The advancement of electric aviation in unmanned aerial vehicles (UAVs) demands innovative energy storage systems that extend flight time while maintaining safety and efficiency. Hydrogen (H₂) fuel technologies are emerging as a leading solution, offering high energy density and safety benefits. This presentation focuses on Fuel Additives for Solid Hydrogen (FLASH) materials—an advanced alternative to compressed hydrogen gas. FLASH uses metal-borohydride-based materials activated thermally to store hydrogen in chemical bonds, enabling stable, ambient-condition storage with controlled on-demand release. This approach not only enhances safety but also significantly extends UAV flight endurance compared to batteries. FLASH systems have demonstrated the potential to achieve 7 wt% hydrogen content and 550 Wh/kg energy density, offering a promising, low-cost, drop-in replacement for current fuel cartridge technologies. By integrating FLASH, UAV platforms can benefit from increased operational range and reduced logistical burdens, marking a key step forward in sustainable electric aviation.

To combat climate change and reduce reliance on fossil fuels, the transportation sector is shifting toward sustainable, zero-emission solutions. Legislative mandates in many regions will soon require fleet operators to adopt low-carbon vehicles. Hydrogen fuel offers a compelling alternative due to its clean emissions, extended range, and fast refueling capabilities compared to other low-carbon options.

This project focuses on building a hydrogen refueling station in LaPorte, Texas, connected to a hydrogen pipeline to minimize costs and promote hydrogen as a viable fuel for large trucks. By leveraging pipeline infrastructure, Linde’s station will reduce hydrogen delivery costs and enhance environmental benefits, encouraging adoption among fleet operators, especially along the Texas-to-California freight corridor, one of the largest in the U.S.

Linde’s cutting-edge hydrogen production, compression, and fueling technologies will drive this initiative, showcasing the feasibility of pipeline-connected refueling stations. The project explores operational considerations, including optimizing infrastructure, maintaining hydrogen purity, designing the station layout, managing fleet growth, and expanding heavy-duty refueling capacity to meet rising demand.

Additionally, potential technology upgrades like liquid-to-liquid fueling for subcooled liquid hydrogen (sLH2) will be analyzed to further enhance efficiency. By addressing economic, logistical, and environmental challenges, Linde aims to accelerate the adoption of hydrogen as a clean fuel, providing a scalable model for zero-emission mobility and contributing to global climate goals.

This project positions hydrogen as a transformative solution for decarbonizing heavy-duty transportation while leveraging strategic infrastructure and innovative fueling technologies

Ammonia cracking is pivotal for the hydrogen economy and global clean energy trade, utilizing existing infrastructure for efficient energy transport. This process, essential for hydrogen release from ammonia, favors high temperatures and low pressure for effective conversion. Thus, high-performance catalysts, particularly nickel (Ni) and ruthenium (Ru) types, are crucial for optimizing ammonia cracking at lower temperatures and delivery pressures suitable for various applications.

Catalyst screening and application tests are vital to ensure the catalyst matches the process requirements and operates with maximum efficiency. Ammonia cracking is versatile, suitable for both centralized production for large-scale hydrogen distribution and decentralized systems for local consumption, catering to specific regional or industrial demands. As clean energy demand accelerates, ammonia cracking technology becomes increasingly significant for sustainable hydrogen production.

In this presentation, Evonik will describe the specifics of their highly active Ni and Ru catalysts, options to customize them to the specific process needs and how to match commercialization targets of ammonia cracking technology with reliable catalyst supplies.

Let EVONIK be your catalyst!

Hydrogen embrittlement poses a significant risk to the structural integrity of gas transmission pipelines when they are exposed to hydrogen or hydrogen-containing natural gas. This study focuses on developing a machine learning model to predict the Reduction of Area (RA). A comprehensive dataset was created by combining previously published tensile test data from the literature with our recent experimental data on X52, X60, and X70 steels under varying hydrogen concentrations.

Five supervised machine learning models were developed using carefully selected features representing gas composition, material characteristics, and pipeline operating conditions. The models demonstrated excellent predictive performance, closely matching observed RA values with high R² scores, indicating strong generalization capability. This close alignment validates the effectiveness of the models in estimating hydrogen-induced ductility degradation.

Additionally, a sensitivity analysis was conducted to evaluate the influence of key parameters, including partial pressure, yield strength, and oxygen content, on the predicted RA. The results confirmed that these variables have a significant impact on embrittlement behavior, providing insight into their role in the hydrogen embrittlement process.

