Publications

With the fast-growing implementation of renewable energy projects Morocco is positioned as a pioneer in green and sustainable development aiming to achieve 52% of its electricity production from renewable sources by 2030. This ambitious target faces challenges due to the intermittent nature of renewable energy which impacts grid stability. Hydrogen offers a promising solution but identifying the most cost-effective production configurations is critical due to high investment costs. Despite the growing interest in renewable energy systems the techno-economic analysis of (Concentrating Solar PowerPhotovoltaic) CSP-PV hybrid configurations remain insufficiently explored. Addressing this gap is critical for optimizing hybrid systems to ensure cost-effective and scalable hydrogen production. This study advances the field by conducting a detailed technoeconomic assessment of CSP-PV hybrid systems for hydrogen production at selected locations in Morocco leveraging high-precision meteorological data to enhance the accuracy and reliability of the analysis. Three configurations are analyzed: (i) a standalone 10 MW PV plant (ii) a standalone 10 MW Stirling dish CSP plant and (iii) a 10 MW hybrid system combining 5 MW from each technology. Results reveal that hybrid CSP-PV systems with single-axis PV tracking achieve the lowest levelized cost of hydrogen (LCOH2) reducing costs by up to 11.19% and increasing hydrogen output by approximately 10% compared to non-tracking systems. Additionally the hybrid configuration boosts annual hydrogen production by 2.5–11.2% compared to PV-only setups and reduces production costs by ~25% compared to standalone CSP systems. These findings demonstrate the potential of hybrid solar systems for cost-efficient hydrogen production in regions with abundant solar resources.

Hydrogen production via water electrolysis and renewable electricity is expected to play a pivotal role as an energy carrier in the energy transition. This fuel emerges as the most environmentally sustainable energy vector for non-electric applications and is devoid of CO2 emissions. However an electrolyzer´s infrastructure relies on scarce and energyintensive metals such as platinum palladium iridium (PGM) silicon rare earth elements and silver. Under this context this paper explores the exergy cost i.e. the exergy destroyed to obtain one kW of hydrogen. We disaggregated it into non-renewable and renewable contributions to assess its renewability. We analyzed four types of electrolyzers alkaline water electrolysis (AWE) proton exchange membrane (PEM) solid oxide electrolysis cells (SOEC) and anion exchange membrane (AEM) in several exergy cost electricity scenarios based on different technologies namely hydro (HYD) wind (WIND) and solar photovoltaic (PV) as well as the different International Energy Agency projections up to 2050. Electricity sources account for the largest share of the exergy cost. Between 2025 and 2050 for each kW of hydrogen generated between 1.38 and 1.22 kW will be required for the SOEC-hydro combination while between 2.9 and 1.4 kW will be required for the PV-PEM combination. A Grassmann diagram describes how non-renewable and renewable exergy costs are split up between all processes. Although the hybridization between renewables and the electricity grid allows for stable hydrogen production there are higher non-renewable exergy costs from fossil fuel contributions to the grid. This paper highlights the importance of nonrenewable exergy cost in infrastructure which is required for hydrogen production via electrolysis and the necessity for cleaner production methods and material recycling to increase the renewability of this crucial fuel in the energy transition.

Novel hydrogen-based aircraft concepts pose significant challenges for the system development process. This paper proposes a generic adaptable and multidisciplinary framework for integrated model-based systems engineering (MBSE) and model-based safety assessment (MBSA) for the conceptual design of complex systems. The framework employs a multi-granularity modelcentric approach whereby the architectural specification is utilized for design as well as query purposes as part of a qualitative and quantitative graphbased preliminary safety assessment. For the qualitative assessment design and safety rules based on existing standards and best practices are formalized in the model and applied to a graph-based architecture representation. Consequently the remaining architectures are quantitatively assessed using automated fault trees. This safety-integrated approach is applied to the conceptual design of a liquid hydrogen fuel system architecture as a novel uncertain and complex system with many unknown system interrelations. This paper illustrates the potential of a combined MBSE-MBSA framework to streamline complex early-stage system design and demonstrates that all qualitatively down-selected hydrogen system architecture variants also satisfy quantitative assessment. Furthermore it is shown that the design space of novel systems is also constrained by safety and certification requirements significantly reducing the number of actual feasible solutions.

