Hydrogenenergikjeder og energilagring med hydrogen TEP4150 Energiforvaltning og -teknologi Torsdag 26 februar :00-13:00

Transcription

1 1 Hydrogenenergikjeder og energilagring med hydrogen TEP4150 Energiforvaltning og -teknologi Torsdag 26 februar :00-13:00 NTNU Energi- og Prosessteknikk (EPT) Prof. II Dr.-Ing. Ulrich Bünger

2 2 Outline (1) Lecture One Hydrogen energy chains Why hydrogen energy? Hvorfor hydrogen What are energy chains? Hva er energikjeder? Theoretical considerations for energy chain calculations Teoretisk grunnlag for energikjedeberegninger Typical energy chains with hydrogen Typiske energikjeder med hydrogen Energy consumption, GHG emissions and hydrogen costs Energiforbruk, drivhusgassutslipp og kostnader Relevance of results portfolio analysis Relevans av resultater portfolio analyse

3 3 Outline (2) Lecture Two Energy storage with hydrogen Needs for large-scale energy storage Begrynnelse for storskala energilagring Possible role of hydrogen for large-scale energy storage Mulig rolle for hydrogen i storskala energilagring Hydrogen energy storage technologies Teknologier i hydrogen lagring Basic calculations Beregningsgrunnlag Outlook for real systems Mulig utvikling av reale systemer

4 4 Lecture ONE Hydrogen energikjeder

5 5 Why hydrogen energy? Hydrogen energy is complementary to and compatible with electricity as an energy carrier by use of highly efficient conversion technologies (fuel cells). Next to electricity, hydrogen can introduce renewable energy into the transport sector with added value (as compared to fossil energies today) Hydrogen can be used to store large amounts of renewable electricity for fluctuating loads levelling (e.g. in underground salt caverns) Combining both uses synergetically, hydrogen can be more economic and offer other options than electricity (e.g. high range for vehicles) Elektrolyse

6 6 Renewable Nuclear CO Electricity 2 free Fossil fuels Feedstock transport Feedstock Production Theory for energy chain calculations Methodology - Possible Pathways NG - Production / Purification/ Compression Residual oil from refinery By-product (chemical/ refinery) Coal (extraction/ transport) Electricity mix NG - Production / Purification/ Compression Coal (extraction/ transport) Fuel extraction & fabrication Solar thermal concentrators REN electricity (regional) Large central renew. plant (central) Biomass collection, treatment & transport Biomass - Cultivation and treatment plant (e.g green algae) Hydrogen import via LH 2 tankship HP pipeline HV/MV distribution HP pipeline MV distribution HV/MV distribution Hydrogen production SMR POX Gasification Electrolysis SMR Gasification CO 2 sequestr. HT production process Thermochemical process Electrolysis Gasification Photo-biological process Hydrogen transport CGH 2 transport pipeline LH 2 HP transport hydrogen pipeline Local hydrogen pipeline CGH 2 regional/local pipeline LH 2 truck transport until 2010 End-use SMR (on site) CGH 2 CGH 2 fuelling Electrolysis (on-site) from 2010 to 2030 from 2030 to 2050 F U E L L I N G S T A T I O N S T A T I O N A R Y U S E

7 7 Considerations for energy chain comparison Process and energy chain efficiency [kwh energy input /kwh H2 ] Thermal efficiency alone is no basis for an assessment of energy chains, specifically if comparing fossil and renewable energy sources. E.g. hydrogen from NG steam reforming with hydrogen from wind electrolysis have approximately the same efficiency, but wind hydrogen has to be preferred for sustainability reasons. Global emissions (GHG*, i.e. CO 2 ) [g CO2 /kwh H2 ] and local pollutants (e.g. particulates**) Spec. emissions can be compared directly for total energy chains. Final hydrogen costs [ /kwh] Spec. H 2 supply costs can be compared directly for individual chains. Exogenuous analysis e.g. energy resources/potentials, land area utilization, TtW analysis * GHG emissions also include N 2 O, CH 4, CF 4, SF 6, HFC 134a ** air pollutants also include NO x, SO 2, CO, NMVOC, dust/pm

8 8 Typical hydrogen energy chain: CGH 2 from NG (EU-mix) NO X CH 4 CO 2 NO X CH 4 CO 2 Energy loss Energy loss Natural gas supply (EU-mix) Reformer (on site) NG H 2 H 2 compression CGH 2 Electricity Electricity Energy source Energy loss NO X CH 4 CO 2 Energy source Electricity supply (EU-mix) Electricity Energy loss

