) predictions are based on successful deployment hydrogen systems and 550 ppm CO 2 climate policy Hydrogen deployment through 2035 is predicted to be in stationary applications buildings and industry Hydrogen deployment in transportation sector is expected to increase only beyond Reference: Global Energy Technology Strategy Addressing Climate Change, Phase 2 Findings From An International Public-Private Sponsored Research Program, Global Energy Technology Strategy Program (GTSP), May 2007 Authors J.A. Edmunds, M.A. Wise, J.J. Dooley, S.H. Kim, S.J. Smith, P.J. Runci, L.E. Clarke, E.L. Malone and G.M. Stokes EJ = 1 X J = 8.3 million tons of hydrogen page 18

19 Hydrogen Use in Canada Hydrogen Systems Project Team, Feb, Reference: Hydrogen Systems : A Canadian Strategy for Greenhouse Gas Reduction and Economic Growth, Prepared by Hydrogen Systems Project Team, February 16, 2005 page 19

20 Hydrogen for Oil Sands Hydrogen is used for upgrading Primary upgrading hydro-conversion Secondary upgrading hydro-treating (removes S, N) Hydrogen consumption depends on the extent of upgrading 2.5 kg/b for normal synthetic crude - 38 API 4.3 kg/b for higher quality crude - 40 API Cost of hydrogen Vs value added determines the upgrading Hydrogen is produced on site mostly by steam reforming of natural gas (SMR) Growing trend towards Partial Oxidation (POx) of coke (bitumen residue). 20 Bitumen produced from Athabasca oil sands is converted to synthetic petroleum crude through a process called upgrading which consists of increasing hydrogen/carbon ratio in the crude by addition of hydrogen The extent of upgrading depends on the target quality of synthetic crude. Higher quality crude has higher price. When the petroleum crude prices were low (~$40-50/b) greater hydrogen consumption was not economically justified. With the current high prices of crude (>$100/b), hydrogen demand for upgrading has gone up. Because of increasing natural gas prices, there is a growing trend towards using bitumen residue as feedstock for hydrogen but it produces significantly higher GHG emissions. page 20

21 Hydrogen Demand for Oil Sands Bitumen production, million b/d Synthetic crude oil, million b/d Hydrogen demand, kt/d Million t/y Million scf/d With the current high prices of petroleum crude, the economics of producing synthetic crude from oil sands has significantly improved. Bitumen production is expected to quadruple by 2040 based on the approved and planned projects in Athabasca Hydrogen demand is expected to increase disproportionately because of increasing trend towards producing higher grade crude with additional upgrading. These estimates are based on AECL s internal study. page 21

22 Why Nuclear Hydrogen? High temperature Gen IV reactors makes it possible to produce hydrogen by watersplitting processes Non-GHG emitting Much more energy efficient and economical compared to present-day electrolysis Internationally, the nuclear hydrogen R&D is being driven by the projected increase in demand for the transport sector. In Canada, unique opportunities in oil-sands sector 22 page 22

23 Current Production Methods 23 page 23

24 Production of Hydrogen Theoretical energy required to produce hydrogen Steam ~ 120 MJ/kg Methane (natural gas) ~ 20 MJ/kg Hydrogen Sulfide (found in natural gas in Alberta) ~ 10 MJ/kg Current production methods More than 70% produced by reforming of natural gas Steam- Methane Reforming (SMR) To a lesser extent from other hydrocarbon sources e.g. naphtha, petroleum residues (coke), Partial Oxidation processes ~ 2% by electrolysis water 24 page 24

25 Steam-Methane Reforming More than 70% of hydrogen produced by this process Uses natural gas - ~70% feed, ~30% fuel o CH + 2H O CO + 4H 850 C Produces 9.5 tons of CO 2 for every ton of hydrogen Cost ~$1500/ton at natural gas price of $6/GJ (2005) no CO 2 sequestration highly sensitive to natural gas price 25 page 25

26 Conventional SMR 2 million scf/d merchant plant 1/50 th of normal plant SMR CO 2 Absorption Tower 26 page 26

27 Partial Oxidation of Hydrocarbons Oxygen is introduced in the feed High-sulfur feed can be used but requires gas cleaning unit after HT Shift reactor Coke residues from upgrading plant can be used as a feed stock Cost competitive with Steam- Methane Reforming at natural gas price > $6/GJ Emits ton of CO 2 per ton of hydrogen Main attraction is price stability and secure supply of raw materials 27 page 27