Tilos a Greek island in the Mediterranean Sea hosts a pioneering hybrid energy system combining an 800-kW wind turbine and a 160-kWp photovoltaic (PV) field. The predominance of wind power makes the energy production of the island almost constant during the year while the consumption peaks in summer in correspondence with the tourist season. If the island wants to achieve complete selfsufficiency seasonal storage becomes compulsory. This study makes use of measured production data over 1 year to understand the best combination of renewable energy generation and storage to match energy production with consumption. A stochastic optimization based on a differential evolution algorithm is carried out to showcase the configuration that minimizes the levelized cost of required energy (LCORE) in different scenarios. System performance is simulated by progressively increasing the size of the storage devices including a combination of Lithium-ion batteries and power-to-gas-topower (P2G2P) technologies and the PV field. An in-depth market review of current and forecasted prices for RES and ESS components supports the economic analysis including three time horizons (current and projections to 2030 and 2050) to account for the expected drop in component prices. Currently the hybrid storage system combining BESS and P2G2P is more cost-effective (264 €/MWh) than a BESS-only system (320 €/MWh). In the mid-term (2030) the expected price drop in batteries will shift the optimal solution towards this technology but the LCORE reached by the hybrid storage (174 €/MWh) will still be more economical than BESS-only (200 €/MWh). In the long term (2050) the expected price drop in hydrogen technologies will push again the economic convenience of P2G2P and further reduce the LCORE (132.4 €/MWh).

Environmental concerns and the imperative to achieve net-zero carbon emissions have driven the exploration of efficient and sustainable advancements in automobile technologies. The automotive sector is undergoing a significant transformation primarily propelled by the adoption of green fuel technologies. Among the most promising innovations are green vehicle technologies and the integration of non-conventional power sources including advanced batteries (featuring high energy density) fuel cells (capable of long-range energy generation with water as the sole byproduct) and super-capacitors (characterized by rapid charge–discharge capabilities). This article examines the performance efficiency and adaptability of these power sources for electric vehicles (EVs) providing a comprehensive comparison of their functional capabilities. Additionally it analyzes the integration of super-capacitors with batteries and fuel cells emphasizing the potential of hybrid systems to enhance vehicle performance optimize energy management and extend operational range. The role of power converters in such systems is also discussed underscoring their critical importance in ensuring efficient energy transfer and effective energy management.

Hydrogen (H2) will play a vital role in the global shift towards sustainable energy systems. Due to the high cost and challenges associated with storing hydrogen in large quantities for industrial applications Underground Hydrogen Storage (UHS) in geological formations has emerged as a promising solution. Clay minerals abundant in subsurface environments play a critical role in UHS by providing low permeability cation exchange capacity and stability essential for preventing hydrogen leakage. However microorganisms in the subsurface particularly hydrogenotrophic species interact with clay minerals in ways that can affect the integrity of these storage systems. Microbes form biofilms on clay surfaces which can cause pore clogging and reduce the permeability of the reservoir potentially stabilizing H2 storage and limiting injectivity. Microbial-induced chemical weathering through the production of organic acids and redox reactions can degrade clay minerals releasing metal ions and destabilizing the storage site. These interactions raise concerns about the long-term storage capacity of UHS as microbial processes could lead to H2 loss and caprock degradation compromising the storage system’s effectiveness. This mini review aims to cover the current understanding of the interactions between clay minerals and microorganisms and how these dynamics can affect the safe and sustainable deployment of UHS.

Green hydrogen is a promising solution within carbon free energy systems with Sub-Saharan Africa being a possibly well-suited candidate for its production. However green hydrogen production in Sub-Saharan Africa is not yet investigated in detail. This work determines the cost-potential for green hydrogen production within this region. Therefore a potential analysis for PV wind and hydropower groundwater analysis and energy systems optimization are conducted. The results are evaluated under local socio-economic factors. Results show that hydrogen costs start at 1.6 EUR/kg in Mauritania with a total potential of ~259 TWh/a under 2 EUR/kg in 2050. Two third of the region experience groundwater limitations and need desalination at an added costs of ~1% of hydrogen costs. Socio-economic analysis show that green hydrogen deployment can be hindered along the Upper Guinea Coast and the African Great Lakes driven by limited energy access low labor costs in West Africa and high labor potential in other regions.