9 9 Theoretical considerations Simple energy chains are characterized by a) only one type of primary energy input, b) processes without feedback loops and c) no substitutes electricity NG onsite SMR hydrogen (e.g. 3 MPa) NG electricity Fuel cell CHP onsite SMR hydrogen (e.g. 3 MPa) a) several primary b) chain with c) chain with energy inputs feedback loop energy substitute Complex energy chains can contain any or a combination of the above. Only in simple energy chains straight forward efficiency calculation is possible. heat electricity (main product) Fuel cell heat (by-product) CHP substitution credit reference boiler heat (by-product)

10 10 [PJ/yr] Technical potential for hydrogen as vehicle fuel Here: from renewable electricity Rail Inland navigation Civil aviation Road transport PV 2) Solarthermal power stations Ocean power Geothermal 2) Wind onshore 2) Wind offshore 2) Fuel consumption min max min max (Transport 2002) 1) CGH Hydropower 2) LH 2 2 1) Source: IEA-Statistics ) still exploitable within the EU

11 11 GHG emission factors For the conversion of different greenhouse gases (GHG) to CO 2 equivalents the following conversion factors are typically being used [IPCC, 2001]: g CO2 equivalent per g CO 2 1 CH 4 23 N 2 O 296

12 12 Fuels investigated in Well-to-Wheels analysis Here: CONCAWE/EUCAR/JRC study Crude oil Natural gas (NG) Gasoline Diesel CNG Methanol DME FT diesel CGH 2, LH 2 Electricity (renewable) CGH 2, LH 2 Power trains - conventional (ICE) - advanced conventional - (plug-in) hybrids - battery electric - fuel cells Electricity (fossil, nuclear) CGH 2, LH 2 Biomass (lignocellulosic biomass) CGH 2, LH 2 Methanol DME Ethanol FT Diesel Biomass (Sugar beet, wheat) Ethanol Biomasse (oilseeds) Biogas FAME FAEE Compressed methane gas (CMG)

13 13 Fuel parameters Density LHV CO 2 kg/l MJ/kg MJ/l g/mj Gasoline Diesel Naphtha Ethanol FAME (biodiesel) FT diesel Methanol DME CNG Hydrogen Sources: CONCAWE/EUCAR/JRC, LBST

14 14 Powertrains fuel consumption [MJ] and [l gasoline equivalent /100 km] Non-hybrid Hybrid MJ/km l GE /100 km MJ/km l GE /100 km PISI DISI Gasoline FPFC Diesel DICI DPF Diesel FPFC Naphta FPFC LPG PISI CNG PISI dedicated Ethanol PISI Ethanol DISI Methanol FPFC DME DISI CGH 2 PISI CGH 2 FC LH 2 PISI LH 2 FC Source: CONCAWE/EUCAR/JRC, Reference vehicle: Volkswagen Golf DISI direct injection spark ignition PISI pilot injction spark ignition FPFC fuel processor fuel cell

15 15 Calculation of energy chains An example Task Calculate a 1 st order approximation for the total WtW energy demand for the following 2 H 2 supply chains (basis LHV): a) alkaline water-electrolysis (output pressure ~3 MPa) multi-stage compression to ~45 MPa at fuelling station (to provide 35 MPa in the vehicle tank) fuel cell vehicle (assuming New European Driving Cycle). The electricity is derived from hydropower (efficiency = 100% by definition because renewable). b) central natural gas steam reformer (output ~3 MPa) hydrogen liquefaction liquid hydrogen transport liquid hydrogen fuelling station internal combustion engine vehicle (assuming New European Driving Cycle). Using the typical electricity consumption for electrolysis (1.54 kwh el /kwh H2 ), the typical electricity consumption for hydrogen compression from 2 to 45 MPa (0.06 kwh el /kwh H2 ), the typical NG consumption of a large scale SMR (1.4 kwh NG /kwh H2 ), the typical electricity consumption for hydrogen liquefaction (0.3 kwh el /kwh H2 ), the typical fuel consumption of a FC vehicle (0.3 kwh H2 /km) and an ICE car (0.6 kwh H2 /km). The fuel demand for truck transport can be neglected. The electricty requirement for the hydrogen liquefaction is met by a CCGT (electricitiy generation efficiency: 55%).

