TECHNICAL PROGRAMME | Energy Leadership – Future Pathways
Financing the Future Energy Supply
Forum 27 | Hall 5 Digital Poster Plaza 5
28
April
12:30
14:30
UTC+3
Experts will discuss investment trends, risk management, and the role of public and private sectors in an evolving energy industry amidst a dynamic global transition. The panel will also address challenges in financing the energy transition, policy and market uncertainties, and adaptation to technological advancements. Join us to gain insights into innovative financing models, opportunities for growth, and how to ensure a stable and sustainable energy future.
Objectives
With an axisymmetric connected fracture model, this paper discovers that the resonance of acoustic waves within the connected fractures yields reflected Stoneley waves of many oscillation cycles. The inherent frequency of the resonant waves changes with the extension length of the fracture and with the depth of mud invasion for gas layer. Stemming from these discoveries, this paper proposes a method for identifying connected fractures and gas layers using the attenuation coefficient of Stoneley waves.
Methodology
Using the axisymmetric connected fracture model to study the Stoneley waves that enter the fracture, it is found that the waves propagate radially within the fracture invasion zone and are totally reflected at the liquid-gas boundary. The reflected waves propagate continuously towards the opposite opening of the same fracture system. Upon reaching the liquid-gas interface again, they are reflected once more. The consecutively reflected waves superimpose, resulting in a resonance with the inherent frequency of the fracture. This specific cross-borehole resonance exhibits as a barrier against the Stoneley waves of the same inherent frequency.
Conclusion
This barrier produces total reflection for the Stoneley wave of the inherent frequency. The reflection spectrum peaks at the inherent frequency, while the transmission Stoneley waves lack the inherent frequency components. The inherent frequency components are severely attenuated when passing through the connected fractures, and the attenuation coefficient of the transmitted Stoneley waves peaks at the inherent frequency, and it is referred to as an anomaly. When the extension length of the fracture or invasion length of gas zone is limited, the abnormal values of the attenuation coefficient are evenly distributed with frequency. Therefore, the distribution of abnormal values can be used to determine the presence of fractures and the invasion depth of the fracture zone.Using the improved matrix method to process the waveform of array acoustic logging to obtain the image of the Stoneley wave attenuation coefficient varying with frequency. From the image, it can be seen that at some depth intervals, the value of the Stoneley wave attenuation coefficient is significantly larger, showing an anomaly with red areas. The anomalous values indicate the presence of connected fractures and gas layer.
Additive Information
The figure shows an example of fracture in dolomite, with the far right being the image of the Stoneley wave attenuation coefficient. There are many densely distributed red areas on the image, indicating that there are connected fractures here.
With an axisymmetric connected fracture model, this paper discovers that the resonance of acoustic waves within the connected fractures yields reflected Stoneley waves of many oscillation cycles. The inherent frequency of the resonant waves changes with the extension length of the fracture and with the depth of mud invasion for gas layer. Stemming from these discoveries, this paper proposes a method for identifying connected fractures and gas layers using the attenuation coefficient of Stoneley waves.
Methodology
Using the axisymmetric connected fracture model to study the Stoneley waves that enter the fracture, it is found that the waves propagate radially within the fracture invasion zone and are totally reflected at the liquid-gas boundary. The reflected waves propagate continuously towards the opposite opening of the same fracture system. Upon reaching the liquid-gas interface again, they are reflected once more. The consecutively reflected waves superimpose, resulting in a resonance with the inherent frequency of the fracture. This specific cross-borehole resonance exhibits as a barrier against the Stoneley waves of the same inherent frequency.
Conclusion
This barrier produces total reflection for the Stoneley wave of the inherent frequency. The reflection spectrum peaks at the inherent frequency, while the transmission Stoneley waves lack the inherent frequency components. The inherent frequency components are severely attenuated when passing through the connected fractures, and the attenuation coefficient of the transmitted Stoneley waves peaks at the inherent frequency, and it is referred to as an anomaly. When the extension length of the fracture or invasion length of gas zone is limited, the abnormal values of the attenuation coefficient are evenly distributed with frequency. Therefore, the distribution of abnormal values can be used to determine the presence of fractures and the invasion depth of the fracture zone.Using the improved matrix method to process the waveform of array acoustic logging to obtain the image of the Stoneley wave attenuation coefficient varying with frequency. From the image, it can be seen that at some depth intervals, the value of the Stoneley wave attenuation coefficient is significantly larger, showing an anomaly with red areas. The anomalous values indicate the presence of connected fractures and gas layer.