By integrating high-quality experimental data with advanced modeling techniques, this work offers a reliable predictive framework for assessing pipeline steel performance in hydrogen environments. The findings can support the design and evaluation of hydrogen-compatible infrastructure, aiding the transition toward safer hydrogen-based energy systems.

At the 2023 AIChE Spring Meeting, ExxonMobil Technology and Engineering Company outlined the development and testing of a “proof-of-concept” burner for hydrogen combustion in steam cracking furnaces. Test furnace firing revealed acceptable heat distribution and attractive NOx emission characteristics.

This paper describes the steps taken and challenges overcome in translating the “proof-of-concept” burner into a commercial-furnace-ready burner.

Additional test firing data, and initial commercial furnace data, including NOx emissions on very-high-hydrogen and conventional fuels, will be provided.

In addition, the design concept of the pencil-flame burner (subject of the 2023 paper) has been translated to a floor-fired, flat-flame burner for applications with limited space between the furnace coils and side-walls.

Initial test data for this hydrogen-capable burner will be provided.

Matrix-stabilized combustion, also known as porous media combustion, is a burner technology in which chemical reactions are facilitated within the hollow pores of a solid lattice, generally fabricated using refractory alloys or high-temperature ceramics. Downstream of the flame, heat exchange from the hot combustion products to the solid matrix leads to the formation of a steep temperature gradient in the solid phase, leading to intense conductive and radiative heat recirculation towards the fresh reactants, and significantly enhancing the flame speed of the mixture. This allows us to stabilize flame at operating conditions that are usually challenging for flame stability, but beneficial for lowered pollutant emissions. In this talk, we will investigate the stabilization properties and pollutant emissions of premixed CH₄/H₂/air and NH₃/H₂/air flames in an interface-stabilized porous media burner. We show that the porous media burner is highly fuel flexible, stabilizing flames ranging from pure H₂/air to pure NH₃/air without modification. This is achieved with reduced emissions of nitric oxides emissions, well-below regulatory limits for H₂ operation, and at a level compatible with selective catalytic reduction for treatment of the NH₃-fueled burner's exhaust stream. We conclude by presenting current work to leverage additive manufacturing to enable high performance operation of these burners with non-premixed injector typically found in practical systems.

As California pursues ambitious decarbonization goals, understanding the potential role of hydrogen in the electric sector is critical. This research investigates the conditions under which hydrogen becomes a cost-effective resource for supporting deep emissions reductions in California’s electricity system. Specifically, we examine how hydrogen’s viability is influenced by cross-sector demand for green hydrogen, the commercial availability of hydrogen production technologies, and the development of transportation and storage infrastructure.

To evaluate these dynamics, we use RESOLVE, a publicly available capacity expansion model widely applied by the California Public Utilities Commission (CPUC) and other state agencies for long-term grid planning. We simulate multiple decarbonization scenarios through 2045, varying emissions caps and infrastructure assumptions to assess hydrogen’s competitiveness relative to other zero-carbon technologies.

Our findings suggest that under California’s current electric sector emissions target of 8 million metric tons (MMT) CO₂ by 2045, there is no economic incentive to invest in hydrogen infrastructure. However, in a more stringent policy scenario—achieving net-zero electric sector emissions (0 MMT) by 2045—hydrogen emerges as a valuable resource for grid balancing and reliability, particularly when paired with high renewable penetration and seasonal storage needs.

These results highlight the importance of aligning emissions targets with infrastructure and technology planning. While hydrogen is unlikely to play a major role under moderate decarbonization trajectories, it becomes a strategic asset under more aggressive climate goals, contingent on parallel progress in hydrogen production and delivery infrastructure.

