WP2: Hydrogen and fuel cell systems

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1 WP2: Hydrogen and fuel cell systems Multi-time scale modelling and analysis of the future hydrogen supply chain Sheila Samsatli, Nouri Samsatli and Nilay Shah Aberdeen, 21 May 2013

2 Hydrogen as the future transport fuel

3 Hydrogen supply network pathways Raw materials Production technologies Form Primary distribution Storage facilities Secondary distribution Dispensing technologies Natural gas Coal Steam methane reforming Coal gasification Liquid hydrogen Tanker truck Railway tanker car Liquid hydrogen storage Tanker truck Railway tanker car Fuelling stations (liquid) Biomass Electricity Biomass gasification Electrolysis Compressed gaseous hydrogen Railway Tube tanker trailer car Railway tube car Compressed hydrogen gas storage Tube trailer Railway tube car Fuelling stations (gas)

4 Key questions Under what conditions can we expect to see a large scale H 2 generating and using system in the UK? What are the optimal system configurations under different conditions? What improvement should be targeted for components for them to become relevant at the system level? What are the impacts of hydrogen storage on whole-chain operation? Is there any added value?

5 Approach Develop an optimisation framework that can support strategic decisions in hydrogen supply chain design and operation for the energy (esp. transport) sector in the UK over a long-term planning horizon Include spatial and temporal (short, medium and long timescales) elements Identify the main data requirements for such an activity

6 Model elements 1. Description of the spatial layout (grid squares) 2. Description of time (multiple time scales) 3. Production facilities 4. Storage facilities 5. Production and storage sizes 6. Hydrogen physical forms 7. Primary energy sources 8. Transportation modes 9. Fuelling stations and secondary distribution

7 Grid squares The UK mainland is divided into 34 grid squares of equal sizes Aberdeen Glasgow Newcastle Leeds Manchester Liverpool Sheffield Birmingham Coventry Bristol Greater London and the South East Plymouth Portsmouth

8 Time Modelled using hierarchical non-uniform time discretisation Five 6-year periods identical years in a period seasons in a year Winter Spring Summer Autumn 13 identical weeks in a season days in a week M T W Th F S S Four 6-hour periods in a day

9 Model elements Raw materials Production technologies Form Primary distribution Storage facilities Secondary distribution Dispensing technologies Natural gas Coal Steam methane reforming Coal gasification Liquid hydrogen Tanker truck Railway tanker car Liquid hydrogen storage Tanker truck Railway tanker car Fuelling stations (liquid) Biomass Electricity Biomass gasification Electrolysis Compressed gaseous hydrogen Railway Tube tanker trailer car Railway tube car Compressed hydrogen gas storage Tube trailer Railway tube car Fuelling stations (gas) Plant size Production capacity range (t/d) Small Medium Large Storage size Storage capacity range (t) Small Medium Large

10 Hydrogen demand Hydrogen demand Winter Spring Summer Autumn Six-yearly profile Seasonal profile Average H 2 demand (kt/d) in WD Q1 WD Q2 WD Q3 WD Q4 WE Q1 WE Q2 WE Q3 WE Q4 Quarter daily profile

11 Base case - network snapshots at different times Summer Summer Summer Winter

12 Cost (M$/day) Base case breakdown of cost Plant OPEX Fuelling station OPEX Raw material cost Transport CAPEX Plant CAPEX Storage CAPEX Transport OPEX Storage OPEX

13 Base case - production and storage facilities Total UK capacity investment and utilisation Production plants Storage facilities Number of facilities according to size Production plants Storage facilities

14 Snapshot of London and the South East (grid 29) in No. of production plants SML MED LRG SMR CG BG WE No. of storage facilities SML MED LRG LH2S CGH2S week dynamic profile during summer in Demand Production Surplus Weekly transport

15 Snapshot of London and the South East (grid 29) in year hydrogen inventory profile Winter Spring Summer Autumn Week

16 Case study 1: Impact of including existing facilities Existing facilities H 2 network considering existing facilities Plants Steam methane Type reforming Size Medium Large Grid g07 1 g17 1 g19 1 g27 1 g29 1 Storage Size Medium Large Grid g07 1 g17 1 g19 1 g27 1 g29 1 Summer Summer Location of existing facilities

17 Case study 1: Impact of including existing facilities (cont...)

18 Case study 2: Impact of storage costs on storage utilisation Base case cost Storage Facility Capital Cost (M$) Form Liquid hydrogen Compressed hydrogen gas Size SML MED LRG SML MED LRG LH2S CGH2S Unit storage cost ($/t/d) Form Liquid hydrogen Compressed hydrogen gas Size SML MED LRG SML MED LRG LH2S CGH2S Total UK surplus Total daily network cost (Runs include existing facilities)

19 Case study 3: Impact of limiting the storage capacity Case 1: Unlimited storage capacity Case 2: Upper bound on storage capacity = 50% of the base case storage Case 3: Minimum storage requirement Case 1 Case 2 Case 3 Plant CAPEX + OPEX (M$/day) Storage CAPEX + OPEX (M$/day) Transport CAPEX + OPEX (M$/day) Total network cost (M$/day) (Runs do not include existing facilities)

20 Case study 4: Impact of not considering the seasonal and daily variations in the demand Case 1: With temporal variations, Case 2: No temporal variations, no existing facilities no existing facilities Case 3: No temporal variations, with existing facilities Plant CAPEX + OPEX (M$/d) Storage CAPEX + OPEX (M$/d) Total network cost (M$/d) Total UK storage capacity No storage facilities established Case 1 Case 2 Case 3

21 Transport Storage Plant Case study 5: Impact of H 2 form on network cost CAPEX (M$/d) OPEX (M$/d) Total network cost

22 Case study 6: Hydrogen as electricity storage Electrolysers and hydrogen storage can take advantage of daily price variations in electricity Electricity cost + = Hydrogen demand Hydrogen surplus Advantages: Flattening of the effective demand Reduced requirement for peaking generators Enhanced operating efficiency of production plants Hydrogen production

23 Conclusions For any conceivable scenario, an economically competitive H 2 supply network can be designed Hydrogen will be produced from natural gas in medium to large reforming plants, distributed via trucks and rail and stored in small and medium storage facilities Lower network costs can be achieved by: Utilising existing production facilities Investing in storage facilities Using compressed gaseous hydrogen instead of liquid hydrogen Not including the dynamics in the model will result in underestimation of the overall network cost Electrolysers and hydrogen storage can take advantage of daily price variations in electricity

24 Future work Stationary applications CCS Distribution via pipelines Mega-scale storage, e.g., caverns Addition of other novel technologies GHG emissions as another objective