28 Electrolysis of Water The only non-ghg emitting technology 28 page 28

29 Conventional Electrolysis Not economical for largescale production of hydrogen Energy efficiency ~30% compared with ~80% for SMR High equipment cost Commercial cell capacity ~ 5 kg/h Requires 8 cells for a 1 ton/d plant Requires cheap electric power Could be cost competitive if produced during of-peak power. 29 Unlike electricity, hydrogen can be stored. So off-peak capacity of a power plant can be used to produce hydrogen thus improving the economics of the power plant operation. page 29

30 Hydrogen Production Using Nuclear Energy Nuclear-assisted steam methane reforming (>800 C) Electrolysis of water conventional and high temperature Thermochemical cycles ( C) 30 page 30

31 Nuclear Assisted Steam-Methane Reforming 31 page 31

32 Use of Nuclear Energy for Steam Methane Reforming Most (~ Mt/y) of the hydrogen produced in the world is by steam methane reforming (SMR) using natural gas feedstock CH + 2H O CO + 4H In SMR, Natural gas is also used as fuel Emits about 9.5 tons of CO 2 per ton of hydrogen ~ 1/3 rd of CO 2 from fuel ~ 2/3 rd of CO 2 from the process easy to sequester Natural gas fuel can be replaced by thermal energy from hightemp. Gen IV reactor Reduces total CO 2 production by 1/3 rd CO 2 from the process can be easily sequestered thus making the process CO 2 -free US DOE and JAEA pursuing the R&D a novel SMR design is required AECL demonstrated a similar concept on a lab scale in 1980s. 32 page 32

33 Integration of SMR with Gen IV High-Temp. Reactor Source: JAEA Demonstration planned for page 33

34 Electrolysis Using Nuclear Power 34 page 34

35 Effect of Temperature on Energy Required for Electrolysis Energy Input (MJ /kg 2 H 2 ) Thermal Energy Input Electrical Energy Input Total Energy Input Temperature ( C) 35 page 35

36 Comparison of Conventional Vs HT Electrolysis Feed to the cell Operating temperature Operating pressure Electrolyte Cell potential Liquid Water <100 C V Conventional Electrolysis 1 MPa (10 bar) Mostly alkaline solution (but also acidic solutions, PEM) High-Temperature Electrolysis steam ~ 850 C 5 MPa (50 bar) Ceramic electrolyte (oxygen ion-conducting or proton-conducting ceramic electrolyte V Electrolysis efficiency Overall efficiency - current nuclear plants Overall efficiency Gen IV VHTR (900 C) ~ 80% 27% 32-36% ~ 80% ~33% 45-55% 36 page 36

37 Status of HT Electrolysis Being developed under US DOE s Nuclear Hydrogen Initiative, At Idaho National Lab (INL) Based on SOFC technology Unlike SOFC, SOEC development is entirely in nuclear R&D community Demonstrated at 100 L/h at INL 0.5 kg/h ( ~ 15 kw) integrated test planned to be complete by July 2008 Pilot scale planned for 200 kw Several challenges optimization of the cell design, equipments for handling hot (850 C) hydrogen and oxygen Parallel developments in Japan and France 25 cell prototype stack lan to develop 1000 cell stack 37 page 37

38 High Temperature Electrolysis Coupled with Gas Cooled Very High Temp. Reactor US DOE New Generation Nuclear Plant (NGNP) project Prototype high-temperature helium cooled reactor Cogeneration of hydrogen US $ 4 billion project Start-up by 2020 US DOE Nuclear Hydrogen Initiative program Integrated lab scale demonstration (15 kw) 2011 decision on technology (HTE or TC or both) Pilot scale 200 kw 600 MWth Reactor Hydrogen 2383 t/d 85 million scf/d 38 References: 1. Herring JS, Lessing P., O Brien JE, Stoots C, Hartvigsen J, Hydrogen production through high-temperature electrolysis in a solid oxide cell, Second Information Exchange Meeting on Nuclear Hydrogen Production, Argonne National Laoboratory, IL, USA, October 2-3, Herring JS, Lessing P., O Brien, JE, Stoots C., Kaufmann, M., High temperature solid-oxide electrolyzer system, DOE Hydrogen Program FY 2004 Progress Report. page 38