Liquid hydrogen use as a fuel on launch vehicles has a long history owing to its high performance outweighing its challenges, including operational complexity, high boiloff rates, and material compatibility. Interest in liquid hydrogen applications now extends into space to include use as a coolant in reentry thermal protection systems, as a propellant in nuclear thermal propulsion, and for refueling chemical propulsion systems with in-situ resources. In all these applications the usage efficiency is a strong driver of operational cost and performance. Liquid hydrogen costs remain high, and a significant fraction (as much as 50%) is lost to boiloff during launch operations. As launch vehicles become fully and rapidly reusable and flight cadence increases, fuel costs gain significance as a cost driver to launch. Even worse, the consequences of boiloff lost during propellant transfer are compounded by the price involved in getting the hydrogen to space. While active cooling systems can mitigate storage boiloff losses, it is important to develop boiloff mitigation solutions for the fuel transfer process as well.
Capturing boil-off losses in an empty tank is not a viable option; the low volumetric density of hydrogen would necessitate an unreasonably large tank at typical boil-off pressures and the rate of boil-off losses (up to hundreds of grams per second) make direct compression a challenging obstacle. A materials-based recovery system offers a more promising solution. Known materials can rapidly adsorb (physisorption) hydrogen and densely store the hydrogen under low overhead pressures that are in line with typical venting pressures (<3 bar). This is to say that significantly more hydrogen can be stored on the materials of interest than in an empty tank at the same pressure and temperature. For example, recovering 50 kg of H2 from boil-off, assuming a storage tank pressure of 2 bar and 77K, would only require a 6.6 m3 tank containing standard off the shelf activated carbon for reversible storage. In contrast, a 79 m3 tank would be required to store the same amount of free gas at 77K and 2 bar. Importantly, the captured hydrogen could be released and delivered from a material on demand to a desired end use by controlling the temperature of the material.
This project is a large-scale demonstration of a materials-based liquid hydrogen boil-off recovery system. The team is a collaboration between industry, national laboratories, and academia and leverages materials development and expertise from the Hydrogen Materials Advanced Research Consortium (HyMARC), a Department of Energy (DOE) Energy Materials Network (EMN) consortium. The project approach integrates modeling and material characterization with engineering design. This talk will provide a high-level overview of the project and describe the successes as well as lessons learned.

The upcoming expansion of green hydrogen infrastructure under limited federal support highlights the urgent need for digital tools that ensure operational, economic, and environmental viability. Hyggle is a SaaS platform built for operators of hydrogen production, storage, and distribution assets. It offers real-time orchestration of assets via a scalable Energy Management System (EMS), designed specifically to address the complexity of integrating renewables, market-based power procurement, and storage flexibility.

In this presentation, we showcase how Hyggle enables infrastructure developers and operators to:

• Optimize production and delivery schedules based on electricity price forecasts, storage levels, and demand.
• Navigate and monetize volatility in power markets through embedded Energy Purchase Management (EPM) modules.
• Seamlessly integrate with existing SCADA/PLC infrastructure, as well as third-party data providers such as PPA aggregators and hydrogen vehicle fleets.
• Quantify carbon abatement and economic performance in real-time, a key requirement for securing subsidies, offtake agreements, and investor confidence.

We will present real-world use cases from European deployments and introduce ongoing U.S. proof-of-concept work (notably in the Southeast in partnership with Techstars Alabama EnergyTech), focused on hydrogen hubs and distributed hydrogen production.

This session will demonstrate how Hyggle bridges digital innovation and industrial practicality—helping the hydrogen economy scale faster, cleaner, and more intelligently.

The global transition to a hydrogen economy demands efficient, safe, and cost-effective solutions for hydrogen storage and transportation. Metal hydride (MH) storage systems are promising candidates, offering high volumetric and gravimetric energy densities alongside enhanced safety compared to conventional pressurized or liquid hydrogen methods. However, while small-scale studies highlight MH systems' economic potential, a significant knowledge gap remains: no holistic, large-scale approach spans the full value chain, from material synthesis and process engineering to operational integration. Additionally, current techno-economic analyses (TEA) lack thermodynamic models that capture performance under transient operating conditions.

This study conducts a techno-economic analysis of large-scale hydrogen storage and transportation systems (3 MWh to 10 GWh, corresponding to 0.1–300 tons of hydrogen). A conceptual design integrates detailed process engineering with multi-parametric thermodynamic optimization. By embedding a dedicated thermodynamic submodule into our TEA framework, we evaluate the sensitivity of capital and operational expenditures to key parameters, hydrogenation and dehydrogenation temperatures, pressures, and reaction kinetics, that dictate MH-system performance. This integration identifies optimal operating conditions, minimizing energy inputs and costs while maximizing efficiency and cyclic performance, bridging thermodynamic material-level properties and system-level operational heat and mass transfer kinetics.

The study demonstrates MH-based large-scale storage as cost-competitive, safer, and environmentally sustainable compared to conventional methods. Additionally, an interactive open-source platform developed for cost estimation and system optimization provides policymakers and industry stakeholders essential decision-support tools, advancing MH applications in stationary storage and transport.