16 16 Calculation of energy chains An example Solution Η total a) = (1.54 kwh el /kwh H kwh el /kwh H2 )*0.3 kwh H2 /km = 0.48 kwh el /km Η total b) = (1.4 kwh NG /kwh H kwh el /kwh H2 * (1/0.55) kwh NG /kwh el )*0.6 kwh H2 /km = 1.17 kwh NG /km

17 17 Liquid hydrogen (LH 2 ) via electrolysis Electricity kwh Electrolysis Water Hydrogen η WC = 100 % kwh Liquefaction kwh (average delivery distance:300 km) Diesel LH 2 trailer Distribution kwh kwh (LHV) η = 1 = 54 % This is only a virtual efficiency! LH 2 η 54 % (LHV)

18 18 Electricity-based compressed hydrogen (CGH 2 ) η WC = 100 % Compressed hydrogen from renewable electricity Example: Wind Power Electricity Electrolysis Water Hydrogen Concept for a CGH 2 -Refueling Station (Hydrogen Systems) Compression η 60 % (LHV) CGH 2 (for 70 MPa vehicle tanks)

19 19 CGH 2 from natural gas via onsite steam reforming Gas turbine Gas turbine Mechanical work Mechanical work NG extraction and processing NG NG transport (4000 km) NG HP pipeline (500 km) NG MP pipeline (10 km) NG onsite SMR H 2 CGH 2 filling station CGH 2 Electricity EU power plant mix Electricity distribution ( kv) Electricity distribution (10-20 kv) Electricity distribution (0.4 kv) Source: HyWays, 2005

20 20 Norwegian hydrogen energy chains (selected) European Hydrogen Roadmap Project HyWays Source: HyWays, 2005

21 21 GHG emissions Norway WtT and StU European Hydrogen Roadmap Project HyWays Selected pathways Feedstock production Feedstock transportation H2 production H2 liquefaction H2 transport to EU H2 distribution Filling station GHGs [g CO 2 equivalent/kwh] CGH2-LWE-Nord Pool CGH2-LWE-Wind CGH2-SMR* LH2-SMR** LH2-SMR*** CGH2-SMR* export LH2-SMR** export CGH2-SMR (regional) HCNG / SMR* Elec-Wind-H2-FC Elec-Wind-H2-ICE CGH2-by-product (ref = NG) CGH2-by-product (ref = NG)**** CGH2-by-product (ref = el) LH2-by-product (ref = NG) LH2-by-product (ref = el) CGH2-WW CGH2-LWE-Wind (islands) 0 Source: HyWays, 2005 * with CO 2 capture and sequestration ** with CO 2 capture and sequestration, H 2 liquefaction with NG fueled CCGT ***with CO 2 capture and sequestration, H 2 liquefaction with H 2 fueled CCGT **** trucked CGH 2

22 22 GHG emissions for passenger cars in Norway European Hydrogen Roadmap Project HyWays Vehicle operation Filling station H2 tansport and distribution H2 liquefaction H2 production Feedstock transportation Feedstock production * with CO 2 capture and sequestration ** with CO 2 capture and sequestration, H 2 liquefaction with NG fueled CCGT ***with CO 2 capture and sequestration, H 2 liquefaction with H 2 fueled CCGT **** trucked CGH 2 Gasoline ICE (reference) Diesel ICE (reference) CGG2-FC / LWE-Nord Pool CGG2-ICE / LWE-Nord Pool CGG2-FC / LWE-Wind CGG2-ICE / LWE-Wind CGH2-FC / SMR* LH2-FC / SMR** CGH2-ICE / SMR* LH2-ICE / SMR** LH2-FC / SMR*** LH2-ICE / SMR*** CGH2-FC / SMR* export CGH2-ICE / SMR* export CGH2-FC / SMR (regional) CGH2-ICE / SMR (regional) HCNG ICE / SMR* CGH2-FC / by-product (ref = NG) CGH2-FC / by-product (ref = NG)**** CGH2-FC / by-product (ref = el) LH2-FC / by-product (ref = NG) CGH2-ICE / by-product (ref NG) CGH2-ICE / by-product (ref = NG)**** CGH2-ICE / by-product (ref = el) LH2-ICE / by-product (ref = NG) CGH2-FC / WW CGH2-ICE / WW CGH2-FC / LWE-Wind (islands) CGH2-ICE / LWE-Wind (islands) Source: HyWays, ) CONCAWE/EUCAR/JRC 2003 non-hybrid vehicles! Fuel consumption vehicles 1) FC: 0.26 kwh/km H 2 ICE: 0.47 kwh/km HCNG-ICE: 0.54 kwh/km Gasoline-ICE: 0.52 kwh/km Diesel-ICE: 0.50 kwh/km GHGs [g CO 2 equivalent/km]