Additive Information
The figure shows an example of fracture in dolomite, with the far right being the image of the Stoneley wave attenuation coefficient. There are many densely distributed red areas on the image, indicating that there are connected fractures here.
This article explores a strategic intersection between mining land rehabilitation and renewable energy development, offering a solution to global energy and transmission challenges. It argues that by leveraging innovative updates of existing regulations, countries like Brazil can transform their mining liabilities—specifically inactive tailings dams—into significant assets for a decentralized, self-generating energy supply. This approach offers a powerful new framework for degraded land rehabilitation, turning a mandatory closure procedure into a catalyst for national energy security.
Drawing on international precedents and legislation, this analysis highlights a global shift in perspective. In Australia, the Mining Rehabilitation Fund Act and the Environmental Protection and Biodiversity Conservation Act emphasize sustainable post-mining land use, creating a regulatory environment where solar projects could be integrated into closure plans. Similarly, Chile's Ley No. 20.551 (Mine Closure), which requires financial guarantees and detailed rehabilitation strategies, provides a clear legal pathway. In South Africa, the Mineral and Petroleum Resources Development Act (MPRDA) also mandates rehabilitation and post-mining land use planning, offering a comparable legal basis for similar initiatives. This technological neutrality of the law is critical, as demonstrated by Anglo American's pilot floating PV plant on a tailings pond at its Los Bronces mine, which showcases the technical feasibility and environmental benefits of such projects.
The implementation of such projects is no longer theoretical. Real-world examples confirm the technical and economic viability of this model. In Zambia, Zuwa Solar is developing a large-scale solar farm on the Bwana Mkubwa tailings dams. In the United States, the Questa Mine in New Mexico successfully installed a 1-megawatt solar facility on a reclaimed tailings site, while the Elizabeth Mine in Vermont repurposed a 45-acre capped tailings pile to generate 5 megawatts of power, enough to supply 1,500 homes in the region. These projects underscore the potential for converting contaminated or degraded sites into productive land for clean energy generation.
The article articulates that a similar regulatory adaptation in Brazil, offering incentives to consider solar energy as a valid and beneficial component of the legally required plan to recover degraded lands - PRAD, could bring significant benefits for all stakeholders. It would offer mining companies with nearby active operations a pathway to energy independence and self-generation, reducing reliance on the grid and lowering operational costs. The state would benefit from expanded clean energy capacity without the land-use conflicts associated with new developments, and society would gain a stable, sustainable energy source while simultaneously addressing environmental remediation, as well as effectively reducing regional socioeconomic dependence on mining activities. This innovative model provides a compelling blueprint for how Brazil can strategically finance its energy transition by turning its industrial past into a renewable energy future.
Keywords: Energy Security. Solar. Mining.
Co-author/s:
Estevam Fregapani, Analyst, Vale S.A.
Vinícius Domingues, General Manager of Regulatory Policy Management, Vale S.A.
Amir Mesquita, Professor, CDTN/Cnen.
Daniel Palma, Regulatory Management, Cnen.
Walmir Souza, Regulatory Manager for Energy, Oil and Gas, Vale S.A.
Bruno Pereira, Regulatory Analyst, Vale S.A.
Drawing on international precedents and legislation, this analysis highlights a global shift in perspective. In Australia, the Mining Rehabilitation Fund Act and the Environmental Protection and Biodiversity Conservation Act emphasize sustainable post-mining land use, creating a regulatory environment where solar projects could be integrated into closure plans. Similarly, Chile's Ley No. 20.551 (Mine Closure), which requires financial guarantees and detailed rehabilitation strategies, provides a clear legal pathway. In South Africa, the Mineral and Petroleum Resources Development Act (MPRDA) also mandates rehabilitation and post-mining land use planning, offering a comparable legal basis for similar initiatives. This technological neutrality of the law is critical, as demonstrated by Anglo American's pilot floating PV plant on a tailings pond at its Los Bronces mine, which showcases the technical feasibility and environmental benefits of such projects.
The implementation of such projects is no longer theoretical. Real-world examples confirm the technical and economic viability of this model. In Zambia, Zuwa Solar is developing a large-scale solar farm on the Bwana Mkubwa tailings dams. In the United States, the Questa Mine in New Mexico successfully installed a 1-megawatt solar facility on a reclaimed tailings site, while the Elizabeth Mine in Vermont repurposed a 45-acre capped tailings pile to generate 5 megawatts of power, enough to supply 1,500 homes in the region. These projects underscore the potential for converting contaminated or degraded sites into productive land for clean energy generation.
