Jason Amiri on LinkedIn: Solid Oxide Electrolysis Cell (SOEC) for Hydrogen Production 🟦 1) Solid… | 42 comments (2024)

Ammonia's role in decarbonised Industry🟦 1- Ammonia is a crucial global commodity, with 80% used for nitrogen-based fertilizers and 20% for various industrial applications like plastics, explosives, and synthetic fibers.🟦 2- New application of clean ammonia as a carbon-free energy carrier:- Clean fuel for shipping vessels,- Direct co-firing of power plants with ammonia,- Ammonia as hydrogen carrier that can be converted back into hydrogen and nitrogen (ammonia cracking).🟦 3- Renewable and low carbon ammonia colours:- Renewable 'green' ammonia → made of renewable hydrogen- 'blue' ammonia → made of ATR or SMR + CCUS- 'turquoise ammonia' → made of 'turquoise hydrogen'🟦 4- Ammonia pipelinesAmmonia has been mainly transported by pipelines since the 1960s, with over 7,600 kilometres of pipelines. In the Netherlands, a 3.5-kilometre pipeline operated by OCI transports ammonia from an inland harbour in Stein to the Chemelot site. In its 70 years of existence, the pipeline has had 11 accidents, with no human fatalities.🟦 5- Ammonia crackingAn ammonia cracker can convert ammonia to hydrogen and nitrogen, with a hydrogen production capacity of 10 to 500 tonnes per day. A feasibility study showed that a central large-scale cracker is more cost-effective than a decentralized approach.- Ammonia Cracker Catalyst = oxide-supported Ni catalysts, Fe-Co catalysts, or oxide-supported Ru catalysts- Temperature = 600-900°C- Pressure = 10 to 80 bars- Hydrogen purification = using pressure swing adsorption (PSA)🟦 6- Ammonia as shipping fuel (bunkering)Ammonia is being considered to decarbonize international shipping, with new ships being built with 'ammonia-ready' fuel storage. Two and four-stroke ammonia-fed maritime engines are being developed (MAN ES and Wärtsilä) and are expected to be commercialized by 2024 or 2025. Mitigation measures for emissions include exhaust gas recycling and a deNOx system.🟦 7- Ammonia as fuel for gas turbinesAmmonia can be used to replace natural gas in gas turbines for electricity generation. It can be used as a direct fuel or partially cracked to hydrogen and nitrogen. The main challenge is NOx generation during combustion. Mitsubishi Heavy Industries aims to commercialize this technology by 2025. Large-scale gas turbines may require 30% ammonia cracking for optimal performance, using exhaust heat to improve energy efficiency.🟦 8- Ammonia fired powerplantAmmonia can replace coal and other hydrocarbons in thermal power stations for steam generation boilers or to generate high temperature heat. JERA from Japan plans to operate one of its 1 GW coal-fired power plants with 20% ammonia co-feed in 2024. The Netherlands aims to prohibit the use of coal as fuel by 2030, and ammonia could be used for power generation beyond that.Source: see attached imagesThis post reflects my personal knowledge and is for educational purposes only. 👇What are mitigations for emissions from ammonia combustion?

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Innovative methods for hydrogen production: "SunHydrogen's PAH", "Solhyd Hydrogen panels" and "H2PRO E-TAC"🟥 a. SunHydrogen's PAH🟦 1) SunHydrogen's "Photoelectrosynthetically Active Heterostructures" (PAH) nanoparticles are microscopic machines powered by solar energy that split water at the molecular level, extracting clean hydrogen energy. These nanoparticles are bundled into solar hydrogen panels, enabling mass production for use in localized or large-scale settings.Sunlight + Water = Renewable "Hydrogen"🟦 2) Traditional electrolysis processes have high operating costs due to extensive power electronics, hindering widespread implementation. However, PAH nanoparticle technology uses sunlight to generate hydrogen without relying on grid power or costly electronics. Unlike traditional electrolyzers, PAH's technology can use water of varying purities. 🟦 3) SunHydrogen's PAH CostPAH solution has the potential to make green hydrogen competitive with natural gas hydrogen by aiming for a cost of "$2.50/kg", effectively displacing fossil fuels.🟥 b. Solhyd Hydrogen panels 🟦 4) What is Photoelectrolysis?"Photoelectrolysis" is a technique that utilises light to make hydrogen and oxygen.light + 2(H₂O) → O₂ + 2(H₂) 🟦 5) What is a hydrogen panel?"Solhyd Hydrogen panels" are modules that utilise solar energy to produce hydrogen gas.