23 23 Hydrogen (and electricity) supply costs for Norway European Hydrogen Roadmap Project HyWays CONCAWE/EUCAR/JRC 2003 (crude oil price: 25 US$/bbl) Selected pathways * with CO 2 capture and sequestration Tax Costs [EUR/kWh] Sept 2004 w/o tax ** with CO 2 capture and sequestration, H 2 liquefaction with NG fueled CCGT ***with CO 2 capture and sequestration, H 2 liquefaction with H 2 fueled CCGT **** trucked CGH2 Gasoline (reference) Diesel (reference) CGH2-LWE-Nordpool CGH2-LWE-Windpower CGH2-SMR* LH2-SMR** LH2-SMR*** CGH2-SMR* export LH2-SMR** export CGH2-SMR (regional) HCNG SMR* Elec-Wind-H2-FC Elec-Wind-H2-ICE CGH2-by-product (ref = NG) CGH2-by-product (ref = NG)**** CGH2-by-product (ref = el) LH2-by-product (ref = NG) LH2-by-product (ref = el) CGH2-WW CGH2-LWE-Wind (islands) Source: HyWays, 2005

24 24 Emissions and costs in comparison CO 2 -equivalent emissions/fuel costs based on km driven CO 2 -equivalent [g/km] W/o tax CGH 2 (NG) Gasoline/Diesel FT-Diesel (res. wood) EtOH (res. wood) MeOH (res. wood) EtOH (Sugar beet) RME 0 0,03 0,06 0,09 CGH 2 (res. wood) 100 US$/barrel (w/o tax) LH 2 (res. wood) CGH 2 (Wind) Fuel costs [EUR/km] CMG (biogas) With tax Rape seed oil FT-Diesel (SOT) LH 2 (Wind) LH 2 (SOT) CGH 2, LH 2 : FC Ethanol, Methanol: FPFC* Diesel, RME, Rape seed oil, FT-Diesel**: ICE (Diesel) Gasoline, CMG: ICE (Otto) *FPFC fuel processor FC **FT Fischer-Tropsch Source: LBST, 2003 (based on TES and GM-WtW-data; oil price ~30 US$/bbl)

25 25 Lecture TWO Energilagring med hydrogen

26 26 Relevant hydrogen storage tasks Vehicle onboard storage Compressed (ambient T; 25, 30 and 70 MPa) As liquid (20.4 K; MPa) Cryo-compressed ( K; MPa) Adsorbed ( K; ambient p) Absorbed (77 K; MPa) Transport and distribution of hydrogen Compressed (ambient T; MPa As liquid (20.4 K; MPa) Stationary bulk storage In underground salt caverns: compressed (ambient T; 7 21 MPa) In pressure bundles, e.g. at fuelling station (ambient T; MPa) In liquid tanks (20.4 K; MPa)

27 27 Hydrogen in fluctuating REN electricity systems electricity or hydrogen Source: Siemens, StatoilHydro, CEP, KBB UT, Proton Motor

28 28 Hydrogen in fluctuating REN electricity systems Expected capacity build-up Germany solar Fluctuating & non-dispatchable resources (~22 TWh/a) wind Fluctuating & non-dispatchable resources (~142 TWh/a) Source: BMU Leitstudie 2008 In 2030 fluctuating resources amount to ~164 TWh (~3 times the value of 2007 / ~30% of total expected power generation of 560 TWh)

29 29 Hydrogen in fluctuating REN electricity systems Possible 10 day production versus end-use profile [MW] Overrun Sources: E.ON, LBST Gap Mrz 17 Mrz 18 Mrz 19 Mrz 20 Mrz 21 Mrz 22 Mrz 23 Mrz 24 Mrz 25 Mrz 26 Mrz 27 Mrz wind power 2007 estimated wind power 2030 (3 x 2007) load

30 [MW] Hydrogen in fluctuating REN electricity systems Energy storage tasks and comparision of possible technical solutions Hydrogen salt cavern 734 GWh Σ Pumped Hydro Germany 40 GWh Sources: E.ON, LBST Pumped Hydro Goldisthal 8.48 GWh CAES Huntorf 0.66 GWh Charging Discharging Mrz 17 Mrz 18 Mrz 19 Mrz 20 Mrz 21 Mrz 22 Mrz 23 Mrz 24 Mrz 25 Mrz 26 Mrz 27 Mrz wind power 2007 estimated wind power 2030 (3 x 2007) load

31 31 Hydrogen in fluctuating REN electricity systems Energy storage tasks and comparision of possible technical solutions [MW] GWh 16 Mrz 17 Mrz 18 Mrz 19 Mrz 20 Mrz 21 Mrz 22 Mrz 23 Mrz 24 Mrz 25 Mrz 26 Mrz 27 Mrz wind power 2007 estimated wind power 2030 (3 x 2007) load 734 GWh storage capacity requires m 3 water basin (pumped hydro) 86 x Goldisthal or m³ cavern volume (AA-CAES) x Huntorf or m³ cavern volume (hydrogen) ~1,2 x cavern field Etzel ~0,5 x cavern field Nüttermoor (both used for NG)

