Applications & Pathways

The maritime industry is a major source of greenhouse gas (GHG) emissions largely due to ships running on fossil fuels. Transitioning to hydrogen-powered marine transportation in the Mediterranean Sea requires the development of a network of hydrogen refueling stations across the region to ensure a steady supply of green hydrogen. This paper explores the technoeconomic viability of harnessing wave energy from the Mediterranean Sea to produce green hydrogen for hydrogenpowered ships. Four promising island locations—near Sardegna Galite Western Crete and Eastern Crete—were selected based on their favorable wave potential for green hydrogen production. A thorough analysis of the costs associated with wave power facilities and hydrogen production was conducted to accurately model economic viability. The techno-economic results suggest that with anticipated cost reductions in wave energy converters the levelized cost of hydrogen could decrease to as low as 3.6 €/kg 4.3 €/kg 5.5 €/kg and 3.9 €/kg for Sardegna Galite Western Crete and Eastern Crete respectively. Furthermore the study estimates that in order for the hydrogen-fueled ships to compete effectively with their oil-fueled counterparts the levelized cost of hydrogen must drop below 3.5 €/kg. Thus despite the competitive costs further measures are necessary to make hydrogen-fueled ships a viable alternative to conventional diesel-fueled ships.

Hydrogen refueling stations (HRS) can cause a significant fraction of the hydrogen refueling cost. The main cost contributor is the currently used mechanical compressor. Electrochemical hydrogen compression (EHC) has recently been proposed as an alternative. However its optimal integration in an HRS has yet to be investigated. In this study we compare the performance of a gaseous HRS equipped with different compressors. First we develop dynamic models of three process configurations which differ in the compressor technology: mechanical vs. electrochemical vs. combined. Then the design and operation of the compressors are optimized by solving multi-stage dynamic optimization problems. The optimization results show that the three configurations lead to comparable hydrogen dispensing costs because the electrochemical configuration exhibits lower capital cost but higher energy demand and thus operating cost than the mechanical configuration. The combined configuration is a trade-off with intermediate capital and operating cost.

Hydrogen-based Power Systems (H2PSs) are gaining accelerating momentum globally to reduce energy costs and dependency on fossil fuels. A H2PS typically comprises three main parts: hydrogen production storage and power generation called packages. A review of the literature and Original Equipment Manufacturers (OEM) datasheets reveals that no single manufacturer supplies all H2PS components posing significant challenges in system design parts integration and safety assurance. Additionally both the literature and H2PS projects’ database highlight a gap in a systematic hydrogen equipment and auxiliary sub-systems technology selection process and how this selection affects the overall H2PS Balance of Plant (BoP). This study addresses that gap by providing a guideline for available technology options and their impact on the H2PS-BoP. The analysis compares packages and auxiliary sub-system technologies to support informed engineering decisions regarding technology and equipment selection. The study finds that each package’s technology influences the selection criteria of the other packages and the associated BoP requirements. Furthermore the choice of technologies across packages significantly affects overall system integrity and BoP. These interdependencies are illustrated using a cause-and-effect matrix. The study’s significance lies in establishing a structured guideline for engineering design and operations enhancing the accuracy of feasibility studies and accelerating the global implementation of H2PS.

Sustainable aviation fuels (SAFs) represent the short-term solution to reduce fossil carbon emissions from aviation. The Carbon Offsetting and Reduction Scheme for International Aviation (CORSIA) was globally adopted to foster and make SAFs production economically competitive. Fischer-Tropsch synthetic paraffinic kerosene (FTSPK) produced from forest residue is a promising CORSIA-eligible fuel. FT conversion pathway permits the integration of carbon capture and storage (CCS) technology which provides additional carbon offsetting ca pacities. The FT-SPK with CCS process was modelled to conduct a comprehensive analysis of the conversion pathway. Life-cycle assessment (LCA) with a well-to-wake approach was performed to quantify the SAF’s carbon footprint considering both biogenic and fossil carbon dynamics. Results showed that 0.09 kg FT-SPK per kg of dry biomass could be produced together with other hydrocarbon products. Well-to-wake fossil emissions scored 21.6 gCO2e per MJ of FT-SPK utilised. When considering fossil and biogenic carbon dynamics a negative carbon flux (-20.0 gCO2eMJ− 1 ) from the atmosphere to permanent storage was generated. However FT-SPK is limited to a 50 %mass blend with conventional Jet A/A1 fuel. Using the certified blend reduced Jet A/A1 fossil emissions in a 37 % and the net carbon flux resulted positive (30.9 gCO2eMJ− 1 ). Sensitivity to variations in process as sumptions was investigated. The lifecycle fossil-emissions reported in this study resulted 49 % higher than the CORSIA default value for FT-SPK. In a UK framework only 0.7 % of aviation fuel demand could be covered using national resources but the emission reduction goal in aviation targeted for 2037 could be satisfied when considering CCS.