🟦 6) How does the hydrogen panel work?The panel absorbs and stores moisture from the airflow during the night, approximately "250 ml daily". Solar energy is then used during the day to convert the stored moisture into hydrogen and oxygen gases. A PV module also converts solar energy into electricity to split water. A membrane prevents the gases from mixing.🟦 7) How much hydrogen can be created by hydrogen panels?- One hydrogen panel → "6-12 kg" hydrogen annually;- A 1000 m2 roof → "2-4 tons" of hydrogen annually;- Smaller roof with 20 hydrogen panels → "120-240 kg" annually.🟥 c. "H2PRO Electrochemical, Thermally Activated Chemical" (E-TAC) hydrogen production🟦 8) How E-TAC electrolysis worksSimilar to other hydrogen electrolyzers, E-TAC uses electricity to divide water into hydrogen and oxygen. However, unlike conventional electrolysis, hydrogen and oxygen are produced separately in two separate stages: the Electrochemical (E) and thermally Activated Chemical (TAC) steps.🟦 9) Lower material and assembly costs:The technology separates hydrogen and oxygen reactions, eliminating the need for a costly membrane in electrolyzers. It also supports high-pressure hydrogen production, reducing the need for compressors and overall costs.🟦 10) High efficiency;E-TAC hydrogen electrolysers generate oxygen thermally, so there is no power loss. The result is high energy efficiency (98.7% HHV, compared to ~75% HHV in conventional hydrogen electrolyzers).This post reflects my personal knowledge and is for educational purposes only.👇 Can we produce hydrogen from "air" instead of "water"?

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Understanding Proton Exchange Membrane (PEM) Electrolyzers🟦 1) PEM Hydrogen Electrolyzer Reactions:Reaction at Cathode: (2H+) + (2e−)→ H₂Reaction at Anode: H₂O → (2H+) + ½ O₂ + 2e−🟦 2) PEM Hydrogen Electrolyzer advantages- High efficiency,- Compact design,- High power densities,- Fast cold start-up time,- Quick load-changing capabilities,- Best for High-purity hydrogen needs,- Mature technology and scaled up to the MW level,- Best for intermittent power and renewable energy integration projects.🟦 3) PEM Hydrogen Electrolyzer disadvantages- Using expensive materials such as titanium and critical platinum group metals (PGM) on the cell level,- Higher capital cost,- Sensitive to impurities,- Requires high-purity water.🟦 4) Proton exchange membrane (PEM) electrolyzer spec (Plug Power)Plug Power EX-4250D System Specifications- Stack Power Consumption → Up to 10MW- Voltage & Frequency → 6 to 34.5 kV (USA) 11 to 33 kV (EU)- Water Consumption = 10.23 liters per kg of H2 produced- Volume = 1,989 Nm3 /h- Mass = 4,250 kg/day- Purity → Up to 99.999% - Pressure = 40 barg / 580 psig (w/o compressor)- Start-Up Time = 60 sec ramp-up time- Average Stack Efficiency = 49.9 kWh / kg- Load Following → 60 seconds from min. to max. (ramp up) ≤15 seconds from max. to min. (ramp down)- Installed Footprint = 117.2m2 / 1,280 ft2- Ambient Temperature → 5°C to +40°C - Compliance → ISO 22734, NFPA 2, CE 🟦 5) DOE 2022 StatusStack:Platinum Group Metal Content (both electrodes combined) = 3 mg/cm2(0.8 g/kW)Performance = 2.0 A/cm2 @ 1.9 V/cellElectrical Efficiency = 51 kWh/kg H₂ (65% LHV) Average Degradation Rate= 4.8 (0.25) mV/kh (%/1,000 h)Lifetime= 40,000 Operation hoursCapital Cost= 450 $/kWSystem:Energy Efficiency = 55 kWh/kg H2 (61% LHV)Uninstalled Capital Cost = 1,000 $/kWH2Production Cost→ 3 $/kg H₂🟦 6) DOE Ultimate TargetStack:Platinum Group Metal Content (both electrodes combined) = 0.125 mg/cm2(0.03 g/kW)Performance = 3.0 A/cm2 @ 1.6 V/cellElectrical Efficiency = 43 kWh/kg H₂ (77% LHV) Average Degradation Rate= 2.0 (0.13) mV/kh (%/1,000 h)Lifetime= 80,000 Operation hoursCapital Cost= 50 $/kWSystem:Energy Efficiency = 46 kWh/kg H2 (72% LHV) Uninstalled Capital Cost = 150 $/kWH2Production Cost= 1 $/kg H₂🟦 7) Proton Exchange Membrane (PEM) Electrolyzer OEMs:1- ITM Power2- PLUG POWER3- Siemens Energy4- H-TEC SYSTEMS5- Hystar6- IMI Process Automation7- Rolls-Royce & Hoeller8- iGAS Energy9- Kyros turnkey electrolyzer10- H2GREEM11- Ohmium PEM12- Bosch13- co*ckERILL JINGLI14- Fortescue15- AHES16- H2next17- HITACHI ZOSEN18- KOBELCO19- Cummins - Hydrogenics20- NEL Hydrogen21- HyGreen Energy22- China Huadian Corporation23- Beijing Hydrogenergy Technologies Co.24- Shuangliang Group25- Hydrogen Innovation GmbH26- EnduaThis post reflects my personal knowledge and is for educational purposes only. 👇Can you name other PEM electrolyzer OEMs?

