Applications & Pathways

Alternative energy resources have a significant function in the performance and decarbonization of power engendering schemes in the building application domain. Additionally “green buildings” play a special role in reducing energy consumption and minimizing CO2 emissions in the building sector. This research article analyzes the performance of alternative primary energy sources (sun and hydrogen) integrated into a hybrid photovoltaic panel/fuel cell system and their optimal synergy to provide green energy for a green building. The study addresses the future hydrogen-based economy which involves the supply of hydrogen as the fuel needed to provide fuel cell energy through a power distribution infrastructure. The objective of this research is to use fuel cells in this field and to investigate their use as a green building energy supply through a hybrid electricity generation system which also uses photovoltaic panels to convert solar energy. The fuel cell hydrogen is supplied through a distribution network in which hydrogen production is outsourced and independent of the power generation system. The case study creates virtual operating conditions for this type of hybrid energy system and simulates its operation over a one-year period. The goal is to demonstrate the role and utility of fuel cells in virtual conditions by analyzing energy and economic performance indicators as well as carbon dioxide emissions. The case study analyzes the optimal synergy between photovoltaic panels and fuel cells for the power supply of a green building. In the simulation an optimally configured hybrid system supplies 100% of the energy to the green building while generating carbon dioxide emissions equal to 11.72% of the average value calculated for a conventional energy system providing similar energy to a standard residential building. Photovoltaic panels account for 32% of the required annual electricity production and the fuel cells generate 68% of the total annual energy output of the system.

Hydrogen is the cleanest fuel available because its combustion product is water. The internal combustion engine can in principle and without significant modifications run on hydrogen to produce mechanical energy. Regarding the technological solution leading to compact engines a question to ask is the following: Can combustion engine systems be lubricated with hydrogen? In general since many applications such as in turbomachines is it possible to use the surrounding gas as a lubricant? In this paper journal bearings global parameters are calculated and compared for steady state and dynamic conditions for different gas constituents such as air pentafluoropropane helium and hydrogen. Such a bearing may be promising as an ecological alternative to liquid lubrication.

Hydrogen Mobility Europe (H2ME 2015–2022) is the largest European Fuel Cells and Hydrogen Joint Undertaking (EU FCH JU)-funded hydrogen light vehicle and infrastructure demonstration. Up until April 2017 the 40 Daimler passenger car fuel cell electric vehicles (FCEVs) and 62 Symbio Fuel Cell-Range Extended Electric Vans (FC-REEV)-vans deployed by the project drove 625300 km and consumed a total of 7900 kg of hydrogen with no safety incidents. During its first year of operation (to April 2017) the NEL Hydrogen Fueling HRS (hydrogen refuelling station) in Kolding Denmark dispensed 900 kg of hydrogen and demonstrated excellent reliability (98.2% availability) with no safety incidents. The average hydrogen refuelling time for passenger cars is comparable to that for conventional vehicles (2–3 min).

The 30 integrated steel plants operating in the European Union (EU) are among the largest single-point CO₂ emitters in the region. The deployment of bioenergy with carbon capture and storage (bio-CCS) could significantly reduce their emission intensities. In detail the results demonstrate that CO₂ emission reduction targets of up to 20% can be met entirely by biomass deployment. A slow CCS technology introduction on top of biomass deployment is expected as the requirement for emission reduction increases further. Bio-CCS could then be a key technology particularly in terms of meeting targets above 50% with CO₂ avoidance costs ranging between €60 and €100 tCO2−1 at full-scale deployment. The future of bio-CCS and its utilisation on a larger scale would therefore only be viable if such CO₂ avoidance cost were to become economically appealing. Small and medium plants in particular would economically benefit from sharing CO₂ pipeline networks. CO₂ transport however makes a relatively small contribution to the total CO₂ avoidance cost. In the future the role of bio-CCS in the European iron and steelmaking industry will also be influenced by non-economic conditions such as regulations public acceptance realistic CO₂ storage capacity and the progress of other mitigation technologies.

Hydrogen is often touted as the fuel of the future but hydrogen is already an important feedstock for the chemical industry. This review highlights current means for hydrogen production and use and the importance of progressing R&D along key technologies and policies to drive a cost reduction in renewable hydrogen production and enable the transition of chemical manufacturing toward green hydrogen as a feedstock and fuel. The chemical industry is at the core of what is considered a modern economy. It provides commodities and important materials e.g. fertilizers synthetic textiles and drug precursors supporting economies and more broadly our needs. The chemical sector is to become the major driver for oil production by 2030 as it entirely relies on sufficient oil supply. In this respect renewable hydrogen has an important role to play beyond its use in the transport sector. Hydrogen not only has three times the energy density of natural gas and using hydrogen as a fuel could help decarbonize the entire chemical manufacturing but also the use of green hydrogen as an essential reactant at the basis of many chemical products could facilitate the convergence toward virtuous circles. Enabling the production of green hydrogen at cost could not only enable new opportunities but also strengthen economies through a localized production and use of hydrogen. Herein existing technologies for the production of renewable hydrogen including biomass and water electrolysis and methods for the effective storage of hydrogen are reviewed with an emphasis on the need for mitigation strategies to enable such a transition.

Hydrogen produced with renewable energy sources – or “green” hydrogen – has emerged as a key element to achieve net-zero emissions from heavy industry and transport. Along with net-zero commitments by growing numbers of governments green hydrogen has started gaining momentum based on low-cost renewable electricity ongoing technological improvements and the benefits of greater power-system flexibility.



Hydrogen-based fuels previously attracted interest mainly as an alternative to shore up oil supply. However green hydrogen as opposed to the “grey” (fossil-based) or “blue” (hybrid) varieties also help to boost renewables in the energy mix and decarbonise energy-intensive industries.