39 Thermochemical Cycles 39 page 39

40 Thermochemical cycles for H 2 Production Water splits spontaneously at very high temperature H 2 O H 2 + ½ O 2 (> 2500 C) Thermochemical cycle splits water at relatively lower temperature (<900 C) HighTemp. Heat Water Chemicals O 2 Cycled H 2 Waste Heat Sulfur-Iodine Cycle 40 page 40

41 Thermochemical cycle Efficiencies Thermal efficiency of the process is important for economics Higher temp. cycles have better thermal efficiencies Minimum electrical energy use maximizes energy efficiency Thermochemical cycles requiring electrical energy for one or more chemical reactions are known as hybrid cycles ΔH η th = Q T T H TH Target efficiencies are in the 40-50% range compared to 25-30% for conventional electrolysis Sources of heat (non-ghg emitting) Gen IV nuclear, Solar thermal, fusion 0 ΔH ΔG C η th page 41

42 Thermochemical cycles for H 2 Production Thermochemical cycles have been studied since 1964 In 2000, US DOE study screened 115 cycles Two promising cycles were recommended for further development Sulfur-Iodine Cycle (General Atomics, USA) UT-3 (University of Tokyo Ca- Br-Fe process) US DOE s Nuclear Hydrogen Initiative selected S-I cycle for demonstration Generation IV International Forum (GIF) also selected S-I for development Number of Publications Number of Publications Year References: 1. High Efficiency Generation of Hydrogen Fuels Using Nuclear Power, Annual Report to the U.S. Department of Energy, August 1, 1999 through July 31, 2000, by L.C. Brown, J.F. Funk and S.K. Showalter, Report No. GA-A23451, July High Efficiency Generation of Hydrogen Fuels Using Nuclear Power, Final Technical Report to the U.S. Department of Energy for the period August 1, 1999 through Sept. 30, 2002, by L.C. Brown, G.E. Besenbruch, R.D. Lentsch, K.R. Shultz, J.F. Funk, P.S. Pickard, A.C. Marshall and S.K. Showalter, Report No. GA-A24285, June 2003 page 42

43 Desirable Characteristics of Thermochemical Cycle Minimum number of chemical reaction steps Minimum number of separation steps Minimum number of elements Employ elements which are abundant Minimize flow of solids Minimize use of expensive materials by avoiding corrosive chemicals Minimum electrical energy input Extensively researched - many papers from many authors and institutions Tested at a moderate scale Good efficiency and cost data are available Temperature compatibility with the nuclear reactor operating temperature 43 page 43

44 Sulfur-Iodine Thermochemical Cycle Requires high temperature (>850 C) reactor e.g. VHTR, MSR Significant challenges in separation of HI and H 2 SO 4 Various process flow sheets proposed Efficiency Vs. Cost optimization Cogeneration can improve efficiency from 42% to 52% Low temp. waste heat can be used for desalination H 2 O 2 Water SO 2 Heat 1/2O 2 +SO 2 + H 2 O H 2 SO C H 2 + I 2 2HI I 2 >800 C 120 C HI SO 2 + I 2 + 2H 2 O 2HI +H 2 SO 4 Waste Heat H 2 SO 4 44 page 44

45 Current Status of S-I Process Endorsed for development by the Generation IV International Forum (GIF) GIF Hydrogen Project Plan identified remaining R&D tasks for the participants (Canada, France, Japan, South Korea, EURATOM and USA) JAEA has a fully integrated lab scale facility (50 L/h) KAERI just completed an integrated lab scale facility US DOE and French CEA collaborating on a pilot plant demonstration (5 Nm 3 /h) at General Atomics facility in San Diego target commissioning July 2008 US DOE s Nuclear Hydrogen Program s target for pilot plant by page 45

46 S-I Cycle Development in Japan H2 Production Rate Connect to HTTR Basic Engineering Test Rig Produce acids Decompose H 2 SO 4 Pilot test Basic engineering Testing Rig(on going) 30l/hr H2 produced Principle proved (1997) Decompose HI 46 page 46