The article articulates that a similar regulatory adaptation in Brazil, offering incentives to consider solar energy as a valid and beneficial component of the legally required plan to recover degraded lands - PRAD, could bring significant benefits for all stakeholders. It would offer mining companies with nearby active operations a pathway to energy independence and self-generation, reducing reliance on the grid and lowering operational costs. The state would benefit from expanded clean energy capacity without the land-use conflicts associated with new developments, and society would gain a stable, sustainable energy source while simultaneously addressing environmental remediation, as well as effectively reducing regional socioeconomic dependence on mining activities. This innovative model provides a compelling blueprint for how Brazil can strategically finance its energy transition by turning its industrial past into a renewable energy future.
Keywords: Energy Security. Solar. Mining.
Co-author/s:
Estevam Fregapani, Analyst, Vale S.A.
Vinícius Domingues, General Manager of Regulatory Policy Management, Vale S.A.
Amir Mesquita, Professor, CDTN/Cnen.
Daniel Palma, Regulatory Management, Cnen.
Walmir Souza, Regulatory Manager for Energy, Oil and Gas, Vale S.A.
Bruno Pereira, Regulatory Analyst, Vale S.A.
Green finance also has a significant role to play in speeding the global energy transition by facilitating mobilization of funds to low-carbon and clean energy projects. This study assesses the key role that has been played by green financing towards encouraging energy transition activities and addresses existing investment patterns, with special emphasis on changing dynamics between public and private sectors' roles. It also addresses key challenges, such as policy and market uncertainties, technological risks, and the barriers to capital availability that emerging markets face. It presents in-depth analysis on these issues, drawing from conclusions of case studies in Europe, the MENA region, and Southeast Asia, which demonstrate best practices in green finance and their applications in reality. Additionally, several creative financing structures, such as green bonds, blended finance approaches, and products tied to environmental, social, and governance (ESG) metrics, are evaluated for their effectiveness in promoting investment in clean energy. The research refers to global frameworks, like the EU Sustainable Finance Taxonomy and the United Nations Sustainable Development Goals (SDGs), to position green finance against the broader sustainability objectives. Studies show that while green finance has come a long way, with substantial deployment of clean energy solutions, there needs to be a more integrated strategy to overcome the barriers to investment, improve public-private sector partnerships, and increase financing scale in order to meet climate objectives. The conclusion determines best practices and policy implications and emphasizes the requirement for strong financial frameworks and collaborative partnerships to set up the sustainable energy supplies to provide a robust and stable energy future.
This study proposes a novel national framework for just transition financing, grounded in a financial leadership pathway within cross-sectoral coordination. Embedding the principles of just transition into banking activities emerges as an effective strategy to develop clean energy supply-demand chains while ensuring equitable economic and social outcomes. Key roles and responsibilities for public and private stakeholders are outlined in a structured business plan (BP), supported by Delegation of Authority (DOA) provisions: 1) Ministry of Petroleum: Identifies and prioritizes projects with high GHG reduction potential (Scope 1 & 2 emissions) based on techno-economic analyses and Greenium effects; 2) Ministry of Economy: Assesses project alignment with just transition criteria, including regional economic diversification, governance strengthening, human capital development, and workforce justice; 3) Designated Green Bank: Implements industry-leading environmental and social safeguards. It issues tradable green certificates for Sustainable Development Goals (SDG) compliant processes and products. Financing mechanisms linked to certificate trading between different stakeholders are proposed; 4) Private Sector Engagement: Energy-demanding entities co-finance clean energy operations through incentives like green-labeled products. Financial support includes direct investments, credit facilitation, and corporate social responsibility (CSR) budgets, with green certificate credits weighted by participation level. Green loans (lower interest rates) and debt instruments further incentivize adoption to support projects utilizing green products. The mentioned framework is applied to CO₂-based Enhanced Oil Recovery (EOR) projects. Different scenarios configured various reservoirs and CO₂ source -including carbon capture from refineries, steel, and power plants- are evaluated. Downstream industries (e.g., steelworks) benefit from cleaner energy streams and green-certified products. Industries such as steel manufacturers and subsidiaries may engage financially due to market incentives for green-labeled products. Additionally, green loans for infrastructure (e.g., green pipelines/vessels) of EOR-CO₂ projects, with a traded green project portfolio facilitated by circulating green certificates. The cash flow of these interconnected projects is analyzed, and a green credit flow model is proposed accordingly. Results show that depend on characteristic of each scenario, specific projects can be successfully financed within this integrated circular system. Ultimately, this innovative approach illustrates how financial leadership can foster large-scale sustainable energy projects, advancing both decarbonization and just transition objectives.
