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Introduction The global energy system is undergoing a structural transformation as governments and industries pursue credible decarbonisation pathways without compromising reliability, scale, or competitiveness. Green hydrogen and its derivatives have emerged at the forefront of this shift. While falling renewable energy costs and rapid technology improvements are enabling projects on the ground, the real pace, direction, and economics of deployment are increasingly being determined by regulatory frameworks—both those already in force and those being actively signalled. In practice, policy design is now deciding not only whether projects get built, but which pathways win, where capital flows, and how quickly markets mature. Within this regulatory-led landscape, green hydrogen—produced via renewable-powered electrolysis—and green ammonia are moving from pilot-scale demonstration into early industrial deployment. Yet this evolution is not being driven by market forces or cost curves alone. Across major economies, policy architectures spanning fiscal incentives, certification regimes, infrastructure rules, and demand-creation mechanisms are actively shaping where projects concentrate, how risk is shared between public and private capital, and which production pathways achieve durable commercial viability. Deployment patterns are therefore beginning to reflect policy intent as much as resource quality or technology readiness. As these frameworks mature, regulation is also drawing sharper lines between transitional solutions—such as blue hydrogen and blue ammonia—and structurally low-carbon, end-state pathways. These distinctions are no longer theoretical: they are becoming material to investment decisions, bankability, cross-border market access, and asset longevity. The result is a market in which policy is not merely accelerating deployment but actively encoding technology preferences and decarbonisation trajectories—cementing its role as a central architect of market structure rather than a secondary overlay. A review of regulatory frameworks in geographies leading the push for green hydrogen and its derivatives clearly illustrates this pattern. United States – When Policy Refines Project Economics In the United States, policy has shifted the conversation from whether green hydrogen will be developed to how projects must be structured to maximise value and remain compliant over their operating life. The Inflation Reduction Act fundamentally reshaped project economics through the Clean Hydrogen Production Tax Credit (45V), offering up to USD 3.00/kg for hydrogen achieving the lowest lifecycle emissions intensity[1]. As implementation has progressed, the mechanics of electricity sourcing and emissions attribution have become central to project design. For electrolytic hydrogen, developers must demonstrate the carbon intensity of consumed power through approved lifecycle modelling approaches, with growing reliance on energy attribute certificates (EACs) and auditable power-procurement structures. Projects targeting long-term bankability are increasingly being configured around conservative, time-aligned power sourcing and robust emissions accounting rather than minimal compliance. In parallel, prevailing wage and apprenticeship provisions required to access the full value of 45V have effectively turned labour strategy into a financial variable, embedding workforce planning directly into capital and operating cost structures. This architecture was further recalibrated in 2025 with the enactment of the One Big Beautiful Bill Act, which accelerates the sunset of several clean-energy tax credits, tightens foreign-entity-of-concern and domestic-content restrictions, and advances the construction-start deadline for 45V-eligible projects to 2027. The practical result is a sharper policy premium on near-term execution and tax-credit optimisation, and greater uncertainty for long-duration hydrogen strategies. U.S. financing is therefore gravitating toward integrated renewable-to-hydrogen configurations, conservative compliance assumptions, and domestic supply-chain alignment—making policy timing and political risk central to bankability. European Union – The Global Regulatory Architect While the U.S. approach is anchored in subsidies, the European Union has positioned itself as the global rule-setter for renewable hydrogen and its derivatives. By 2026, EU regulatory frameworks are shaping not only domestic deployment, but also the conditions under which producers outside Europe can access European demand. The EU’s model combines capital support with binding market definitions. Funding mechanisms such as the Innovation Fund and the European Hydrogen Bank are paired with legally enforceable rules under the Renewable Energy Directive (RED III). Central to this architecture is the Renewable Fuels of Non-Biological Origin (RFNBO) framework, which establishes strict requirements around renewable electricity sourcing, lifecycle emissions