Policy & Socio-Economics

The global green hydrogen rush is prone to repeat extractivist patterns at the expense of economies ecologies and communities in the production zones in the Global South. With a socio-ecological risk analysis grounded in energy water and environmental justice scholarship we systematically assess the risks of the ‘green’ hydrogen transition and related injustices arising in 28 countries in the Global South with regard to energy water land and global justice dimensions. Our findings show that risks materialize through the exclusion of affected communities and civil society the enclosure of land and resources for extractivist purposes and through the externalization of socio-ecological costs and conflicts. We further demonstrate that socio-ecological risks are enhanced through country-specific conditions such as water scarcity historical continuities such as post-colonial land tenure systems as well as repercussions of a persistently uneven global politico-economic order. Contributing to debates on power inequality and justice in the global green hydrogen transition we argue that addressing hydrogen risks requires a framework of environmental justice and a transformative perspective that encompasses structural shifts in the global economy including degrowth and a decentering of industrial hegemonies in the Global North.

The high potential in renewable energy sources (RES) and the availability of strategic minerals for green hydrogen technologies place Africa in a promising position for the development of a climate-compatible economy leveraging on hydrogen. This study reviews the potential hydrogen value chain in Africa considering production and final uses while addressing perspectives on policies possible infrastructures and facilities for hydrogen logistics. Through scientific studies research and searching in relevant repositories this review features the collection analysis of technical data and georeferenced information about key aspects of the hydrogen value chain. Detailed maps and technical data for gas transport infrastructure and liquefaction terminals in the continent are reported to inform and elaborate findings about readiness for hydrogen trading and domestic use in Africa. Specific maps and technical data have been also collected for the identification of potential hydrogen offtakers focusing on individual industrial installations to produce iron and steel chemicals and oil refineries. Finally georeferenced data are presented for main road and railway corridors as well as for most important African ports as further end-use and logistic platforms. Beyond technical information this study collects and discusses more recent perspectives about policies and implementation initiatives specifically addressing hydrogen production logistics and final use also introducing potential criticalities associated with environmental and social impacts.

Life cycle assessment which evaluates the complete life cycle of a product is considered the standard methodological framework to evaluate the environmental performance of climate change solutions. However significant challenges exist related to datasets used to quantify these environmental indicators. Although extensive research and commercial data on climate change technologies pathways and facilities exist they are not readily available to practitioners of life cycle assessment in the right format and structure using an open platform. In this study we propose a new open data hub platform for life cycle assessment considering a hierarchical data flow starting with raw data collected on climate change technologies at laboratory pilot demonstration or commercial scales to provide the information required for policy and decision-making. This platform makes data accessible at multiple levels for practitioners of life cycle assessment while making data interoperable across platforms. The proposed data hub platform and workflow are explained through the polymer electrolyte membrane electrolysis hydrogen production as a case study. The climate change environment impact of 1.17 ± 0.03 kg CO2 eq./kg H2 was calculated for the case study. The current data hub platform is limited to evaluating environmental impacts; however future additions of economic and social aspects are envisaged.

Hydrogen energy is critical in replacing fossil fuels and achieving net zero carbon emissions by 2050. Three measures can be implemented to promote hydrogen energy: reduce the cost of low-carbon hydrogen through technological improvements increase the production capacity of low-carbon hydrogen by stimulating investment and enhance hydrogen use as an energy carrier and in industrial processes by demand-side policies. This article examines how effective these measures are if successfully implemented in boosting the hydrogen market and reducing global economy-wide carbon emissions using a global computable general equilibrium model. The results show that all the measures increase the production and use of low-carbon hydrogen whether implemented alone or jointly. Notably the emissions reduced by joint implementation of all the measures in 2050 become 2.5 times the sum of emissions reduced by individual implementation indicating a considerable multiplier effect. This suggests supply and demand side policies be implemented jointly to maximize their impact on reducing emissions.