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Hydrogen Production: SMR + CCUS Process Explained🟦 1) "Steam methane reforming"A hydrocarbon feedstock can be converted into a synthesis gas (syngas) using a steam methane reformer (SMR). This process involves reacting the feedstock with steam in nickel-based catalyst inside metal tubes. The heat required for the reaction is generated by burning fuel in a firebox outside the tubes.🟦 2) "Sulfur Polishing"Sulfur can poison the reformer catalysts, so sulfur removal prior to the prereformer is vital. A zinc oxide sulfur guard bed is used to remove 98 percent of the CH4S in the natural gas, resulting in a maximum sulfur content of 0.1 ppm exiting the sulfur guard bed.Design condition:Inlet: 70,000 kg/hr3.0 MPa370 °C🟦 3) PrereformerThe desulfurized natural gas feedstock is preheated to 500 °C before being mixed with steam and sent to the "prereformer." There, C₂+ hydrocarbons reform to reduce carbon deposition on the downstream catalyst and improve product recovery.The function of prereformer is to ensure the effluent stream has less than 500 ppm of C₂+ hydrocarbons. Design condition:NG In: 70,000 kg/hr 2.9 MPa500 °C Steam In: 195,000 kg/hr 3.1 MPa399 °C 🟦 4) Steam Methane ReformerPartially reformed gas and steam leaving the prereformer enter the "primary steam methane reformer". The mixture is reacted over a nickel-based catalyst held inside high alloy steel tubes. CH₄ + H₂O ↔ CO + 3H₂; Δ𝐻°rxn = 205.8 kJ/molThe metallurgy of the tubes restricts the reaction to 760-925 °C.Design condition:Syngas Production265,000 kg/hr 2.8 MPa 871 °C 🟦 5) "Water Gas Shift Reactors"The raw syngas leaving the reforming are transformed into CO₂ and H₂-rich syngas to improve hydrogen yield and maximize the CO₂ separation that can be performed on the high-pressure syngas stream. CO is transformed to CO₂ by reacting with steam over a catalyst bed. In the WGS design, intercooling is used between stages and the recovered heat is utilised to generate steam for use elsewhere in the plant to offset some of this loss. CO + H₂O ↔ CO₂ + H₂; Δ𝐻°rxn = −41.2 kJ/molDesign condition:88,000 kg/hr 204 °C 2.8 MPa 🟦 6) "Pressure Swing Adsorber" (PSA)The PSA unit purifies the syngas into highly pure hydrogen. As a byproduct, an H₂-rich off-gas stream is produced, which is sent to the primary reformer furnace. Design condition:Hydrogen20,126 kg/hr 38 °C 2.4 MPa 🟦 7) Hydrogen CompressorThe hydrogen compressor is an "integrally geared", "multi-stage" "centrifugal" compressor. To control the temperature rise, interstage cooling to 30 °C is needed. The high-purity hydrogen from the PSA is compressed to a pipeline-ready pressure of 6.48 MPa.🟦 8) CO2 capture:- "Pre-combustion"Refrigerated methyl diethanolamine (MDEA)- "Post-combustion"Cansolv system✅ Source: see attached imagesThis post reflects my personal knowledge and is for educational purposes only. 👇What is the final product of the PSA unit?