47 Hybrid Sulfur Thermochemical Cycle Developed by EU Joint Research Center (ISPRA) and Westinghouse Eliminates use of expensive iodine Simple two-step process Challenge is to reduce power consumption and cost of electrolyzers Less efficient and costcompetitive compared to S- I Cycle Estimated efficiency 37% to 40% Selected by GIF as alternative technology O 2 Water SO 2 Heat >800 C 1/2O 2 +SO 2 + H 2 O H 2 SO 4 Electrolysis C SO 2 + 2H 2 O H 2 +H 2 SO 4 Waste Heat Electrical energy H 2 SO 4 H 2 H2 47 page 47

48 Lower-Temperature Thermochemical Cycle Heat and Electricity Water H 2 O C 2CuCl (l) + 1 O 2 = CuO * CuCl 2 ( s) 2 CuO*CuCl C CuCl 2CuCl 2 (s) + H 2O = CuO *CuCl 2 (s) + 2HCl (g) C CuCl 2 (electrolysis) 4CuCl (s) = 2CuCl2 ( aq) + 2Cu CuCl Cu C 2CuCl(l) + H ( g) = 2Cu + 2HCl 2 HCl Waste Heat 48 page 48

49 Status of Cu-Cl Cycle Development Concept developed by US DOE (Argonne Nat. Lab) Hybrid cycle - ~40% of energy input is electrical Maximum temp. is 520ºC compatible with lower temp. Gen IV reactors SCWR, SFR Initial estimates of efficiency ~ 44% - comparable to S-I cycle Challenges Solids handling - continuous transfer between steps Electrolytic vessel is too large Being investigated by GIF Hydrogen Project as an alternative technology A consortium of Canadian universities developing all aspects of technology in collaboration with US DOE (ANL) AECL s focus on development of electrolytic step Optimize efficiency electrode configuration AECL also developing an alternative process to eliminate solid copper handling 49 References: 1. M.A. Rosen, G.F. Naterer, R. Sadhankar and S. Suppiah, Nuclear-Based Hydrogen Production with a Thermochemical Copper-Chlorine Cycle and Supercritical Water Reactor, in press, International Journal of Energy Research 2. Generation IV Reactor Development in Canada, R. Sadhankar, D. Brady, R. Duffey, H. Khartabil and S. Suppiah, 3 rd International Symposium on SCWR Design and Technology, Shanghai, March 12-15, Future Hydrogen Production Using Nuclear Reactors, R.R. Sadhankar, J. Li, H. Li, D.K. Ryland and S. Suppiah, Climate Change Technology Conference of the Engineering Institute of Canada, Ottawa, Ontario, 2006 May Leveraging Nuclear Research to Support Hydrogen Economy, R.R. Sadhankar, International Journal of Energy Research, Vol. 31, , May Lewis MA, Serban M, Basco J, Hydrogen Production at <550 C Using Low Temperature Thermochemical Cycle., ANS/ENS International Meeting, New Orleans, LA, Nov page 49

50 Modified Cu-Cl Thermochemical Cycle Eliminates solid copper handling Development and optimization of electrolysis equipment is a challenge Initial work by AECL shows promise O 2 Heat and Electricity 530 C 2CuCl (l) + 1 O 2 = CuO * CuCl 2 ( s) 2 Water CuCl CuO*CuCl C 2CuCl 2 (s) + H 2O = CuO *CuCl 2 (s) + 2HCl (g) CuCl 2 H 2 (electrolysis) <100 C 2CuCl + HCl( aq) = CuCl2 + H2(g) Waste Heat 50 page 50

51 Efficiency of Hydrogen Production Using Nuclear Electricity and Heat Water-Splitting carbon-free Processes Conventional Electrolysis High-Temperature Electrolysis Thermochemical Water Splitting Steam- Methane Reforming Temperature Required, C ~ ~800 Efficiency of chemical process, % > Efficiency coupled with present generation nuclear reactors, % Not feasible Not feasible Efficiency coupled with high-temperature Generation IV reactors, % page 51