This review aims to enhance the understanding of the fundamentals applications and future directions in hydrogen production techniques. It highlights that the hydrogen economy depends on abundant non-dispatchable renewable energy from wind and solar to produce green hydrogen using excess electricity. The approach is not limited solely to existing methodologies but also explores the latest innovations in this dynamic field. It explores parameters that influence hydrogen production highlighting the importance of adequately controlling the temperature and concentration of the electrolytic medium to optimize the chemical reactions involved and ensure more efficient production. Additionally a synthesis of the means of transport and materials used for the efficient storage of hydrogen is conducted. These factors are essential for the practical feasibility and successful deployment of technologies utilizing this energy resource. Finally the technological innovations that are shaping the future of sustainable use of this energy resource are emphasized presenting a more efficient alternative compared to the fossil fuels currently used by society. In this context concrete examples that illustrate the application of hydrogen in emerging technologies are highlighted encompassing sectors such as transportation and the harnessing of renewable energy for green hydrogen production.

Can Norway be an important hydrogen exporter to the European Union (EU) by 2030? We explore three scenarios in which Norway’s hydrogen export market may develop: A Business-as-usual B Moderate Onshore C Accelerated Offshore. Applying a sector-coupled energy system model we examine the techno-economic viability spatial and socio-economic considerations for blue and green hydrogen export in the form of ammonia by ship. Our results estimate the costs of low-carbon hydrogen to be 3.5–7.3€/kg hydrogen. While Norway may be cost-competitive in blue hydrogen exports to the EU its sustainability is limited by the reliance on natural gas and the nascent infrastructure for carbon transport and storage. For green hydrogen exports Norway may leverage its strong relations with the EU but is less cost-competitive than countries like Chile and Morocco which benefit from cheaper solar power. For all scenarios significant land use is needed to generate enough renewable energy. Developing a green hydrogen-based export market requires policy support and strategic investments in technology infrastructure and stakeholder engagement ensuring a more equitable distribution of renewable installations across Norway and national security in the north. Using carbon capture and storage technologies and offshore wind to decarbonise the offshore platforms is a win-win solution that would leave more electricity for developing new industries and demonstrate the economic viability of these technologies. Finally for Norway to become a key hydrogen exporter to the EU will require a balanced approach that emphasises public acceptance and careful land use management to avoid costly consequences.

The defossilization of industry has far-reaching implications regarding the future demand for hydrogen and other forms of energy. This paper presents and applies a fundamental bottom-up model that relies on techno-economic data of industrial production processes. Its aim is to identify across a range of scenarios the most cost-effective low-carbon options considering a variety of production systems. Subsequently it derives the hydrogen and electricity demand that would result from the implementation of these least-cost low-carbon options in process industries in Germany. Aligning with the German government's target year for achieving climate neutrality this study’s reference year is 2045. The primary contribution lies in analyzing which hydrogen-based and direct electrification solutions would be cost-effective for a range of energy price levels under climate-neutral industrial production and what the resulting hydrogen and electricity demand would be. To this end the methodology of this paper comprises the following steps: selection of the relevant industries (I) definition of conventional reference production systems and their low-carbon options (II) investigation and processing of the techno-economic data of the standardized production systems (III) establishment of a scenario framework (IV) determination of the least-cost low-carbon solution of a conventional reference production system under the scenario assumptions made (V) and estimation of the resulting hydrogen and electricity demand (VI). According to the results the expected industrial hydrogen consumption in 2045 ranges from 255 TWh for higher hydrogen prices in or above the range of onshore wind-based green hydrogen supply costs to up to 542 TWh for very low hydrogen prices corresponding to typical blue hydrogen production costs. Meanwhile the direct electricity consumption of the process industries in the results ranges from 122 TWh for these rather low hydrogen prices to 368 TWh for the higher hydrogen prices in the region of or above the hydrogen supply costs from the electrolysis of energy from an onshore wind farm. Most of the break-even hydrogen prices that are relevant to the choice of low-carbon options are in the range of the benchmark purchase costs for blue hydrogen and green hydrogen produced from offshore wind power which span between €40 per MWh and €97 per MWh.