The global energy transition demands inclusive financing to achieve sustainability, affordability, and security, engaging individuals, communities, and institutions in transformative climate action. This study proposes a Company-Managed Sustainability Investment Platform (CMSIP), enabling employees to invest salaries or bonuses in corporate-led green projects, such as solar microgrids, waste-to-energy systems, or carbon capture pilots, while leveraging India’s ₹1 lakh crore annual CSR pool. Unlike provident funds or REITs, CMSIP harnesses corporate expertise—technical, regulatory, and R&D—to deploy innovative technologies, including those requiring Patent and Technology Rights (PTR), fostering grassroots innovation and societal impact.
CMSIP aligns with schemes like PM Suryaghar Muft Bijli Yojana of India, targeting solar panels for 100 million households with ₹30,000–₹78,000/kW subsidies, and the National Solar Mission, aiming for 100 GW solar capacity by 2030. Employees and their families, including unemployed children, participate in project implementation, gaining hands-on experience in technologies like advanced solar inverters or biomass gasifiers. This exposure equips them with real-time knowledge for higher studies or careers in new companies, fostering employability. Mutual MoUs between employee unions of different firms pool engineering and construction skills, enabling billion-dollar projects driven by employee contributions and voluntary time, strengthening workplace and community bonds.
By facilitating PTR acquisition, CMSIP revives globally transferred but underutilized technologies, such as energy storage or carbon-sequestering materials, scaling them for public good. Small-scale pilots, funded by CMSIP and CSR, test innovations like a 100 kW solar-battery system, offsetting 120 tons of CO₂ annually and saving 60% on energy costs. Weekend brainstorming and sub-committees drive community-specific solutions, like rural off-grid systems. Redirecting 50% of CSR funds could support 500 MW of renewable projects yearly, creating 10,000 jobs, including opportunities for employee families, and cutting emissions by 600,000 tons. Collaborations with institutes like IITs or MIT refine technologies, enhancing reliability.
Public-private synergies, supported by green bonds and blended finance, mitigate policy volatility and costs, while corporate governance ensures transparent fund management. CMSIP transforms workplaces into green innovation hubs, aligning with India’s 2070 net-zero goal, empowering communities, enhancing employability, and redefining investment as a catalyst for equitable, sustainable energy access and resilience.
CMSIP aligns with schemes like PM Suryaghar Muft Bijli Yojana of India, targeting solar panels for 100 million households with ₹30,000–₹78,000/kW subsidies, and the National Solar Mission, aiming for 100 GW solar capacity by 2030. Employees and their families, including unemployed children, participate in project implementation, gaining hands-on experience in technologies like advanced solar inverters or biomass gasifiers. This exposure equips them with real-time knowledge for higher studies or careers in new companies, fostering employability. Mutual MoUs between employee unions of different firms pool engineering and construction skills, enabling billion-dollar projects driven by employee contributions and voluntary time, strengthening workplace and community bonds.
By facilitating PTR acquisition, CMSIP revives globally transferred but underutilized technologies, such as energy storage or carbon-sequestering materials, scaling them for public good. Small-scale pilots, funded by CMSIP and CSR, test innovations like a 100 kW solar-battery system, offsetting 120 tons of CO₂ annually and saving 60% on energy costs. Weekend brainstorming and sub-committees drive community-specific solutions, like rural off-grid systems. Redirecting 50% of CSR funds could support 500 MW of renewable projects yearly, creating 10,000 jobs, including opportunities for employee families, and cutting emissions by 600,000 tons. Collaborations with institutes like IITs or MIT refine technologies, enhancing reliability.
Public-private synergies, supported by green bonds and blended finance, mitigate policy volatility and costs, while corporate governance ensures transparent fund management. CMSIP transforms workplaces into green innovation hubs, aligning with India’s 2070 net-zero goal, empowering communities, enhancing employability, and redefining investment as a catalyst for equitable, sustainable energy access and resilience.