This week the EAH team discusses LIFTE H2’s plans for the future and discusses the challenges in hydrogen markets expansion and rollout the need for resiliency for offtakers and how to build consumer confidence.

The podcast can be found on their website.

In this study the applicability of an integrated-hybrid process was performed in a divided electrochemical cell for removing organic matter from a polluted effluent with simultaneous production of green H2. After that the depolluted water was reused for the first time in the cathodic compartment once again in the same cell to be a viable environmental alternative for converting water into energy (green H2) with higher efficiency and reasonable cost requirements. The production of green H2 in the cathodic compartment (Ni-Fe-based steel stainless (SS) mesh as cathode) in concomitance with the electrochemical oxidation (EO) of wastewater in the anodic compartment (boron-doped diamond (BDD) supported in Nb as anode) was studied (by applying different current densities (j = 30 60 and 90 mA cm−2 ) at 25 ◦C) in a divided-membrane type electrochemical cell driven by a photovoltaic (PV) energy source. The results clearly showed that in the first step the water anodically treated by applying 90 mA cm−2 for 180 min reached high-quality water parameters. Meanwhile green H2 production was greater than 1.3 L with a Faradaic efficiency of 100%. Then in a second step the water anodically treated was reused in the cathodic compartment again for a new integrated-hybrid process with the same electrodes under the same experimental conditions. The results showed that the reuse of water in the cathodic compartment is a sustainable strategy to produce green H2 when compared to the electrolysis using clean water. Finally two implied benefits of the proposed process are the production of green H2 and wastewater cleanup both of which are equally significant and sustainable. The possible use of H2 as an energetic carrier in developing nations is a final point about sustainability improvements. This is a win-win solution.

This paper addresses public acceptance of a proposed sub-regional hydrogen– electric aviation service reporting initial empirical evidence from the UK HEART project. The objective was to assess public acceptance of a wide range of service features including hydrogen power electric motors and pilot assistance automation in the context of an ongoing realisable commercial plan. Both qualitative and quantitative data collection instruments were leveraged including focus groups and stakeholder interviews as well as the questionnaire-based Scottish National survey coupled with the advanced discretechoice modelling of the data. The results from each method are presented compared and contrasted focusing on the strength reliability and validity of the data to generate insights into public acceptance. The findings suggest that public concerns were tempered by an incomplete understanding of the technology but were interpretable in terms of key service elements. Respondents’ concerns and opinions centred around hydrogen as a fuel singlepilot automation safety and security disability and inclusion environmental impact and the perceived usefulness of novel service features such as terminal design automation and sustainability. The latter findings were interpreted under a joint framework of technology acceptance theory and the diffusion of innovation. From this we drew key insights which were presented alongside a discussion of the results.

This study introduces an effective analysis framework for exploring the complex interrelation between the renewable energy factor (REF) and the economic dimensions of a PV-driven microgrid featuring a dual-level storage system that incorporates both hydrogen and electrical energy storage. By establishing a coupled model that integrates dynamic simulations with a statistical multi-objective optimization algorithm the research aims to achieve optimal component sizing—a critical step in assessing the hybrid system across various REF levels—while effectively reducing the levelized cost of electricity (LCOE). Using the analysis outcomes of a case study a comprehensive techno-economic assessment facilitates a nuanced evaluation of the interplay between the REF system economics across various equipment cost quartiles and grid tariffs addressing the feasibility of the proposed solution for a sustainable energy transition. The results highlight how grid tariffs and REF jointly influence LCOE values across cost quartiles impacting hybrid system design and decision-making. An exponential correlation is observed between life cycle cost (LCC) and REF with the increase in annual operating costs being marginal compared to the initial cost rise. For the net-zero energy case the LCOE ranges from 0.0380 to 0.1873 $/kWh while at REF = 0.6 it spans from 0.0461 to 0.1334 $/kWh reflecting a 71 % larger difference (range). A sensitivity analysis indicates that each 5 % increase in REF leads to an average 20.7 % rise in payback period (PBP) for a given grid tariff.