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61 Hydrogen Codes, Standards, Guidelines and Practices of hydrogen Production, Storage, Transport, Safety and Fuel Cells for your reference🟦 a- Hydrogen Generation1) ISO 16110 Hydrogen generators using fuel processing technologies 2) ISO 22734 Hydrogen generators using water electrolysis - Industrial, commercial, and residential applications3) ISO 15649 Industrial - Piping4) CGA H-10 Combustion Safety For Steam Reformer Operation5) EIGA DOC 15 Gaseous Hydrogen Installations6) EIGA DOC 246 Small-Scale Hydrogen Production7) EIGA DOC 211 Hydrogen Vent Systems8) EIGA DOC 210 Hydrogen pressure swing adsorber (PSA) Mechanical Integrity9) EIGA DOC 185 EIGA Safe start up and shutdown practices for steam reformers10) EIGA DOC 155 Best available techniques for H2 production by SMR🟦 b- Hydrogen storage and transport 11) ASME B31.12 Hydrogen Piping and Pipeline12) ASME Section VIII Rules for Construction of Pressure Vessels13) ASME Section VIII Division 3, Article KD-1014) ISO 19881 Land vehicle fuel containers15) ISO 9809 Gas cylinders - Steel16) ISO 7866 Gas cylinders - Aluminium17) ISO 13985 Liquid Hydrogen fuel tanks18) CGA G-5 series Hydrogen19) CGA H-3 Cryogenic Hydrogen Storage20) EIGA Doc 121 Hydrogen Pipeline21) ISO 16111 Reversible metal hydride hydrogen storage22) ASME B31.3 Process Piping23) ASME STP/PT-005 High-pressure composite hydrogen tanks24) CGA H-5 Publication Guides Safe Design, Installation, and Use of Bulk Hydrogen Supply Systems25) CGA H-7 Standard Procedures for Hydrogen Supply Systems26) EIGA TB 42 Welded Vessels and Hydrogen Compatibility27) EIGA DOC 247 Hydrogen Distribution-Storage28) EIGA DOC 235 Gas Pipeline Integrity29) EIGA DOC 171 Underground Storage of Hydrogen30) EIGA DOC 10207 Safety Audit / Assessment Tool – hydrogen Compression, Purification and Cylinder Filling31) EIGA DOC 100 Hydrogen Cylinders and Vessels🟦 c- Hydrogen Compressors, Pumps and Turbines32) API STD 618 Reciprocating Compressors33) API STD 692 Dry Gas Sealing Systems for Axial, Centrifugal, and Rotary Screw Compressors and Expanders34) API Standard 617 Axial and Centrifugal Compressors and Expander-compressors35) EIGA DOC 244 Reciprocating Cryogenic Pumps for Hydrogen and LNG🟦 d- Hydrogen fuel cells/ refuelling36) REGULATION (EC) No 79 - on type-approval of hydrogen-powered motor vehicles, and amending Directive 2007/46/EC37) UN Global Technical Regulation No. 13, Hydrogen and Fuel Cell Vehicle38) IEC 62282-3-100 Fuel cell - Safety 39) IEC 62282-3-300 Fuel cell - Installation40) DIN EN 17124 Hydrogen fuel - product specification and quality assurance for hydrogen PEM fuel cell41) CSA/ANSI HGV 4.10 Standard For Fittings In Compressed Gaseous Hydrogen Fuelling Stations✅ See comment section for number 42-61 hydrogen codes.This post reflects my personal knowledge and is for educational purposes only.👇 Have you used any other hydrogen specific code?