Objectives/Scope:
India’s pledge to achieve net-zero carbon emissions by 2070 has elevated green hydrogen to a strategic priority in its energy transformation. As a clean fuel produced via electrolysis powered by renewable energy, green hydrogen holds the key to deep decarbonization in hard-to-abate sectors such as steel, cement, fertilizers, and oil refining. Unlike grey hydrogen derived from fossil fuels, green hydrogen offers a zero-emissions alternative, aligning with India’s sustainable development goals. However, its current production cost—$5 to $6 per kg—remains a major barrier, significantly higher than grey hydrogen's $1 to $2 per kg. The primary objective of this study is to assess India's roadmap for reducing the Levelized Cost of Hydrogen (LCOH) and catalyzing market growth by leveraging renewable energy, technological advancements, policy incentives, and industrial initiatives, with Bharat Petroleum Corporation Limited (BPCL) as a case in focus.
Methods, Procedures, Process:
The study analyzes the cost structure of green hydrogen production, primarily focusing on Capital Expenditure (CAPEX) and Operational Expenditure (OPEX). CAPEX comprises electrolyzer systems and associated infrastructure, estimated between $700 and $1,200 per kW in the Indian context. OPEX is predominantly influenced by electricity costs, accounting for 60–70% of the LCOH. India’s globally competitive renewable tariffs—ranging from $0.02 to $0.03 per kWh—are a pivotal advantage for cost minimization. The analysis also reviews national policies under the ₹19,744 crore ($2.4 billion) National Green Hydrogen Mission, including Production-Linked Incentives (PLI) for electrolyzers, Viability Gap Funding (VGF), and tax exemptions on green energy. Additionally, state-level policies in Rajasthan, Gujarat, and Maharashtra offering concessional power and water support have been evaluated for their role in facilitating large-scale hydrogen projects.
BPCL’s leadership has been studied through its flagship 5 MW green hydrogen plant at Bina Refinery and its strategic R&D investments. The company is also focusing on infrastructure development such as hydrogen pipelines and mobility applications to create a complete hydrogen ecosystem.
Results, Observations, Conclusions:
India’s green hydrogen ecosystem is rapidly evolving through a synergy of industrial leadership, policy reform, and technological innovation. BPCL’s commitment to producing 30 KTPA of green hydrogen by 2030 signals robust industry momentum. Technological advancements, particularly in electrolyzer efficiency, localization of manufacturing, and renewable integration, are poised to reduce LCOH to $1–$2 per kg by 2030. BPCL’s hydrogen mobility initiatives, such as commissioning India’s first hydrogen fueling station in Kerala, and plans for similar projects in Lucknow and Varanasi, demonstrate scalable models for urban transport decarbonization.
India’s ambition to become a green hydrogen exporter to the Middle East, Japan, and Europe—with estimated delivered prices of $1.5–$2 per kg—is both realistic and strategic, positioning it as a global hub. However, challenges remain, including water usage for electrolysis, storage, transport logistics, and high initial investments. With proactive policy implementation, industry collaboration, and continued investment in R&D, India is on a promising trajectory to unlock the full potential of green hydrogen—enabling clean industrial growth, energy security, and global climate leadership.
Keywords: Green hydrogen, cost reduction, renewable energy, electrolyzer technology, sustainable decarbonization
India’s pledge to achieve net-zero carbon emissions by 2070 has elevated green hydrogen to a strategic priority in its energy transformation. As a clean fuel produced via electrolysis powered by renewable energy, green hydrogen holds the key to deep decarbonization in hard-to-abate sectors such as steel, cement, fertilizers, and oil refining. Unlike grey hydrogen derived from fossil fuels, green hydrogen offers a zero-emissions alternative, aligning with India’s sustainable development goals. However, its current production cost—$5 to $6 per kg—remains a major barrier, significantly higher than grey hydrogen's $1 to $2 per kg. The primary objective of this study is to assess India's roadmap for reducing the Levelized Cost of Hydrogen (LCOH) and catalyzing market growth by leveraging renewable energy, technological advancements, policy incentives, and industrial initiatives, with Bharat Petroleum Corporation Limited (BPCL) as a case in focus.