52 Cost of Nuclear Hydrogen 52 page 52

53 Cost of Nuclear Hydrogen Base-line costs (Source International Nuclear Societies Council, 2004): SMR - $1552/t ( for 50 t/day production, natural $ 6.67/GJ) Electrolysis - $ /t (for 1 ton/day, $46-56/MWh) Nuclear Hydrogen costs Sulfur-Iodine thermochemical (US DOE, 2007) $ 2200/t Hybrid sulfur process (Westinghouse, 2005) - $2,400/t High-temp. electrolysis (US DOE, 2007) $2,530/t Both thermochemical and high-temp. electrolysis are evolving technologies cost cannot be estimated realistically 53 References: 1. A.I. Miller, Hydrogen Economics for Automotive Use, Chapter 6 in Nuclear Production of Hydrogen Technologies and Perspectives for Global Deployment, International Nuclear Societies Council, 2004 page 53

54 Cost Comparison High Low H2 Cost, $/kg Carbon W ater 2 0 Natural gas Coal Biomass On-shore wind Source: IEA Committee on Energy R&D, Hydrogen Coordination Group, June 2004 Off-shore wind Solar thermal Solar-PV Nuclear - electrolysis Nuclear - Thermochemica 54 Reference: Hydrogen Coordination Group, Committee on EWNERGY Research and Development, International Energy Agency, Organisation for Economic Co-operation and Development, Policy Analysis IEA/CERT/HCG(204)3, June 2004 The costs for hydrogen production from natural gas ad coal include the cost of CO 2 capture and storage. Hydrogen production from on-shore wind, off-shore wind, solar thermal and solar PV power sources is assumed to be by electrolysis of water. page 54

55 Evolution of Cost Over Time Relative Efficiency Relative Cost Time 55 page 55

56 Safety Considerations 56 page 56

57 Nuclear Safety Leave nothing to chance. -GNF No historical precedent of co-location of hydrogen plant and nuclear reactor. Licensing challenges for first-of-a-kind Regulators must be convinced that hydrogen plant does not pose statistically significant hazard for nuclear reactor 57 page 57

58 Safety Considerations Quantitative Risk Analysis (also known as Probabilistic Safety Analysis) required Hazards due to hydrogen plant and heat transfer loop Hydrogen Explosions Chemical fires (H 2, O 2 and other reactive chemicals) Chemical releases (toxic, corrosive gasses and liquids) Radioactive contamination of hydrogen plant Migration of radioactive tritium through intermediate heat exchanger DOE estimated minimum distance based on 100 kg hydrogen explosion to reduce the probability of nuclear core damage to 1 in 1 million. 110 m 60 m with blast deflection barriers, earthen wall or below-grade nuclear plant 58 page 58

59 Proposed Arrangement of Nuclear and Hydrogen Plants 59 References: 1. Steven R. Sherman, Nuclear Plant /Hydrogen Plant Safety: Issues and Approaches, ST-NH2 Conference, American Nuclear Society Meeting, Boston, June 24-28, Hyung Seok Kang et al. Regulatory Issues on the Safety Distance due to Gas Explosion and an Overpressure Prediction by Correlation for the JAEA Explosion Test in an Open Space, ST-NH2 Conference, American Nuclear Society Meeting, Boston, June 24-28, 2007 page 59

60 Hydrocarbon Fuels from Nuclear Hydrogen 60 page 60

61 Hydrocarbon Fuels for Transportation Coal Coal Power Plant Flue Gas Separator Water O2 CO 2 Electric Power Hydrogen Plant H 2 Synfuel Plant Transportation Fuels Heat + Electricity Water Nuclear Power Plant 61 References: 1. Ken Shultz, S. Locke Bogart, Richard P. Noceti, Synthesis of Hydrocarbon Fuels Using Renewable and Nuclear Energy, ST-NH2 Conference, American Nuclear Society Meeting, Boston, June 24-28, B.D. Middleton and M.S. Kazimi, Nuclear Hydrogen and Captured Carbon Dioxide For Alternative Liquid Fuels, ST-NH2 Conference, American Nuclear Society Meting, Boston, June 24-28, 2007 page 61