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Levelised Cost of Hydrogen (LCOH) Calculator✅ In this post, I compare two tools for calculating the "LCOH" in "Europe".🟦 1)"Umlaut & Agora Industry (2023)"This tool calculates the levelised cost of hydrogen and adjusts key system parameters such as electricity costs, discount rate, lifetime, specific energy consumption, and full load hours. It also breaks down major cost components and provides sensitivity analysis.Umlaut (2023) calculation is based on Fraunhofer formula (2018). Heating value: The "lower heating value (LHV)" is recommended for calculations involving efficiencies to ensure consistency and avoid errors arising from inconsistent use of the "higher heating value (HHV)" and LHV. In the literature we reviewed, efficiency data were primarily based on the LHV. HHV values are approximately 10% higher than LHV values.LCOH = (LHV/ŋₛᵧₛ,ₗₕᵥ) * {[ j*(1+j)ⁿ/((1+j)ⁿ-1)+ OPEX/100 ] *(CAPEX/𝜏)+ E}LCOH = levelised cost of hydrogen [€/kg H₂]LHV = lower heating value [kWh/kgH₂]i = discount rate [%]j= i/100n = lifetime [a]E = electricity costs [€/kWh]ηₛᵧₛ,ₗₕᵥ = system efficiency related to the LHV𝜏 = full load hours [h]OPEX = operational expenditures [% CAPEX/a]CAPEX = capital expenditures [€/kW] Result of the Calculation:Discount rate = 6 %Lifetime hydrogen electrolyzer system = 30 aLifetime stack (manufacturer's data) = 80000 hAnnuity factor = 0.073 -Specific energy consumption = 55.5 kWh/kg hydrogenEnergy consumption (pressure<30bar) = 57.9 kWh/kg hydrogenFull load hours = 4000 hCapacity factor = 0.457 -System pressure = 1 barCompressor efficiency = 80 %Electricity costs = 70 €/MWhO2 selling price = 0.05 €/kgO2Heat selling price = 40 €/MWhOPEX 3.00 % of CAPEX per yearCAPEX electrolyzer system 800.00 €/kWEPC = 30 % of CAPEX electrolyzer systemLifetime stack (calculated) = 20.0 aStack replacement costs = 30 % of CAPEX hydrogen electrolyzer systemCAPEX system without stack = 560.00 €/kWCompressor costs = 1000.00 €/kW compressorTotal CAPEX = 1202.01 €/kWLCOH = 5.84 €/kgH₂LCOH (incl. sale of heat and O2) = 4.45 €/kgH₂LCOH (LHV specific) = 0.18 €/kWhH₂,LHV 🟦 2) "European Hydrogen Observatory"The Levelised Cost of Hydrogen (LCOH) calculator enables the calculation of hydrogen production costs using low-temperature water electrolysis in EU27 countries, Norway, and the United Kingdom (UK). The calculator offers a choice of four electricity sources (Wholesale, PV, Onshore, or Offshore wind) for the calculation.I have used user-specified values as below to compare the European Hydrogen Observatory calculation with"Umlaut & Agora Industry (2023)", and the results are very close to each other:CAPEX = 1.21 Electricity = 2.89Other OPEX = 0.5Grid fees = 0.29Taxes = 0.87Subsidies = 0Total = 5.75 €/kgH2Source: see post imagesThis post reflects my personal knowledge and is for educational purposes only.👇 What method do you use to calculate the Levelised Cost of Hydrogen (LCOH)?

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Liquid Hydrogen Application Overview:🟦 1) Hydrogen can be stored as compressed gas, liquid hydrogen, hydrides, adsorbed hydrogen, and reformed fuels. Liquid hydrogen offers advantages including high hydrogen densities and purity, making it suitable for long-term storage, long-distance transportation, and economic efficiency.🟦 2) Physical properties of hydrogen:Lower heating value = 118.8 MJ/kgHigher heating value = 143 MJ/kgBoiling temperature at 1 atm = -253 °CMelting temperature = -259 °CDensity of gaseous hydrogen at 0 °C = 0.08987 kg/m3Density of liquid hydrogen at -253 °C = 70.85 kg/m3Density of solid hydrogen at -259 °C = 858 kg/m3Heat capacity of gaseous hydrogen at 0 °C = 14.3 kJ/kg. °CHeat capacity of liquid hydrogen at °256 °C = 8.1 kJ/kg. °CHeat capacity of solid hydrogen at °259.8 °C = 2.63 kJ/kg. °CLiquid-to-gas expansion ratio at atmospheric condition = 1:848 🟦 3) Liquid Hydrogen Boil-OffThe phenomenon of liquid hydrogen vaporising during storage is called boil-off, which results in energy and hydrogen loss. Factors affecting boil-off include thermal insulation, tank dimensions, and the hydrogen ratio. If the vaporised hydrogen is not released, the pressure inside the tank will increase.🟦 4) Liquid Hydrogen Boil-Off mitigation:- Isomer change acceleration from ortho- to para-hydrogen during liquefaction,- The surface-to-volume ratio minimization of the vessel (e.g. spherical vessel), - Vessel super insulation to reduce the heat transfer from the environment, - Cryocooler utilization. - A combination of liquid hydrogen storage vessels and metal hydrides, where metal hydride absorbs evaporated liquid hydrogen,- Cryocoolers and passive insulation have also been developed to minimize boiloff- Shielding the liquid hydrogen vessel wall using liquid nitrogen,- Reliquefying the liquid hydrogen boil-off where the liquefaction plant and liquid hydrogen storage vessel are close.- boil-off gas can be used for power generation and fuel for tankers and trucks.🟦 5) Liquid Hydrogen Standards:International Standardization Organization (ISO)ISO/TR 15916ISO 13984ISO 13985United Kingdom- Dangerous Substances and Explosive Atmosphere Regulations (DSEAR), - Control of Major Accident Hazard (COMAH), - Pressure Equipment Regulations (PER), - Carriage of Dangerous Goods (CDG) regulations.- ATEX 137 (Directive 99/92/EC)- ATEX 95 (Directive 94/9/EC)United States- NFPA 2- NFPA 55- OSHA Process and Safety Management (OSHA PSM) - EPA Risk Management Plan (EPA RMP) Guidance- CG G-5.4- CGA G-5.5- CGA P-28- CGA P-12 - CGA PS-17- CGA H-3- IFC 3005- IFC 2209.3- IFC 3203- IFC 3204 - IFC 3205- IFC 2204- IFC 2209- SAE AS6679- NFPA 30AChina- GB/T 34583 - GB/T 34584 - GB/T 29729 Source: see post imageThis post reflects my personal perspective and is for educational purposes only.👇 What other codes, standards or guidelines have you used for liquid hydrogen application?