Methods, Procedures, Process:
The study analyzes the cost structure of green hydrogen production, primarily focusing on Capital Expenditure (CAPEX) and Operational Expenditure (OPEX). CAPEX comprises electrolyzer systems and associated infrastructure, estimated between $700 and $1,200 per kW in the Indian context. OPEX is predominantly influenced by electricity costs, accounting for 60–70% of the LCOH. India’s globally competitive renewable tariffs—ranging from $0.02 to $0.03 per kWh—are a pivotal advantage for cost minimization. The analysis also reviews national policies under the ₹19,744 crore ($2.4 billion) National Green Hydrogen Mission, including Production-Linked Incentives (PLI) for electrolyzers, Viability Gap Funding (VGF), and tax exemptions on green energy. Additionally, state-level policies in Rajasthan, Gujarat, and Maharashtra offering concessional power and water support have been evaluated for their role in facilitating large-scale hydrogen projects.
BPCL’s leadership has been studied through its flagship 5 MW green hydrogen plant at Bina Refinery and its strategic R&D investments. The company is also focusing on infrastructure development such as hydrogen pipelines and mobility applications to create a complete hydrogen ecosystem.
Results, Observations, Conclusions:
India’s green hydrogen ecosystem is rapidly evolving through a synergy of industrial leadership, policy reform, and technological innovation. BPCL’s commitment to producing 30 KTPA of green hydrogen by 2030 signals robust industry momentum. Technological advancements, particularly in electrolyzer efficiency, localization of manufacturing, and renewable integration, are poised to reduce LCOH to $1–$2 per kg by 2030. BPCL’s hydrogen mobility initiatives, such as commissioning India’s first hydrogen fueling station in Kerala, and plans for similar projects in Lucknow and Varanasi, demonstrate scalable models for urban transport decarbonization.
India’s ambition to become a green hydrogen exporter to the Middle East, Japan, and Europe—with estimated delivered prices of $1.5–$2 per kg—is both realistic and strategic, positioning it as a global hub. However, challenges remain, including water usage for electrolysis, storage, transport logistics, and high initial investments. With proactive policy implementation, industry collaboration, and continued investment in R&D, India is on a promising trajectory to unlock the full potential of green hydrogen—enabling clean industrial growth, energy security, and global climate leadership.
Keywords: Green hydrogen, cost reduction, renewable energy, electrolyzer technology, sustainable decarbonization
The petroleum industry is going through a period of significant uncertainty, shaped by geopolitical instability, shifting regulations, market volatility, and the global push toward cleaner energy sources. In this evolving landscape, traditional decision-making methods often fall short in capturing the full complexity of market dynamics. AI, when combined with expert insights, offers a way to enhance decision-making by providing speed, accuracy, and flexibility, helping industry leaders and investors make better financial choices.
This project introduces an AI-driven approach to scenario modeling, designed to improve strategic decision-making in the petroleum sector. AI processes vast amounts of information, including market trends, regulatory signals, expert analyses, and real-time economic data, to build predictive scenarios that help companies navigate uncertainty. Unlike traditional models, AI can incorporate both numerical data and expert viewpoints, leading to more reliable forecasts and investment strategies. When combined with real options theory, AI helps determine the right moments to invest, disinvest, or adjust financial plans based on changing future conditions.
The work first examines how AI-powered tools are currently used across the industry, from daily operations to risk management and long-term strategic planning. It then explores AI’s expanding role in refining market forecasts, improving financial models, and supporting executive decision-making when paired with human expertise.
Building on previous studies, industry case studies, and insights from my doctoral thesis, this analysis highlights both theoretical foundations and practical applications of AI in investment strategy. By integrating AI with economic modeling and expert judgment, petroleum companies can refine business strategies, mitigate risks, and optimize investment decisions in an uncertain economic climate. This analysis presents a clear framework for industry leaders looking to modernize their approach to decision-making.
This project introduces an AI-driven approach to scenario modeling, designed to improve strategic decision-making in the petroleum sector. AI processes vast amounts of information, including market trends, regulatory signals, expert analyses, and real-time economic data, to build predictive scenarios that help companies navigate uncertainty. Unlike traditional models, AI can incorporate both numerical data and expert viewpoints, leading to more reliable forecasts and investment strategies. When combined with real options theory, AI helps determine the right moments to invest, disinvest, or adjust financial plans based on changing future conditions.
The work first examines how AI-powered tools are currently used across the industry, from daily operations to risk management and long-term strategic planning. It then explores AI’s expanding role in refining market forecasts, improving financial models, and supporting executive decision-making when paired with human expertise.
Building on previous studies, industry case studies, and insights from my doctoral thesis, this analysis highlights both theoretical foundations and practical applications of AI in investment strategy. By integrating AI with economic modeling and expert judgment, petroleum companies can refine business strategies, mitigate risks, and optimize investment decisions in an uncertain economic climate. This analysis presents a clear framework for industry leaders looking to modernize their approach to decision-making.