62 Nuclear Hydrogen + Captured CO 2 an Alternative Route to Hydrogen Economy Motivations Technologies for CO 2 capture and making synthetic fuels from hydrogen and CO 2 are available Does not require large infrastructure changes to transportation sector to achieve the same CO 2 reduction Current CO 2 emission in USA Total 5900 million t/y Thermal power plants ~ 1894 million t/y Transportation section ~ 1891 million t/y Converting all CO 2 from thermal power plants to synthetic fuel Reduces CO 2 emissions by ~ 1/3 rd Requires 255 million t/y of hydrogen (25 times the current demand) 215 GWth (~ 105 GWe) Gen IV nuclear capacity 150 to 300 new nuclear plants depending on individual plant capacities Replaces ~75% of gasoline 62 page 62

63 High-Temperature Process Heat Applications 63 page 63

64 Petroleum Refining Processes requiring large amount of thermal energy are potential candidates for Gen IV reactors Oil refineries Petrochemical plants Aluminium production A petroleum refinery requires about 500 MW of thermal energy most of which at or below 540 C Major challenge is integration of process plant with a nuclear reactor Thermal Power demand of 6 million t/y refinery Process Crude Oil Distillation Vacuum Distillation Propane Deasphalting Vacuum Residue Distillation Vacuum Gas Oil Desulphurisation Middle Dist. Desulphurisation Gasoline Desulphurisation Gasoline Reformer Hydrogen generation Effluent Water Cleaning Steam Generation Heat (MW) Temp, C Gen IV high temperature reactors could be used to provide thermal energy for process industries. Combined heat and power applications (CHP) improve the overall energy efficiency. Ref: Generation IV Roadmap Crosscutting Energy Products R&D Scope Report issued by the Nuclear Energy Advisory Committee and the Generation IV International Forum, Report No. GIF page 64

65 Extraction of Bitumen from Deep Oil Sands Deposits of Gen IV Systems Steam Assisted Gravity Drainage (SAGD) for deep deposits Steam Requirements barrels of steam/barrel of oil 6-12 MPa, C steam Challenges Distance for steam travel Fracture pressure of formation 65 page 65

66 Conclusions Use of nuclear thermal energy directly has tremendous potential to replace fossil fuel and reduce GH-emissions Current generation reactors can possibly be used for low-temp. applications Desalination, district heating Challenges dynamics of co-generation, public perception Hydrogen demand will grow rapidly Demand from industry (oil refining, upgrading) is expected to peak earlier Demand from transportation sector is expected to dominate beyond 2050 several challenges remain in the deployment of hydrogen as energy carrier Non-GHG emitting H 2 production technologies required for the future Conventional electrolysis using off-peak power may be deployed in the interim Thermochemical cycles and high-temperature electrolysis need further development and demonstration but are important Coupling technologies and safety issues are equally important 66 page 66

67 Topics for Discussion Low Temperature Applications Potential to reduce greenhouse gas emissions Technical challenges of deployment of nuclear reactors for Combined Heat and Power (CHP) applications load following, disruption of service due to outage of nuclear reactors, avoiding radioactive contamination, seasonal load for district heating Public perception final product (potable water and heating) directly delivered to the customer, location of nuclear plants near urban areas Adequacy of current generation and Gen III ( MW) reactors for moderately low load applications for desalination and district heating Need to develop modular reactors (100MW?) for these applications Disparity availability of technology and nuclear infrastructure in countries that need desalination Economics consumer affordability 67 page 67

68 Topics for Discussion Hydrogen Production Factors affecting growth in hydrogen demand: stationary fuel cell applications, industrial applications ammonia, methanol, oil upgrading etc., fuel cell vehicles, parallel development of plug-in hybrid vehicles Challenges of hydrogen as an energy carrier - storage, distribution, infrastructure, fuel cell costs and performance, safety codes and standards Factors favouring use of nuclear power for hydrogen: GHG reduction, energy efficiency at high temperatures, volatility of natural gas prices Technological challenges for deployment of high-temperature electrolysis and thermochemical cycles: developed on bench-scale, high costs of development and demonstration on large scale, integration (coupling) with nuclear plant, safety Can the water-electrolysis be deployed with the current nuclear reactors in the interim? Cost competitiveness of nuclear hydrogen 68 page 68

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