The U.S. possesses an extensive natural gas transmission pipeline system comprising of 300,000 miles of steel pipe, of which repurposing could offer a low-cost pathway to transport hydrogen. However, various factors and uncertainties regarding hydrogen’s material and equipment performance impacts on existing natural gas pipeline infrastructure challenge transmission pipeline repurposing for hydrogen transport. Such factors include but are not limited to: enhanced fatigue crack growth and fracture resistance in steel pipes, a reduction of energy capacity at fixed pipeline pressures and an increase in compression energy need as to maintain energy transmission capacity. A proper hydrogen blending techno-economic assessment must balance operating and capital cost considerations such as existing pipeline pressure de-rating, increased compression energy and increased inspection frequency as well as capital equipment modification costs tied to enabling energy transmission capacity. In this presentation, we will introduce the Blending Pipeline Analysis Tool for Hydrogen (BlendPATH), which flexibly assesses the technical and economic impacts of repurposing existing natural gas pipeline to transport hydrogen or blends thereof on a case-by-case basis.

Hydrogen is a versatile energy carrier capable of serving multiple roles across the energy system. The U.S. Department of Energy’s H2@Scale initiative has explored the potential for scaling up hydrogen production from various sources and assessed the associated demand across sectors such as refining, chemical manufacturing, metallurgy, transportation, and power generation. Its ability to be stored for extended periods and transported over long distances makes hydrogen particularly valuable for balancing energy supply and demand. Consequently, several H2@Scale demonstration projects have been launched, and recent federal legislation has introduced incentives to support the large-scale deployment of hydrogen production and end-use applications.

For large-scale industrial use, pipeline delivery is often the most cost-effective option. In hydrogen hub configurations, multiple demand centers are typically located sparsely near one or more major production facilities, necessitating the development of a coordinated pipeline network.

To support such planning, Argonne National Laboratory has developed a computational tool, Pipeline Network Scenario Analysis Model (PNSAM) to optimize hydrogen pipeline infrastructure for both cost and efficiency. The model can connect any number of demand points to one or more production hubs. Rather than routing pipelines along direct geometric paths, it utilizes existing road networks to minimize land acquisition issues and related costs. Cost estimates are generated using regional models based on historical natural gas pipeline data, and a discounted cash flow analysis is applied to evaluate the cost contributions of both pipelines and compression. The model's capabilities are demonstrated through hypothetical scenarios simulating various supply and demand configurations.

The environmental credibility and market value of hydrogen depend not just on how it is produced, but on how its emissions are measured and verified. Lifecycle analysis (LCA) plays a critical role in quantifying the true carbon intensity of hydrogen across its entire value chain. As clean hydrogen becomes central to global decarbonization strategies, accurate LCA is increasingly vital for investors and developers to assess project viability, compare technology pathways, and determine eligibility for emerging carbon-related incentives. With governments and markets tightening definitions of “clean” hydrogen, projects that demonstrate verifiable low lifecycle emissions will be better positioned to capitalize on financial incentives and policy support.

Steam Methane Reforming (SMR) has long been the preferred and most efficient method for industrial hydrogen production. As the demand for low-carbon hydrogen grows, SMR remains central to blue hydrogen strategies. Conventional SMR plants equipped only with pre-combustion CO₂ capture typically achieve 60-70% decarbonization. This is due to residual carbon in unconverted CO and methane, which—along with supplemental natural gas fuel—is combusted in the reformer furnace, resulting in 30-40% of total CO₂ emissions associated with hydrogen production.

To surpass 90% CO₂ capture in an SMR, the industry has been exploring the use of post-combustion capture systems—either standalone or in combination with pre-combustion capture. While effective, the use of post-combustion CO2 capture remains a significant investment component of a blue hydrogen facility.

This paper presents an alternative configuration: the hydrogen-fired SMR. By using a portion of the produced hydrogen as fuel for the reformer furnace, flue gas CO₂ emissions are virtually eliminated. This enables a simplified and more economical carbon capture strategy focused solely on the high-pressure process gas, where the capture process is more efficient. The result is a flexible, scalable, and cost-effective decarbonized hydrogen product.

The paper outlines a hydrogen-fired SMR configuration and contrasts it with competing low-carbon SMR configurations, focusing on CO₂ intensity, efficiency, and adaptability to evolving regulatory landscapes. The configuration and analysis draw on engineering studies and experience from Technip Energies (T.EN), whose involvement in the development and implementation of hydrogen technologies provides practical insights into the feasibility of this pathway for blue hydrogen production.