32 32 Considerations for H 2 storage in salt caverns Hydrogen underground storage then of highest relevance if location of hydrogen production and usable salt formations coincide This is the case in i.e. Northern Germany, Denmark, the UK, the Netherlands, Portugal, Spain and Texas as well as North Dakota Hydrogen underground storage schemes can have massive influence on build-up of hydrogen supply infrastructure as a vehicle fuel

33 33 Underground salt formations worldwide

34 34 H 2 supply and distribution infrastructure Germany Stepwise build-up of infrastructure, starting from densely population agglomerations During transition phase (until 2030) distribution of centrally produced liquid hydrogen by trailer to fuelling station dominates (integration of e.g. offshore wind and by-product hydrogen) Growing demand will require mostly pipeline distribution, incorporating central underground storage Regional relevance of hydrogen on-site production from natural gas, biomass and electrolysis Hydrogen transport Frankfurt Hamburg Berlin Pipeline percentage 2030 ca. 20% 2050 ca. 80% München Scenario 2030 moderate Source: GermanHy, June 2008

35 35 Underground gas storage options

36 36 H 2 underground storage considerations H 2 underground storage in rock caverns impractical due to high losses through porous rock formations H 2 underground storage in aquifers possible but with higher losses due to porous rock formations H 2 underground storage in salt caverns more economical in operation (higher pressure swing and comparatively smaller hydrogen inventory) Geologic formations for underground storage in salt caverns less frequent worldwide Storage depth depends on geologic formation Storage options: Gas compression or brine pumping

37 37 Existing H 2 storage underground salt caverns H 2 caverns: Sabic Petrochemicals, Teesside, UK 3 caverns with 70,000 m³ each 45 bar constant pressure (brine pumping) 370 m depth

38 38 Existing H 2 storage underground salt caverns H 2 pipelines und H 2 caverns: Texas, USA (pressure cycling) Clement Dome Praxair Mont Belvieu Air Liquide Moss Bluff ConocoPhilipps Air Liquide storage under development

39 39 Energy chain with H2 underground storage Hydrogen compression Water electrolysis well head of a hydrogen cavern LH2- trailer (54m²): Gardner/Linde Source: ConocoPhillips Hydrogen gas pipeline (Offshore) wind power

40 40 Basic calculations Energy contents in cavern Maximum energy contents in cavern = energy of hydrogen at max. operating pressure Energy of hydrogen at max. operating pressure = Vcav ρ H 2( pop, max ) Espec. H 2 [ kwhh 2] with Espec. H 2 = kwh / kg and polynomial approximation of real gas behaviour of hydrogen 3 2 a ( pop,max ) b ( pop,max ) + c pop,max + d) ρ H 2 ( pop,max ) = [ kg / l] if p in [ bar] 1,000 with a = ; b = ; c = ; d = Energy of hydrogen inventory = energy contents of hydrogen at min. operating pressure Usable energy contents in cavern = V cav E ( ρ H 2 ( pop,max ) ρ H 2 ( p, min )) spec. H 2 op

41 41 Basic calculations Energy for compression E with pressure ratio per stage (assuming equal ratios for all stages) p p x, out x. in = p p max min 1 s Electric power consumption for compression P comp κ 1 px, out κ κ, isentr. = 1 Ru in IC p x, in 1 κ 3 [ kwh ] E 1 3 Nm comp = in / el, Nm el ηcompr ηel 3,600 22,4 with η compr = 0.75 and η el = 0.90 or P 3 el, Nm Pel, kwh = in kwhel / kwh H 3 [ ] 2 H 2 [ T + T ( s 1) ] in [ J / mol]

42 42 General considerations of H 2 bulk storage Hydrogen bulk storage schemes can have major impact on hydrogen fuel supply and transport/distribution schemes Approach to hydrogen bulk storage depends on region and traditions Use of hydrogen for seasonal REN energy storage has only recently gained momentum, considered by countries with industrial experience (UK), natural gas production (E, NL) and/or utility industry with know-how in underground natural gas storage (D) Use of hydrogen as transport fuel has mostly been pushed by automobile industry for several years already (D) Possible synergies of dual use for energy storage and storage of transport fuel or in industry only partially understood, detailed analysis pending Precious underground salt caverns should be used for energy gas storage with high continuous use (NG, H 2 ) instead of one-time deposition of CO 2 Underground storage of hydrogen (specifically in salt caverns) offers the opportunity to store hydrogen in bulk with high capacity and low losses, limiting international cooperation to specific regions