Hydrogen and electric buses are considered effective options for decarbonizing the public transportation sector positioning them as a leader in this transition. This study models the environmental and economic performances of a set of bus powertrain technologies considering a real case-study of suburban public transport in Italy and including fuel cell electric vehicles (FCEV) battery electric vehicles (BEV) biomethane-powered vehicles (CBM) natural gas (CNG) and diesel buses. The environmental performances of FCEV and BEV are significantly influenced by the energy source used for hydrogen production or battery charging. Specifically using the electricity mix for FCEV leads to the highest greenhouse gas emissions and fossil fuel demand. In contrast BEV show better environmental performance than conventional powertrains especially when powered by photovoltaics. When powered by photovoltaics BEV reveal similar results to FCEV in terms of environmental impacts except for resource depletion where both perform poorly. Transitioning from diesel to BEV or FCEV can enhance local air quality regardless of the energy source. The economic analysis indicates that FCEV are the most expensive option followed by BEV both of which are currently costlier than diesel and CNG systems. CBM from waste streams emerges as a cost-effective and environmentally friendly solution. This study suggests prioritizing biomethane derived from biowaste manure and residual biomass (excluding energy crops) as a part of the fuels for public transport decarbonization in the EU to advance EU decarbonization goals despite limitations due to resource availability. Furthermore BEV powered by renewables should be prioritized whenever their range is adequate.

To enable hydrogen-powered aircraft operations liquid hydrogen infrastructure has to be planned well in advance. This study analyses the transition pathway of liquid hydrogen supply infrastructure from the initial development phase to market penetration optimizing the design and dispatch of the system. The findings reveal that the single-year approach used in previous studies significantly underestimates the costs associated with supply infrastructure. During the transition phase substantial investments are required in specific years leading to high supply costs particularly in the early years. Off-take agreements could be used to achieve a more balanced cost distribution. For the considered location of a generic airport on-site liquid hydrogen supply costs range between 3.83 and 5.03 USD/kgH2 assuming a long-term supply agreement. At a less favourable airport supply costs are 29% higher compared to a favourable location. However costs could be reduced by up to 12% if hydrogen is imported via vessels or the European Hydrogen Backbone. The primary factors influencing supply costs are the availability of renewable energy resources and the distances to the nearest port as well as hydrogen production hubs. Therefore the optimal supply chain must be assessed individually for each airport. Overall this study provides insights and a methodology that can support the development of future liquid hydrogen infrastructure roadmaps for hydrogen-powered aviation.

Today hydrogen (H2) is overwhelmingly produced through steam methane reforming (SMR) of natural gas which emits about 12 kg of carbon dioxide (CO2) for 1 kg of H2 (∼12 kg-CO2/kg-H2). Water electrolysis offers an alternative for H2 production but today’s electrolyzers consume over 55 kWh of electricity for 1 kg of H2 (>55 kWh/kg-H2). Electric grid-powered water electrolysis would emit less CO2 than the SMR process when the carbon intensity for grid power falls below 0.22 kg-CO2/kWh. Solar- and wind-powered electrolytic H2 production promises over 80% CO2 reduction over the SMR process but large-scale (megawatt to gigawatt) direct solar- or wind-powered water electrolysis has yet to be demonstrated. In this paper several approaches for solar-powered electrolysis are analyzed: (1) coupling a photovoltaic (PV) array with an electrolyzer through alternating current; (2) direct-current (DC) to DC coupling; and (3) direct DC-DC coupling without a power converter. Co-locating a solar or wind farm with an electrolyzer provides a lower power loss and a lower upfront system cost than long-distance power transmission. A load-matching PV system for water electrolysis enables a 10%–50% lower levelized cost of electricity than the other systems and excellent scalability from a few kilowatts to a gigawatt. The concept of maximum current point tracking is introduced in place of maximum power point tracking to maximize the H2 output by solarpowered electrolysis.