By 2050, global oil investment will be shaped by the transition to renewable energy, geopolitical shifts, and evolving demand dynamics. Despite the rise of clean energy, oil is expected to remain relevant in certain sectors, such as petrochemicals and aviation, though overall demand may decline. Investment strategies will prioritize cost efficiency, carbon capture technologies, and sustainable extraction methods to align with net-zero commitments. Emerging markets in Asia and Africa may drive demand growth, while developed economies accelerate decarbonization. Geopolitical risks, technological advancements, and climate policies will heavily influence investment decisions, leading to a more selective and strategic approach in the oil sector. The industry’s future will depend on balancing profitability with environmental responsibility, navigating a complex energy landscape.In this article, the global oil investment outlook is examined and statistically analyzed.
Nurgul Akhmetbekova
Vice Chair
Head of Division, Budgeting & Planning Department
KazMunayGas
Kazakhstan
Mohammad Alami Bayat
Speaker
Head of the Office of American Countries Affairs
Ministry of Petroleum
Iran
The petroleum industry is going through a period of significant uncertainty, shaped by geopolitical instability, shifting regulations, market volatility, and the global push toward cleaner energy sources. In this evolving landscape, traditional decision-making methods often fall short in capturing the full complexity of market dynamics. AI, when combined with expert insights, offers a way to enhance decision-making by providing speed, accuracy, and flexibility, helping industry leaders and investors make better financial choices.
This project introduces an AI-driven approach to scenario modeling, designed to improve strategic decision-making in the petroleum sector. AI processes vast amounts of information, including market trends, regulatory signals, expert analyses, and real-time economic data, to build predictive scenarios that help companies navigate uncertainty. Unlike traditional models, AI can incorporate both numerical data and expert viewpoints, leading to more reliable forecasts and investment strategies. When combined with real options theory, AI helps determine the right moments to invest, disinvest, or adjust financial plans based on changing future conditions.
The work first examines how AI-powered tools are currently used across the industry, from daily operations to risk management and long-term strategic planning. It then explores AI’s expanding role in refining market forecasts, improving financial models, and supporting executive decision-making when paired with human expertise.
Building on previous studies, industry case studies, and insights from my doctoral thesis, this analysis highlights both theoretical foundations and practical applications of AI in investment strategy. By integrating AI with economic modeling and expert judgment, petroleum companies can refine business strategies, mitigate risks, and optimize investment decisions in an uncertain economic climate. This analysis presents a clear framework for industry leaders looking to modernize their approach to decision-making.
This project introduces an AI-driven approach to scenario modeling, designed to improve strategic decision-making in the petroleum sector. AI processes vast amounts of information, including market trends, regulatory signals, expert analyses, and real-time economic data, to build predictive scenarios that help companies navigate uncertainty. Unlike traditional models, AI can incorporate both numerical data and expert viewpoints, leading to more reliable forecasts and investment strategies. When combined with real options theory, AI helps determine the right moments to invest, disinvest, or adjust financial plans based on changing future conditions.
The work first examines how AI-powered tools are currently used across the industry, from daily operations to risk management and long-term strategic planning. It then explores AI’s expanding role in refining market forecasts, improving financial models, and supporting executive decision-making when paired with human expertise.
Building on previous studies, industry case studies, and insights from my doctoral thesis, this analysis highlights both theoretical foundations and practical applications of AI in investment strategy. By integrating AI with economic modeling and expert judgment, petroleum companies can refine business strategies, mitigate risks, and optimize investment decisions in an uncertain economic climate. This analysis presents a clear framework for industry leaders looking to modernize their approach to decision-making.
This article explores a strategic intersection between mining land rehabilitation and renewable energy development, offering a solution to global energy and transmission challenges. It argues that by leveraging innovative updates of existing regulations, countries like Brazil can transform their mining liabilities—specifically inactive tailings dams—into significant assets for a decentralized, self-generating energy supply. This approach offers a powerful new framework for degraded land rehabilitation, turning a mandatory closure procedure into a catalyst for national energy security.