thresholds, and traceability. The practical effect is that EU standards are becoming de facto global trade benchmarks. Producers targeting European offtakers must align with RFNBO definitions regardless of project location, effectively exporting EU regulatory logic across international supply chains. This externalisation of standards is reinforced by trade-linked instruments such as the Carbon Border Adjustment Mechanism (CBAM), which translates embedded carbon emissions into direct cost exposure for imports, including ammonia and downstream industrial products. As CBAM moves from reporting to financial liability, lifecycle emissions intensity and verifiable certification are becoming commercially decisive—structurally favouring near-zero-carbon pathways and cementing the EU’s role as an architect of market design rather than merely a participant. India – The Emergence of the “Green Hydrogen Hub” India is positioning itself not only as a major domestic consumer of green hydrogen, but as a potential global production and export hub. This ambition is anchored in some of the lowest renewable energy costs globally and a policy architecture explicitly designed to drive scale while compressing delivered hydrogen costs. The National Green Hydrogen Mission (NGHM), backed by an initial allocation of approximately INR 19,744 crore, has moved from high-level intent into implementation2. A central pillar is the Strategic Interventions for Green Hydrogen Transition (SIGHT) programme, which provides direct incentives for electrolyser manufacturing and green hydrogen production—linking deployment with domestic value-chain development rather than treating them as separate objectives. Market structure is being shaped through a hub-and-spoke development model. Designated green hydrogen hubs—such as Paradip, Tuticorin, and Kandla—are intended to co-locate production, storage, and anchor offtakers including refineries and fertiliser plants. This clustering approach lowers logistics and infrastructure duplication costs, accelerates demand aggregation, and improves utilisation of shared assets. India’s regulatory framework also directly targets the green premium. Long-term waivers on inter-state transmission charges, preferential renewable access, and the potential introduction of consumption obligations for hard-to-abate sectors are designed to narrow the cost gap with fossil-based hydrogen. At the same time, bidding-based allocation under key schemes is imposing early cost discipline, signalling a scale-first, margin-thin deployment model. The practical result is that

Introduction The global energy system is undergoing a structural transformation as industries seek to reduce greenhouse gas emissions while maintaining reliability and scale. While direct electrification remains the most efficient decarbonisation pathway where feasible, fertilisers, shipping, power generation, chemicals, and heavy industry—are inherently difficult to electrify. For these hard-to-abate applications, energy carriers derived from renewable power, particularly Green Hydrogen and Green Ammonia, are emerging as critical transition enablers. Understanding Green Ammonia Among the available pathways for decarbonisation, Green Ammonia stands out not as an incremental improvement over fossil fuels, but as a fundamental shift in how energy and industrial feedstocks are produced and traded. Conventional Ammonia relies on hydrogen produced from natural gas, embedding significant carbon emissions into a product that underpins global food and industrial systems. Green Ammonia replaces this fossil fuel dependency with Renewable electricity—using Green Hydrogen generated from RE driven electrolysis and combining it with nitrogen sourced directly from air. While the Haber-Bosch synthesis process itself remains unchanged, the upstream energy pathway is fundamentally different, enabling near-zero lifecycle emissions when powered by renewable energy.1 In contrast to Green Ammonia, Blue Ammonia—while benefiting from near-term cost advantages and the ability to leverage existing natural gas infrastructure—continues to rely on fossil fuels and carbon capture. Green Ammonia is thus particularly compelling since it removes carbon from the equation altogether. With no carbon in its molecular structure, Green Ammonia offers a structurally more durable decarbonisation solution. Unlike many other hydrogen derivative alternatives, Green Ammonia benefits from stable pricing of Renewable Energy and future proofing against tightening climate policies and carbon-linked trade mechanisms such as Carbon Border Adjustment Mechanism (“CBAM”). Beyond its emissions profile, Green Ammonia offers system-level advantages that strengthen its role in the energy transition. Ammonia is a globally traded commodity with established storage, transport, and handling infrastructure, making it a practical and scalable carrier for Green Hydrogen. Its higher volumetric energy density relative to hydrogen and its ability to be stored over long durations position it as a