Green hydrogen has become more prevalent as a fundamental element for decarbonizing energy sectors, particularly in countries with abundant renewable resources. This review paper aims to investigate and explore the current status of green hydrogen production initiatives and their future vision, considering the country’s remarkable advancements in renewable energy and its valuable location for exports. A comprehensive review of recent and ongoing projects on both local and global levels was presented, along with the renewable energy profile and water resources required for the electrolysis process. The study estimated the levelized cost of hydrogen per region, as well as the cost of desalinated seawater, and identified a suitable location in the kingdom based on renewable resources and land constraints, in line with recent memoranda of understanding by the Ministry of Energy and Mineral Resources. Jordan’s green hydrogen LCOH ranges between $6.5–7.6/kg H₂, with desalinated water costs of $0.9/m³. The national strategy targets 0.5 Mt H₂ export by 2035, primarily for ammonia production and achieving a cost of $2–3/kg H₂ by 2050. A national certification scheme following EU carbon intensity standards (< 3.4 kg CO₂/kg H₂) is under preparation.

International green hydrogen regulations, standards, and guidelines are reviewed to assess their applicability to the Jordanian context. The analysis covers European Union directives, ISO and IEC standards, and best practices drawn from Germany, Japan, and Saudi Arabia. A gap analysis is conducted against Jordan's Draft National Hydrogen Strategy (2023) and the World Bank's 2025 policy note. Five regulatory gaps are identified: the absence of a dedicated hydrogen code, missing certification and quality standards, incomplete safety and technical codes, undefined infrastructure regulations, and weak policy integration. A two-phase adaptation roadmap is proposed, covering 2025 to 2030 and 2030 to 2050. Legislative reform, institutional capacity building, and regional cooperation are recommended to position Jordan as a green hydrogen production and export hub.

The steel sector is considered one of the industrial sectors that contributes significantly to the global carbon emissions ratio. This study examines the potential for decarbonizing Jordan’s steel industry, with a particular focus on the Rammallah steel factory (RAMCO), which utilizes an electrical arc furnace (EAF) to melt and shape steel scrap into steel structures. The research examines the integration of green hydrogen in the steel industry produced by solar energy that operates alongside the electrical grid through fuel cells. Two scenarios have been implemented: a current-based grid and a proposed hydrogen grid system. A comparative assessment has been conducted in terms of energy consumption, levelized cost of energy (LCOE), and carbon emissions rate. Based on the results, the proposed Hydrogen-Grid system reduces the LCOE by $15 \%$, while the carbon emissions significantly drop by $72.47 \%$. The study outcomes reveal a significant insight into the manufacturing of green steel in Jordan, aligning with both local and global sustainability visions.

The fuel prices are increasing nowadays, causing a burden on the power system. From this, diesel generators that are still in use, must be hybridized with renewable energy (RE) to levelized the overall projects costs. This study aims to schedule an operation of a hybrid system photovoltaic (PV)/ diesel in a remote area which located in Wadi Rum district in Jordan to serve factory load in addition to obtain the best economical system combination that can serve the needs of a continuous electrical load without any interruption. Based on the results of the analysis using HOMER software, the configuration in the system will be a combination between PV modules, and diesel generator. The hybrid system has met the target for electricity production which is documented in upcoming sections.

Hydrogen Fuel Cell Electric Buses (FCEBs) are a promising solution for decarbonizing public transport. Their operational feasibility in developing countries depends on hydrogen-supply costs and infrastructure readiness. The Ministry of Energy has reported a 400% increase in imported natural-gas costs due to current geopolitical tensions between the United States and Iran, exposing the strategic vulnerability of relying on imported diesel for public transport. This study assesses the operational hydrogen demand, fuel-cost implications, and avoided diesel tailpipe carbon dioxide (CO₂) emissions associated with gradually integrating FCEBs into Jordan’s Bus Rapid Transit (BRT) project. The baseline system consists of 64 diesel buses covering about 11 million kilometers annually, consuming around 3 million liters of diesel and emitting roughly 8108.3 tons of CO₂. Fleet transition scenarios are assessed for 2030, 2035, and 2040, with FCEB-integration ratios of 10%, 15%, and 25%. Under the reference assumption of equivalent-duty replacement, avoided diesel tailpipe CO₂ emissions increase with the diesel service displaced by FCEBs, reaching 25.7% at the highest penetration level. At the $6/kg reference hydrogen-price input, FCEB integration results in higher operational fuel costs than diesel-only operation. Under the constant diesel-price reference, mixed-fleet operation becomes cost-competitive at hydrogen prices of $1/kg and $2/kg, with operational fuel-cost savings of up to 16.97%. Within the operational fuel-cost boundary of this study, mixed-fleet competitiveness is influenced by both the assumed hydrogen fuel price and diesel-price trajectory. The results support gradual deployment, subject to the greenhouse-gas intensity of the hydrogen-production and delivery pathway and the readiness of hydrogen supply and depot infrastructure.