Hydrogen fueling stations are critical infrastructure for deploying zero emission hydrogen fuel cell electric vehicles (FCEV). Stations with greater dispensing capacities and higher energy efficiency are needed and cryogenic liquid hydrogen (LH2) has the potential to meet these needs. It is necessary to ensure that hazards and risks are appropriately identified and managed. This paper presents a Quantitative Risk Assessment (QRA) methodology for high-capacity (dispensing >1000 kg/day) hydrogen fueling stations with liquid hydrogen storage and presents the application of that methodology by presenting a Failure Mode and Effect Analysis (FMEA) and data curation for the design developed for this study. This methodology offers a basis for risk and reliability evaluation of these systems as their designs evolve and as operational data becomes available. We developed a generic station design and process flow diagram for a high-capacity hydrogen fueling station with LH2 storage. Following the system description is hazard identification done from FMEA to identify the causes of hydrogen releases and the critical components causing the releases. Finally data collection and curation is discussed including challenges stemming from the limited public availability of reliability data on components used in liquid hydrogen systems. This paper acts as an introduction to the full QRA presented in its companion paper Schaad et al. [1].

This report by the Clean Energy Technology Observatory (CETO) provides an updated strategic analysis of the EU clean energy technology sector. The EU's renewable share in gross final energy consumption rose to 24.5% in 2023 and to 44.7% of gross electricity consumption. The electrification rate however has remained almost unchanged at 26% over the decade to 2023 indicating slow progress on decarbonisation of transport and heating sectors. The EU renewable energy industry saw growth in turnover and gross value added in 2023 outperforming the overall economy. However the production value of clean energy technologies declined in some areas such as bioenergy PV and hydrogen electrolyser production. EU public investment in energy research and innovation has increased but it remains lower as a share of GDP compared to other major economies. Employment in the renewable energy sector reached 1.7 million in 2022 growing at a faster rate than the economy as a whole. The clean energy sector however faces challenges in manufacturing. A new sustainability assessment framework has been applied for clean energy technologies highlighting the need for a harmonized basis for comparing results. The report also underscores the general need to improve data quality and timeliness to better inform policy makers and investors.

To mitigate challenges arising from renewable energy volatility and multi-energy load uncertainty this paper introduces a dynamic hydrogen blending (DHB) strategy for an integrated energy system. The strategy is categorized into Continuous Hydrogen Blending (CHB) and Time-phased Hydrogen Blending (THB) based on the temporal variations in the hydrogen blending ratio. To evaluate the regulatory effect of DHB on uncertainty a datadriven distributionally robust optimization method is employed in the day-ahead stage to manage system uncertainties. Subsequently a hierarchical model predictive control framework is designed for the intraday stage to track the day-ahead robust scheduling outcomes. Experimental results indicate that the optimized CHB ratio exhibits step characteristics closely resembling the THB configuration. In terms of cost-effectiveness CHB reduces the day-ahead scheduling cost by 0.87% compared to traditional fixed hydrogen blending schemes. THB effectively simplifies model complexity while maintaining a scheduling performance comparable to CHB. Regarding tracking performance intraday dynamic hydrogen blending further reduces upper- and lower-layer tracking errors by 4.25% and 2.37% respectively. Furthermore THB demonstrates its advantage in short-term energy regulation effectively reducing tracking errors propagated from the upper layer MPC to the lower layer resulting in a 2.43% reduction in the lower-layer model’s tracking errors.

In response to the greenhouse gas (GHG) reduction targets set by the Paris Agreement green hydrogen has become a key solution for global decarbonisation. However research on the design of green hydrogen production facilities remains limited particularly in Brazil. This study bridges this gap by developing a comprehensive design for a green hydrogen production plant powered by an 81 MW photovoltaic (PV) system in Ceará Brazil. The facility layout equipment sizing and resource requirements were determined using the Systematic Layout Planning (SLP) method based on the available energy for daily hydrogen production. The design also integrates safety regulations including local standards in Ceará as well as raw material needs and production capacity. This study delivers a detailed facility layout specifying equipment placement and capacity based on the PV plant’s output while ensuring compliance with safety protocols. This research contributes to the green hydrogen literature by providing a structured methodology for facility design serving as a reference for future projects and fostering the advancement of green hydrogen technology particularly in developing countries.