viable solution for long-distance energy transport and seasonal energy storage. Importantly, Green Ammonia also provides a means to monetise surplus renewable power, supporting grid stability and improving overall renewable energy system economics. As Renewable Energy costs continue to decline and regulatory pressure on embedded carbon intensifies, Green Ammonia is increasingly positioned not as a niche alternative, but as a cornerstone solution for decarbonisation. Its relevance is therefore not limited to environmental objectives alone, but extends to energy security, trade resilience, and long-term industrial competitiveness. Contribution to Emissions Reduction Goals The central role of Green Fuels is to drive net-zero strategies by enabling deep emissions reductions across sectors where conventional decarbonisation pathways are limited. In particular, multiple lifecycle assessments indicate that Green Ammonia can reduce lifecycle carbon dioxide (CO2) and greenhouse gas (GHG) emissions by 70–95% compared to conventional fuels, depending on the renewable power mix, electrolyser efficiency, and system boundaries applied. In hard-to-abate applications where low-carbon alternatives are scarce—Green Ammonia therefore represents one of the most effective substitution pathways available. Beyond its carbon abatement potential, Green Ammonia also delivers substantial local environmental benefits. When combusted or cracked for energy use, it produces negligible sulphur oxides (SOₓ) and very low particulate matter, besides completely avoiding carbon dioxide emissions at the point of use. These characteristics can significantly improve air quality around industrial facilities, ports, logistics hubs, and urban infrastructure, strengthening the case for Green Ammonia not only as a climate solution but also as a means of addressing public-health and regulatory challenges associated with air pollution.2 Economic Viability and Infrastructure Readiness While ammonia itself is a globally traded commodity with established downstream storage, transport, and handling practices, Green Ammonia does not yet enjoy the same level of infrastructure readiness as Blue Ammonia. Blue Ammonia can be deployed more rapidly in the near term by leveraging existing natural gas supply chains, hydrogen production assets, and, where available, carbon capture infrastructure. Green Ammonia, by contrast, requires the development of a new upstream asset stack— Renewable generation capacity, transmission infrastructure, electrolysers, and dedicated synthesis facilities—making the transition inherently capital intensive and unsuited to simple one-to-one replacement of existing fossil-based systems. These structural differences currently translate into higher production costs for Green Ammonia, leading to pricing in the range of USD 800–1,000 per tonne, driven by electrolyser capital costs, renewable intermittency, and relatively low utilisation factors. Regulatory uncertainty—particularly the absence of fully harmonised global definitions and certification schemes and limited large-scale operational experience, has also contributed to demand-side hesitation and elevated financing risk. However, these challenges are increasingly understood as transitional rather than structural. Rapid scale-up of electrolyser manufacturing, localisation of supply chains, and technology learning curves are expected to materially reduce capital costs and improve efficiency over time. Declining Renewable electricity prices, coupled with emerging carbon pricing mechanisms and targeted government incentives, are steadily narrowing the cost gap between Green Ammonia and fossil-based alternatives. At the system level, hybrid renewable configurations, grid-connected operation, and complementary battery and hydrogen storage solutions are improving utilisation rates and overall project economics. Importantly, while Green Ammonia requires significant upfront infrastructure investment, it offers long-term strategic value that Blue Ammonia cannot fully replicate. Thus, Blue Ammonia can play a pragmatic bridging role, but Green Ammonia is clearly the only scalable end-state solution for deep and lasting decarbonisation across hard-to-abate sectors. Applications Across Multiple Sectors As governments and industries pursue credible net-zero pathways, Green Ammonia is increasingly coming into focus as a solution that can potentially be deployed at scale across multiple sectors without compromising on energy security or operational continuity. Power Generation and Energy Systems Green Ammonia can be utilised directly in thermal power generation or cracked to produce hydrogen for use in gas turbines and fuel cells, offering a low-carbon pathway for dispatchable and firm power generation. While it is not yet a drop-in replacement for conventional fuels, it is increasingly being evaluated as a co-firing option to reduce emissions from existing thermal assets.3 Green Ammonia’s ability to function as a form of long-duration energy storage—converting variable