Hydrogen is gaining traction as a key energy carrier due to its clean combustion high energy content and versatility. As the world shifts towards sustainable energy hydrogen demand is rapidly increasing. This paper introduces a novel hybrid time series modeling approach designed and developed to accurately predict hydrogen demand by mixing linear and nonlinear models and accounting for the impact of non-recurring events and dynamic energy market changes over time. The model incorporates key economic variables like hydrogen price oil price natural gas price and gross domestic product (GDP) per capita. To address these challenges we propose a four-part framework comprising the Hodrick–Prescott (HP) filter the autoregressive fractionally integrated moving average (ARFIMA) model the enhanced empirical wavelet transform (EEWT) and high-order fuzzy cognitive maps (HFCM). The HP filter extracts recurring structural patterns around specific data points and resolves challenges in hybridizing linear and nonlinear models. The ARFIMA model equipped with statistical memory captures linear trends in the data. Meanwhile the EEWT handles non-stationary time series by adaptively decomposing data. HFCM integrates the outputs from these components with ridge regression fine-tuning the HFCM to handle complex time series dynamics. Validation using stochastic non-Gaussian synthetic data demonstrates that this model significantly enhances prediction performance. The methodology offers notable improvements in prediction accuracy and stability compared to existing models with implications for optimizing hydrogen production and storage systems. The proposed approach is also a valuable tool for policy formulation in renewable energy and smart energy transitions offering a robust solution for forecasting hydrogen demand

Cement industry due to the decomposition of CaCO3 and the production of clinker emits large amounts of CO2 into the atmosphere. This anthropogenic gas can be captured and through its synthesis with green hydrogen methanol and finally synthetic fuels are achieved. By using e-fuel Europe’s climate neutrality objectives could be achieved. However the energy transition still lacks a clear roadmap and decisions are strongly affected by the geopolitical situation the energy demand and the economy. Therefore different scenarios are analysed to assess the influence of key factors on the overall economic viability of the process: 1) A business-as-usual scenario EU perspectives 2) allowing e-fuels and 3) improving H2 production processes. The technical feasibility of the production of synthetic fuels is verified. The most optimistic projections indicate future production costs of synthetic fuels will be lower than those of fossil fuels. This is directly related to the cost of green hydrogen production.

The present study investigates the design and scale-up of a pure hydrogen oxy-fuel combustion burner for industrial applications. In recent years this technology has garnered attention as an effective approach to the decarbonisation of high-temperature industrial processes. Replacing air with oxygen in combustion processes significantly reduces nitrogen oxides emissions and leads to sustainable energy use. A laboratory-scale burner was designed with inlet nozzle dimensions adapted to the specific properties of hydrogen and oxygen as fuel and oxidant respectively. Implementing oxy-fuel combustion requires addressing several technical issues to prevent the burner wall from overheating and to ensure a stable flame. An infrared camera was used to characterise the performance and operating conditions of the laboratory-scale burner in the range of 2.5–30 kW. The 10 kW baseline case was analysed numerically and validated experimentally using thermocouples. This revealed stable lifted flames with maximum temperatures of 2800 K and a flame length of 0.15 m. A key challenge in engineering is transferring results from laboratory-scale to large-scale industrial applications. Once validated the prototype design was scaled up numerically from 10 kW to 1 MW investigating the feasibility of different scaling criteria. The impact of these criteria on flame characteristics mixing patterns and the volumetric distribution of the reaction zone was then assessed. The constant velocity criterion yielded the lowest pressure drops although it also resulted in longer flame lengths. In contrast the constant residence time criterion generated the highest pressure drops. The increased velocities associated with this criterion enhanced mixing leading to shorter flame lengths as noted in the cases of 200 kW decreasing from 0.98 m under constant velocity criterion to 0.46 m. The intermediate criteria demonstrated a feasible alternative for scaling up the burner by effectively balancing flame length mixing rate and pressure losses. Nevertheless all criteria enabled the burner to sustain high combustion efficiency. Overall this investigation provides valuable insight into the potential of hydrogen oxy-fuel combustion technology to reduce carbon emissions in high-temperature processes.