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How can the hydrogen economy reduce climate change mitigation costs by 22%?🟦 1] The impacts of a changing climate are already evident. Achieving net zero by 2050 is crucial. Clean hydrogen with net-zero emissions is being explored as a viable option for energy storage and facilitating the transition of hard-to-abate sectors.🟦 2] clean hydrogen production is becoming more popular, but its expenses raise concerns about its ability to effectively support the energy system's transition. According to Wolfram et al., in their research published in One Earth, the incorporation of clean hydrogen into the global economy might lead to a reduction in energy transformation costs by as much as 22%, even if it accounts for only 9% of the final energy demand.🟦 3] Hydrogen production methods investigated:1 - biomass, grid electrolysis, 2- natural gas with and without CCS, 3- industrial decentralized electrolysis, 4- central electrolysis,5- central natural gas production, 6- bioenergy with CCS, 7- coal without CCS, 8- coal with CCS (future), 9- nuclear10- thermal splitting, 11- solar electrolysis, 12- wind electrolysis.🟦 4] Hydrogen transmission and distribution:- in the gaseous form via pipelines (including hydrogen compression),- in liquid form via trucks (including hydrogen liquefaction), - produced on-site at service stations and industrial manufacturing facilities.🟦 5] Hydrogen demand (highest hydrogen demand) in 2050, Relative marketshare of H2/ Absolute H2 demand:1. Transport energy use 17% /16 EJ (4.4 PWh),2. Long-distance shipping 46% /3.9 EJ (1.1 PWh),3. Freight rail 27% /0.8 EJ (0.2 PWh),4. Short-distance aviation 26% /1.9 EJ (0.5 PWh),5. Heavy freight trucks 19% /2.7 EJ (0.8PWh),6. Medium freight trucks 15% /2.0 EJ (0.6 PWh),7. Busses 13% /0.8 EJ (0.2 PWh),8. Passenger vehicles 11% /2.8 EJ (0.8 PWh),9. Short-distance shipping 6% /0.1 EJ (0.03 PWh),10. Industrial energy use 8% /22 EJ (6.1 PWh),11. Cement manufacturing 28% /2.5 EJ (0.7 PWh),12. Agricultural energy use 18% /1.3 EJ (0.4 PWh),13. Ammonia fertilizer production 14% /0.8 EJ (0.2 PWh),14. Construction energy use 12% /0.3 EJ (0.1 PWh),15. Iron and steel production 10% /3.0 EJ (0.8 PWh),16. Mining energy use 10% /0.3 EJ (0.1 PWh),🟦 6] Hydrogen iron and steel sectorend use:1) blast furnace, 2) blast furnace with CCS, 3) blast furnace CCS with hydrogen, 4) biomass-based, 5) electric arc furnace (EAF) with direct iron reduction (DRI), 6) EAF with DRI CCS, 7) hydrogen-based DRI, 8) EAF with scrap. 🟦 7] Non-energy costs of alternative mobile equipment relative to liquid-fueled technology- Battery electric = 1.49/2030, 1.3272040, 1.15/2050- Hydrogen = 1.18/2030, 1.14/2040, 1.10/2050Source: see post image This post reflects my personal knowledge and is for educational purposes only.👇 How does the existing infrastructure for natural gas pipelines translate to hydrogen use? Are there significant costs in adapting this infrastructure?

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