Digital Twin technology is rapidly emerging as a key enabler in addressing the major challenges of green hydrogen production, including high lifecycle costs, limited operational experience, and complex system integration. This presentation explores how Integrated Digital Twins—virtual models built by combining advanced software tools with diverse, real-time and historical data—can enhance performance and reduce costs across the entire plant lifecycle.

During the design and engineering phase, Digital Twins allow stakeholders to simulate plant behavior under various scenarios, optimize system configurations, and validate design choices before construction begins. This model-based approach not only reduces design errors and accelerates decision-making but also plays a critical role in minimizing the Levelized Cost of Hydrogen (LCOH) by ensuring that plants are designed for long-term efficiency, scalability, and cost-effectiveness.

Once operational, Digital Twins continue to deliver value by synchronizing with live plant data to support real-time monitoring, predictive maintenance, and process optimization. These capabilities enable operators to make data-driven decisions that improve efficiency, reduce downtime, and extend asset life—all of which contribute directly to lowering the LCOH. Whether applied to individual assets or across entire fleets, Digital Twins provide a scalable, standardized approach to managing hydrogen infrastructure more effectively.

This presentation will highlight practical applications of Digital Twin technology in the hydrogen sector, demonstrating how it supports smarter design, more efficient operations, and ultimately, more sustainable and economically viable hydrogen production.

As the global demand for clean hydrogen, as feedstock to produce low carbon fuels accelerates, Autothermal Reforming (ATR) technology has emerged as a strategic enabler for scalable, low-carbon solutions. Johnson Matthey’s ADVANCED REFORMING TM technologies based on ATR and ATR with Gas Heated Reforming (GHR) flowsheets to maximize decarbonization outcomes while maintaining operational efficiency across various feedstocks, including natural gas and renewable gas.

 This work highlights how JM’s GHR-ATR technology delivers high purity hydrogen at commercial scale with industry-leading carbon capture capabilities. By serving as a front-end hydrogen generator, the ATR unit enables the production of ultra-low carbon hydrogen, positioning it as a critical technology for clean fuel and chemical markets. A key focus will be placed on energy integration, and how JM’s MAXERGY^TM technology with GHR-ATR “in true series” use high grade heat from ATR to drive reforming in the GHR that can enhance process energy efficiency. Effective energy management does not only enhance process efficiency but lower the carbon intensity of final product. The approach balances thermodynamic favourability, catalyst performance, and utility optimization to achieve robust scalable configurations.

 This work will showcase leading edge features of JM’s GHR-ATR, Fischer-Tropsch and Methanol technologies. Emphasis will be placed on how process design choices put forward advantages for licensors, developers and operators pursuing high-impact, financeable low-carbon projects.

There are significant engineering challenges in powering megawatt electrolyzers with solar and wind energy. A poorly designed power system results in significantly higher carbon emission and/or hydrogen cost than fossil fuel derived hydrogen. Today megawatt solar electrolyzers are all coupled through alternating current (AC). The multiple power conversions from direct current (DC) to AC to DC incur significant costs and energy losses of 25–30% just in power delivery between solar array and electrolyzer. DC-coupled solar electrolyzers are hampered by the limited current capacity of DC power converters, with similar energy losses and even higher costs. A common issue with solar and wind energy is their intermittency, leading to low capacity factors and thus high costs for green hydrogen. In this talk, a technoeconomic analysis is presented on energy losses in various system configurations for solar and wind electrolyzers. It concludes with several recommendations for megawatt solar and wind electrolyzers: 1) criterion for a “clean” grid for grid-powered water electrolysis; 2) direct coupling between solar array and electrolyzer for efficient, low-cost, reliable, and scalable hydrogen production; 3) innovations in direct-coupled solar electrolyzers to reduce energy losses in power delivery to 2%; and 4) a proper order of various energy sources (solar, wind, hydro, and/or nuclear) in powering electrolyzers to approach a 100% capacity factor.