The development of liquid hydrogen storage systems is a key aspect to enable future clean air transportation. However safety analysis research for such systems is still limited and is hindered by the limited experience with liquid hydrogen storage in aviation. This paper presents the outcomes of a preliminary safety assessment applied to this new type of storage system accounting for the hazards of hydrogen. The methodology developed is based on hazard identification and frequency evaluation across all system features to identify the most critical safety concerns. Based on the safety assessment a set of safety recommendations concerning different subsystems of the liquid hydrogen storage system is proposed identifying hazard scopes and necessary mitigation actions across various system domains. The presented approach has been proven to be suitable for identifying essential liquid hydrogen hazards despite the novelty of the technology and for providing systematic design recommendations at a relatively early design stage.

This study investigates the potential for establishing a self-sufficient renewable hydrogen production facility utilising a floating photovoltaic (FPV) system on an artificial irrigation reservoir located in a small municipality in southern Italy. The analysis examines the impact of different system configurations and operating conditions on the technical economic and environmental performance with a particular focus on hydrogen production and water conservation resulting from reduced evaporation. Different sizes of the FPV plant are considered with and without a tracking system. The electrolyser performance is evaluated under both fixed and variable load conditions also considering the integration of battery storage to ensure consistent operation. The findings indicate that the adoption of the largest FPV plant can result in the conservation of approximately 1.87 million m3 of water annually while simultaneously producing up to 4199 tons of hydrogen per year in variable load mode—more than twice the output compared to fixed load conditions. Although battery integration increases hydrogen production it also leads to higher investment and maintenance costs. Therefore the variable load operation emerges as the most economically viable option reducing the levelized cost of hydrogen (LCOH) to €13.18/kg a 26 % reduction compared to fixed load operation. Moreover the implementation of a vertical axis tracking system leads to only marginal LCOH reductions (maximum 2.2 %) and does not justify the additional complexity. In all tested scenarios the system proves to be self-sustaining. Given the case study’s location in southern Italy—where a pilot project for fuel cell–battery hybrid trains is underway—the hydrogen produced is assumed to be used for railway applications as a possible offtaker. The analysis shows that the potential of the system in terms of hydrogen production is much higher (tens of times) than the estimated demand of the present hydrogen railway configuration thus suggesting that a significant expansion of the number of trains and routes served could be considered. Although this work is based on a specific case study its key findings are potentially replicable in other contexts—particularly in Mediterranean or semi-arid regions where water scarcity may otherwise act as a limiting factor for the deployment of hydrogen production systems.

Fuel cells have become a fundamental technology in the development of clean energy systems playing a vital role in the global shift toward a low-carbon future. With the growing need for sustainable hydrogen production perfluoro sulfonic acid (PFSA) ionomer membranes play a critical role in optimizing green hydrogen technologies and fuel cells. This study aims to investigate the effects of different environmental and solvent treatments on the chemical and physical properties of Nafion N−115 membranes to evaluate their suitability for both hydrogen production in proton exchange membrane (PEM) electrolyzers and hydrogen utilization in fuel cells supporting integrated applications in the local and global green hydrogen economy. To achieve this Nafion N−115 membranes were partially dissolved in various solvent mixtures including ethanol/isopropanol (EI) isopropanol/water (IW) dimethylformamide/N-methyl-2-pyrrolidone (DN) and ethanol/methanol/isopropanol (EMI) evaluated under water immersion and thermal stress and characterized for chemical stability mechanical strength water uptake and proton conductivity using advanced electrochemical and spectroscopic techniques. The results demonstrated that the EMI-treated membrane showed the highest proton conductivity and maintained its structural integrity making it the most promising for hydrogen electrolysis applications. Conversely the DN-treated membrane exhibited reduced stability and lower conductivity due to solvent-induced degradation. This study highlights the potential of EMI as an optimal solvent mixture for enhancing PFSA membranes performance in green hydrogen production contributing to the advancement of sustainable energy solutions.