The Gulf Cooperation Council (GCC) comprising: Saudi Arabia United Arab Emirates Kuwait Qatar Oman and Bahrain is home to an abundant number of resources including natural gas and solar and wind energy (renewables). Because of this the region is favourably positioned to become a significant player in both blue and green hydrogen production and their export. Current dependence on fossil fuels and ambitious national targets for decarbonisation have led the region and world to research the feasibility of switching to a hydrogen economy. This literature review critically examines the current advantages and strategies adopted by the GCC to expedite the implementation of hydrogen supply chains as well as investigation into the methodologies employed in current research for the modelling and optimisation of hydrogen supply chains. Insight into these endeavours is critical for stakeholders to assess the inherent challenges and opportunities in establishing a sustainable hydrogen economy. Despite a substantial global effort establishing a solid hydrogen supply chain presently faces various obstacles including the costs of clean hydrogen production. Scaling-up storage and transport methods is an issue that affects all types of hydrogen including carbon-intensive (grey) hydrogen. However the current costs of green hydrogen production mostly via the process of electrolysis is a major obstacle hindering the widescale deployment of clean hydrogen. Research in this literature review found that compressed gas and cryogenic liquid options have the highest storage capacities for hydrogen of 39.2 and 70.9 kg/m3 respectively. Meanwhile for hydrogen transportation pipelines and cryogenic tankers are the most conventional and efficient options with an efficiency of over 99 %. Cryogenic ships to carry liquid hydrogen also show potential due to their large storage capacities of 10000 tonnes per shipment However costs per vessel are currently still very expensive ranging between $ 465 and $620 million.

The Clean Energy Technology Research Institute (CETRI) at the University of Regina Canada serves as a collaborative hub where a dynamic team of researchers industry leaders innovators and educators come together to tackle the urgent challenges of climate change and the advancement of clean energy technologies. Specializing in low-carbon and carbon-free clean energy research CETRI adopts a unique approach that encompasses feasibility studies bench-scale and pilot-plant testing and pre-commercial demonstrations all consolidated under one roof. This holistic model distinguishes CETRI fostering a diverse and inclusive environment for technical scientific and hands-on learning experiences. With a CAD 3.3 million pre-commercial carbon capture demonstration plant capable of capturing 1 tonne of CO2 per day and a feed-flexible hydrogen demonstration pilot plant producing 6 kg of hydrogen daily CETRI emerges as a pivotal force in advancing innovative reliable and cost-competitive clean energy solutions essential for a safe prolific and sustainable world. This paper provides a comprehensive overview of the diverse and impactful research carried out in the center spanning various areas including decarbonization zeroemission hydrogen technologies carbon (CO2 ) capture utilization and storage the conversion of waste into renewable fuels and chemicals and emerging technologies such as small modular nuclear reactors and microgrids.

The Mediterranean basin has been characterized by a net flow of fossil commodities from the North African shore to Southern Europe and the Middle East for decades; however decarbonizing the energy system implies to substantially modify this situation turning the current “black dialogue” into a “green dialogue” (i.e. based on the exchange of renewable electricity and green hydrogen). This paper presents a feasibility study conducted to estimate the potential green hydrogen production by electrolysis in three Tunisian sites. It shows and compares several plant layouts varying the size and typology of renewable electricity generators and electrolyzers. The work adopts local weather data and technical features of the technologies in the computations and accounts for site specific topographical and infrastructural constraints such as land available for construction and local power grid connection capacities. It shows that configurations able to produce large quantities of green hydrogen may not be compliant with such constraints basically nullifying their contribution in any hydrogen strategy. Finally results show that the LCOH lies in the range 1.34 $/kgH2 and 4.06 $/kgH2 depending on both the location and the combination of renewable electricity generators and electrolyzers.