Green hydrogen is a vital emerging solution for global decarbonization, particularly for applications incompatible with electrification through renewable energy sources. Because of its production through electrolysis of water, green hydrogen acts as a sustainable fuel and heat source in industries previously depending on high carbon intensity sources. Electrolyzer implementation grows as the demand for green hydrogen production increases, requiring a carefully engineered approach for the coatings and materials used in electrolyzer stack designs. The technologies discussed in this presentation will describe PPG’s efforts to balance cost, efficiency, and durability, particularly for coatings which balance conductivity and corrosion resistance. For example, electrolyzer systems expose components to highly corrosive environments, often necessitating the use of dense precious metal coatings. This presentation will discuss novel protective coatings designed to minimize the use of platinum-group metals while still maintaining high performance qualities. By leveraging computer modeling techniques in conjunction with scalable technologies, we will demonstrate how coatings and materials for electrolyzer systems can be economically optimized to achieve gigawatt/year production volumes.

Off-grid offshore platform-mounted wind-to-hydrogen systems represent a compelling pathway for clean energy production and decarbonization of industrial and maritime sectors. However, these systems face significant operational challenges due to the inherent variability of wind resources. In this presentation, we analyze the technical implications of wind variability governed by Weibull-distributed wind speeds. The Weibull parameters used are representative of Corpus Christi, TX offshore wind speeds. Using Monte Carlo methods over a period 8,760 hours (one year), we evaluate three interrelated performance challenges: (1) the frequency of cold starts and associated HVAC power demand; (2) the limited operational window at nameplate wind turbine capacity; and (3) the probability of energy storage system depletion under battery backup scenarios.

Nickel-electrode seafloor liquid alkaline electrolytic hydrogen production is a new and innovative alternative to platform-mounted PEM electrolysis. It provides solutions to the three challenges. In addition, subsea electrolytic hydrogen production is the safest approach to gigawatt-scale hydrogen because combustible oxygen is not accessible. All unit operations needed for subsea hydrogen production are already being performed by the offshore energy industry. Pressure-balanced electrolysis and hydrostatic pressure are leveraged to produce high pressure hydrogen without mechanical compressors. The electrolyzers are manufactured from low-cost commodity materials including polyethylene, a material with virtually perfect stability in seawater. Seafloor electrolysis shields the hydrogen production systems from lighting strikes, EMP events, and hurricanes.

*Supported by the U.S. Department of Energy, Office of Clean Energy Demonstrations under the EnergyWerx Advisory Voucher Program with GTA, Inc. and the Parabellum Strategic Group LLC.

In the global pursuit of a sustainable hydrogen economy, the deployment of safe, efficient, and technically informed electrolysis systems is paramount. The paper introduces PSRG’s ElectrolysisGPT^TM, a purpose-built Generative Pre-trained Transformer (GPT) assistant designed to support researchers, engineers and clean energy professionals in the selection, deployment, optimization and safe operation of hydrogen electrolysis technologies. The assistant offers up-to-date, expert-level insights across Solid Oxide (SOEC), Anion Exchange Membrane (AEM), Proton Exchange Membrane (PEM), and Alkaline electrolyzers, tailored to diverse applications ranging from small scale industrial plants to distributed renewable energy systems.

ElectrolysisGPT^TM is structured around performance benchmarking, detailed technology comparison and lifecycle guidance. It contextualizes electrolyzer selection based on CAPEX/OPEX considerations, water purity, input power characteristics, thermal requirements, and system lifetime goals. Through structured outputs and interactive modules (including safety checklists, deployment flowcharts, comparison tables and more), the assistant bridges the gap between practical implementation and technical feasibility. With capabilities including the identification of catalyst and membrane innovations, interpretation of stack efficiency metrics, and mapping of use cases such as green ammonia, hydrogen blending, and fueling infrastructure, ElectrolysisGPT^TM serves as an intelligent knowledge interface. The platform supports voice-based querying, multilingual interaction, and presentation-ready content generation including training modules, hence enhancing accessibility for global teams and stakeholders.

This work demonstrates a scalable, audit-grade AI system that accelerates technology deployment, advances decision-making, and promotes technically sound adoption of green hydrogen solutions. ElectrolysisGPT^TM embodies the fusion of advanced AI with domain-specific accuracy, driving the transition toward decarbonized energy systems through informed, data-driven electrolysis strategies.

In this presentation, we will highlight two efforts to develop highly efficient water-splitting catalysts.