: Hydrogen is a clean non-polluting fuel and a key player in decarbonizing the energy sector. Interest in hydrogen production has grown due to climate change concerns and the need for sustainable alternatives. Despite advancements in waste-to-hydrogen technologies the efficient conversion of mixed plastic waste via an integrated thermochemical process remains insufficiently explored. This study introduces a novel multi-stage pyrolysis-reforming framework to maximize hydrogen yield from mixed plastic waste including polyethylene (HDPE) polypropylene (PP) and polystyrene (PS). Hydrogen yield optimization is achieved through the integration of two water–gas shift reactors and a pressure swing adsorption unit enabling hydrogen production rates of up to 31.85 kmol/h (64.21 kg/h) from 300 kg/h of mixed plastic wastes consisting of 100 kg/h each of HDPE PP and PS. Key process parameters were evaluated revealing that increasing reforming temperature from 500 ◦C to 1000 ◦C boosts hydrogen yield by 83.53% although gains beyond 700 ◦C are minimal. Higher reforming pressures reduce hydrogen and carbon monoxide yields while a steam-to-plastic ratio of two enhances production efficiency. This work highlights a novel scalable and thermochemically efficient strategy for valorizing mixed plastic waste into hydrogen contributing to circular economy goals and sustainable energy transition.

Ports are critical hubs in the global supply chain yet they face mounting challenges in achieving carbon neutrality. Port Integrated Multi-Energy Systems (PIMESs) offer a comprehensive solution by integrating renewable energy sources such as wind photovoltaic (PV) hydrogen and energy storage with traditional energy systems. This study examines the implementation of a real-word PIMES showcasing its effectiveness in reducing energy consumption and emissions. The findings indicate that in 2024 the PIMES enabled a reduction of 1885 tons of CO2 emissions with wind energy contributing 84% and PV 16% to the total decreases. The energy storage system achieved a charge–discharge efficiency of 99.15% while the hydrogen production system demonstrated an efficiency of 63.34% producing 503.87 Nm3/h of hydrogen. Despite these successes challenges remain in optimizing renewable energy integration expanding storage capacity and advancing hydrogen technologies. This paper highlights practical strategies to enhance PIMESs’ performances offering valuable insights for policymakers and port authorities aiming to balance energy efficiency and sustainability and providing a blueprint for carbon-neutral port development worldwide.

The purpose of this Hydrogen Pipeline System COP is to provide guidance based on current knowledge for the design construction and operation of transmission pipeline systems transporting gaseous hydrogen or blends of hydrogen and hydrocarbon fluids.<br/>The objective of the code is to provide guidance for the safe reliable and efficient transportation and storage of hydrogen in transmission pipeline systems that are required to conform to the AS(/NZS) 2885 series. The document also references adoption of other international codes where suitable guidance is available.<br/>This document is intended to be updated with revised design criteria and methods as research and experience improves the understanding of hydrogen service in transmission pipelines. Although the CoP may be further developed into a published standard in the future within the AS(/NSZ) 2885 series framework this current revision of the CoP is not equivalent to a formal published Australian standard. The document also includes expanded commentary and background information as an informative code of practice that is more extensive than is typically covered in a standard.

Hydrogen is emerging as a crucial energy source in the global effort to reduce dependence on fossil fuels and meet climate goals. Integrating hydrogen into Integrated Assessment Models (IAMs) is essential for understanding its potential and guiding policy decisions. These models simulate various energy scenarios assess hydrogen’s impact on emissions and evaluate its economic viability. However uncertainties surrounding hydrogen technologies must be effectively addressed in their modeling. This review examines how different IAMs incorporate hydrogen technologies and their implications for decarbonization strategies and policy development considering underlying uncertainties. We begin by analyzing the configuration of the hydrogen supply chain focusing on production logistics distribution and utilization. The modeling characteristics of hydrogen integration in 12 IAM families are explored emphasizing hydrogen’s growing significance in stringent climate mitigation scenarios. Results from the literature and the AR6 database reveal gaps in the modeling of the hydrogen supply chain particularly in storage transportation and distribution. Model characteristics are critical in determining hydrogen’s share within the energy portfolio. Additionally this study underscores the importance of addressing both parametric and structural uncertainties in IAMs which are often underestimated leading to varied outcomes regarding hydrogen’s role in decarbonization strategies.