Hydrogen is a promising energy carrier for decarbonizing maritime and stationary applications. However using 100% hydrogen in large-bore engines introduces combustion challenges such as pre-ignition and backfire. These statistically occurring combustion anomalies particularly their spatial and temporal behavior cannot be fully understood through thermodynamic data alone. This study applies optical diagnostics to a medium-speed single-cylinder research engine (bore: 350 mm stroke: 440 mm displacement: 42.3 dm3 ) operated with 100% hydrogen exceeding 20 bar IMEP. By varying the air–fuel equivalence ratio between 2.3 and 4.0 and comparing active pre-chamber and open combustion chamber ignition systems backfire-induced operating limits are identified. High-speed flame imaging through two endoscopic accesses and up to three cameras captures both visible and UV (308 nm) flame chemiluminescence. An implemented visual vibration compensation method using fiber optics enables tracking of flame origins and propagation. The recordings show that 65% of ignition events initiate near one intake valve suggesting local hydrogen enrichment confirmed via 3D-CFD simulations. This is linked to intake manifold geometry which leads to mixture inhomogeneity up to −260◦ CA BTDC. At loads above 15 bar IMEP the localized enrichment reduces or shifts attributed to increased turbulence and intake mass flow. CFD simulations also reveal that gas temperatures under the intake valves exceeding the ignition temperature of hydrogen as early as 300◦ CA BTDC create the risk of backfire in the early gas phase. Additionally glowing oil droplets and ignition zones near the piston were observed indicating that lube oil ignition may be a cause of later (after −290◦ CA BTDC) backfire events. These findings contribute to the understanding of hydrogen combustion anomalies and support future experimental and modeling-based optimization of large-bore hydrogen engines.

To address the challenges in wind power fluctuation smoothing using electrochemical-hydrogen hybrid energy storage a SOC self-recovery-based capacity optimization is proposed. The key issues include extreme high/low SOC states of electrochemical storage due to large charge-discharge disparities and the degradation of hydrogen storage tank SOH caused by its efficiency characteristics which lead to high configuration costs. First considering grid-connection lag time and algorithm adaptability an adaptive weighted filter is designed to suppress wind power fluctuations to obtain precise active power reference values for hybrid energy storage. The active power is then allocated between electrochemical and hydrogen storage using EMD and HT. Subsequently a complementary operation strategy for electrochemical-hydrogen systems is proposed which incorporates equivalent SOC metrics to assess the overall SOC level of electrochemical storage. By defining trigger thresholds for different operational modes abnormal SOC and SOH states are eliminated. Finally a full lifecycle economic cost assessment model based on the rainflow counting method is established to evaluate the impact of different threshold settings on the operational lifespan of energy storage and the overall configuration cost. The proposed method is validated through real-data simulations demonstrating its effectiveness in optimizing hybrid storage configurations and reducing costs compared to conventional strategies.

Multi-energy systems (MESs) can address issues such as low renewable energy utilization and power imbalances by optimizing the integration of various energy sources. This paper proposes an optimization operation strategy for MES to regulate the hydrogen and battery storage system (HBRS) based on carbon emission factors (CEFs). Insufficient renewable energy utilization caused by reverse peak regulation can be addressed by guiding the optimal output of HBRS through this model thereby achieving multi-energy complementarity. The CEF is used to balance the output of the HBRS to achieve a low-carbon economic operating system. First the fluctuation of renewable energy is decomposed and reconstructed. Subsequently The HBRS system is utilized to smooth out the fluctuations caused by different frequencies of new energy and then the CEF is used to promote the output of the low-carbon subsystem. Finally comparative verification is conducted across validation cases to demonstrate the effectiveness of the proposed model and the optimization strategy.