First, molybdenum-based catalysts show promise for water splitting, but their electrodeposition from aqueous solutions is challenging due to strong oxygen affinity. We optimized a synthesis strategy for Ni-Mo-P alloy deposition on acid-treated stainless steel (ATSS) using Na₂MoO₄ as the Mo precursor and LiCl as an additive. Galvanostatic studies and in-situ Raman spectroscopy confirmed MoO₄²⁻ adsorption and localized pH effects on deposition quality. The optimized NiMoP-ATSS catalyst demonstrated excellent HER activity (-62 mV at 10 mA/cm²) and also exhibited outstanding OER performance (260 mV at 10 mA/cm²).

Second, we will introduce our efforts to develop an automated high-throughput catalyst synthesis and evaluation system for oxygen evolution reaction (OER) catalyst screening. The system employs robotic arms to precisely control and mix catalyst precursors and to manage electrode bundle movements for catalyst deposition. Following deposition, the performance of the catalysts is systematically evaluated and recorded. We will discuss the steps taken to ensure consistent and reliable results using this platform, along with demonstration experiments on metal alloy synthesis for OER applications.

Hydrogen use in fuel cell vehicles is attractive for heavy-duty vehicles. This presentation highlights the key cost drivers and environmental impacts of various hydrogen pathways and hydrogen vehicle classes and duty cycles. The key drivers include fuel cell powertrain efficiency and associated vehicle fuel economy relative to the incumbent vehicle powertrain technology, the hydrogen onboard storage technology, as well as the hydrogen production, packaging, delivery, storage and fueling technologies. The presentation will also address the value proposition of the indirect use of hydrogen via energy carriers such as e-fuels and ammonia for other transportation applications.

Hydrogen as a vector for clean energy experienced strong growth and interest over the last five years, but only about one percent of proposed  global projects have progressed to Final Investment Decision (FID).   Concerns over costs and required infrastructure versus competing options in electrification and battery storage have created headwinds, while a subset of global stakeholders have pushed back over the cost and importance of “decarbonization” versus enhancing energy supply and resilience.    This seminar will examine future roles and opportunities for hydrogen, including where its usage may be differentiated and valued for applications in transportation, industrial decarbonization and energy storage, as well as the technology developments that are needed to address cost challenges, for a world where once-size-fits-all does not apply for energy choices.   

Risk Planning and Analysis are essential activities to enable a new renewable energy economy that will replace the oil economy. Oil has brought more negative effects than positive ones, and it is no longer a suitable value chain for the long term due to the greenhouse effect caused by excessive carbon emissions, which threatens human existence in the current stage of occupation of planet Earth. The current environment is dynamic due to climate change and unfriendly political relations between the continents and countries on our planet. The Multidimensional Analysis of the Green Hydrogen Value Chain is performed and reviewed according to the resulting Scenario. Thus, the dimensions are divided into: Dimension 1 – Geoeconomics of Green Hydrogen; Dimension 2 – Architecture of the Value Chain for Implementation of Projects; Dimension 3 - Risk Analysis of local, regional and global events; and Dimension 4, Analysis of future operability of industrial and logistics facilities distributed across countries and continents. This paper will treat the Dimensios 1 and 2. The first dimension of analysis in the Green Hydrogen Value Chain focuses on the geoeconomics of hydrogen, evaluating the types of enterprises involved based on their chemical, physical, and geographical characteristics. This dimension aims to optimize resource allocation in feasibility studies by assessing potential risks that could lead to production disruptions. The result of this paper is a global vision about limits and opportunities that are general challenges for Green Hydrogen Value Chain with a draft timeline.

Hydrogen production is scaling up and the product gas is being deployed for diverse applications in efforts to pivot away from carbon-based fuels. Clean hydrogen, however, still faces challenge in cost and in the establishment of a low-carbon supply chain. Many existing tools offer detailed insight into emissions and cost modeling independently, or of specific infrastructure stages. As the hydrogen economy further develops, efforts must be made to bring the full supply chain together. The tool presented here leverages existing models and assumptions to present a throughput analysis of a single hydrogen project from production to use case. This work allows users to benchmark their project costs and emissions with specific regional scope to assess its viability. This includes linking together the production method, distribution pathway, and hydrogen use case. Additionally, this tool integrates both greenhouse gas and criteria air pollutants with a cost basis in the use case to develop a holistic view of the benefits of hydrogen alongside the operational costs. By running a first-pass analysis of a desired hydrogen supply chain, project operators and government partners alike can assess what the contributions are to overall cost and emissions at each stage. The results from this tool can inform users on where to allocate further time and research into preparing a cost-effective, low-carbon source of hydrogen for their target use.