This report from the International Renewable Energy Agency (IRENA) outlines the main barriers that inhibiting green hydrogen uptake and the policies needed to address these. It also offers insights on how to kickstart the green hydrogen sector as a key enabler of the energy transition at the national or regional level.



Key pillars of green hydrogen policy making include:

• National hydrogen strategy. Each country needs to define its level of ambition for hydrogen outline the amount of support required and provide a reference on hydrogen development for private investment and finance.
• Setting policy priorities. Green hydrogen can support a wide range of end-uses. Policy makers should identify and focus on applications that provide the highest value.
• Guarantees of origin. Carbon emissions should be reflected over the whole lifecycle of hydrogen. Origin schemes need to include clear labels for hydrogen and hydrogen products to increase consumer awareness and facilitate claims of incentives.
• Governance system and enabling policies. As green hydrogen becomes mainstream policies should cover its integration into the broader energy system. Civil society and industry must be involved to maximise the benefits.
• Subsequent briefs will explore the entire hydrogen value chain providing sector-by-sector guidance on the design and implementation of green hydrogen policies.

The Fuel Cell Industry Review 2020 offers data analysis and commentary on key events in the industry in 2020. Now in its seventh year the Review has been compiled by a team led by E4tech - a specialist energy strategy consultancy with deep expertise in the hydrogen and fuel cell sector (see www.e4tech.com).



Despite the title of this publication we’ve said before that the fuel cell ‘industry’ is not a single industry at all. As those inside it know it is divided by different materials stages of maturity applications and regions – all contributors to the fact it has taken time to get going. But it does seem to be getting traction. Part of that is down to decades of hard work and investment in R&D technology improvement and demonstrations. Thankfully part of it is also down to changes in external conditions. Improving air quality is increasingly non-negotiable. Reducing greenhouse gas emissions likewise. And all while maintaining economic development and opportunity.



The growth spurt of the battery industry allied with some of the drivers above has catalysed thinking in where and how fuel cells can fit. Countries and regions which did not support batteries early on are scrambling to catch up and wish not to risk a repeat of their errors with fuel cells. So support is being targeted at industrial development and competitiveness as well as solving societal problems. Which in turn is helping industry to decide on and take investment steps: Weichai’s 20000 unit per annum PEM factory in China; Daimler and Volvo setting up their fuel cell truck JV; CHEM Energy building a factory for remote systems in S Africa."

The increasing ambition of climate targets creates a major role for hydrogen especially in achieving carbon-neutrality in sectors presently difficult to decarbonise. This work examines to what extent the currently carbon-intensive hydrogen production in Europe could be replaced by water electrolysis using electricity from renewable energy resources (RES) such as solar photovoltaic onshore/offshore wind and hydropower (green hydrogen). The study assesses the technical potential of RES at regional and national levels considering environmental constraints land use limitations and various techno-economic parameters. It estimates localised clean hydrogen production and examines the capacity to replace carbon-intensive hydrogen hubs with ones that use RES-based water electrolysis. Findings reveal that -at national level- the available RES electricity potential exceeds the total electricity demand and the part for hydrogen production from electrolysis in all analysed countries. At regional level from the 109 regions associated with hydrogen production (EU27 and UK) 88 regions (81%) show an excess of potential RES generation after covering the annual electricity demand across all sectors and hydrogen production. Notably 84 regions have over 50% excess RES electricity potential after covering the total electricity demand and that for water electrolysis. The study provides evidence on the option to decarbonize hydrogen production at regional level. It shows that such transformation is possible and compatible with the ongoing transition towards carbon–neutral power systems in the EU. Overall this work aims to serve as a tool for designing hydrogen strategies in harmony with renewable energy policies.

This paper proposes a novel hybrid marine renewable energy-harvesting system to increase energy production reduce levelized costs of energy and promote renewable marine energy. Firstly various marine renewable energy resources and state-of-art technologies for energy exploitation and storage were reviewed. The site selection criteria for each energy-harvesting approach were identified and a scoring matrix for site selection was proposed to screen suitable locations for the hybrid system. The Triton Knoll wind farm was used to demonstrate the effectiveness of the scoring matrix. An integrated energy system was designed and FE modeling was performed to assess the effects of additional energy devices on the structural stability of the main wind turbine structure. It has been proven that the additional energy structures have a negligible influence on foundation/structure deflection.

Wind and solar energies present a time and space disparity that generally leads to a mismatch between the demand and the supply. To harvest their maximum potentials one of the main challenges is the storage and transport of these energies. This challenge can be tackled by electrofuels such as hydrogen methane and methanol. They offer three main advantages: compatibility with existing distribution networks or technologies of conversion economical storage solution for high capacity and ability to couple sectors (i.e. electricity to transport to heat or to industry). However the level of contribution of electric-energy carriers is unknown. To assess their role in the future we used whole-energy system modelling (EnergyScope Typical Days) to study the case of Belgium in 2050. This model is multi-energy and multi-sector. It optimises the design of the overall system to minimise its costs and emissions. Such a model relies on many parameters (e.g. price of natural gas efficiency of heat pump) to represent as closely as possible the future energy system. However these parameters can be highly uncertain especially for long-term planning. Consequently this work uses the polynomial chaos expansion method to integrate a global sensitivity analysis in order to highlight the influence of the parameters on the total cost of the system. The outcome of this analysis points out that compared to the deterministic cost-optimum situation the system cost accounting for uncertainties becomes higher (+17%) and twice more uncertain at carbon neutrality and that electrofuels are a major contribution to the uncertainty (up to 53% in the variation of the costs) due to their importance in the energy system and their high uncertainties their higher price and uncertainty.