Drawing on international precedents and legislation, this analysis highlights a global shift in perspective. In Australia, the Mining Rehabilitation Fund Act and the Environmental Protection and Biodiversity Conservation Act emphasize sustainable post-mining land use, creating a regulatory environment where solar projects could be integrated into closure plans. Similarly, Chile's Ley No. 20.551 (Mine Closure), which requires financial guarantees and detailed rehabilitation strategies, provides a clear legal pathway. In South Africa, the Mineral and Petroleum Resources Development Act (MPRDA) also mandates rehabilitation and post-mining land use planning, offering a comparable legal basis for similar initiatives. This technological neutrality of the law is critical, as demonstrated by Anglo American's pilot floating PV plant on a tailings pond at its Los Bronces mine, which showcases the technical feasibility and environmental benefits of such projects.
The implementation of such projects is no longer theoretical. Real-world examples confirm the technical and economic viability of this model. In Zambia, Zuwa Solar is developing a large-scale solar farm on the Bwana Mkubwa tailings dams. In the United States, the Questa Mine in New Mexico successfully installed a 1-megawatt solar facility on a reclaimed tailings site, while the Elizabeth Mine in Vermont repurposed a 45-acre capped tailings pile to generate 5 megawatts of power, enough to supply 1,500 homes in the region. These projects underscore the potential for converting contaminated or degraded sites into productive land for clean energy generation.
The article articulates that a similar regulatory adaptation in Brazil, offering incentives to consider solar energy as a valid and beneficial component of the legally required plan to recover degraded lands - PRAD, could bring significant benefits for all stakeholders. It would offer mining companies with nearby active operations a pathway to energy independence and self-generation, reducing reliance on the grid and lowering operational costs. The state would benefit from expanded clean energy capacity without the land-use conflicts associated with new developments, and society would gain a stable, sustainable energy source while simultaneously addressing environmental remediation, as well as effectively reducing regional socioeconomic dependence on mining activities. This innovative model provides a compelling blueprint for how Brazil can strategically finance its energy transition by turning its industrial past into a renewable energy future.
Keywords: Energy Security. Solar. Mining.
Co-author/s:
Estevam Fregapani, Analyst, Vale S.A.
Vinícius Domingues, General Manager of Regulatory Policy Management, Vale S.A.
Amir Mesquita, Professor, CDTN/Cnen.
Daniel Palma, Regulatory Management, Cnen.
Walmir Souza, Regulatory Manager for Energy, Oil and Gas, Vale S.A.
Bruno Pereira, Regulatory Analyst, Vale S.A.
Drawing on international precedents and legislation, this analysis highlights a global shift in perspective. In Australia, the Mining Rehabilitation Fund Act and the Environmental Protection and Biodiversity Conservation Act emphasize sustainable post-mining land use, creating a regulatory environment where solar projects could be integrated into closure plans. Similarly, Chile's Ley No. 20.551 (Mine Closure), which requires financial guarantees and detailed rehabilitation strategies, provides a clear legal pathway. In South Africa, the Mineral and Petroleum Resources Development Act (MPRDA) also mandates rehabilitation and post-mining land use planning, offering a comparable legal basis for similar initiatives. This technological neutrality of the law is critical, as demonstrated by Anglo American's pilot floating PV plant on a tailings pond at its Los Bronces mine, which showcases the technical feasibility and environmental benefits of such projects.
The implementation of such projects is no longer theoretical. Real-world examples confirm the technical and economic viability of this model. In Zambia, Zuwa Solar is developing a large-scale solar farm on the Bwana Mkubwa tailings dams. In the United States, the Questa Mine in New Mexico successfully installed a 1-megawatt solar facility on a reclaimed tailings site, while the Elizabeth Mine in Vermont repurposed a 45-acre capped tailings pile to generate 5 megawatts of power, enough to supply 1,500 homes in the region. These projects underscore the potential for converting contaminated or degraded sites into productive land for clean energy generation.
The article articulates that a similar regulatory adaptation in Brazil, offering incentives to consider solar energy as a valid and beneficial component of the legally required plan to recover degraded lands - PRAD, could bring significant benefits for all stakeholders. It would offer mining companies with nearby active operations a pathway to energy independence and self-generation, reducing reliance on the grid and lowering operational costs. The state would benefit from expanded clean energy capacity without the land-use conflicts associated with new developments, and society would gain a stable, sustainable energy source while simultaneously addressing environmental remediation, as well as effectively reducing regional socioeconomic dependence on mining activities. This innovative model provides a compelling blueprint for how Brazil can strategically finance its energy transition by turning its industrial past into a renewable energy future.
Keywords: Energy Security. Solar. Mining.
Co-author/s:
Estevam Fregapani, Analyst, Vale S.A.
Vinícius Domingues, General Manager of Regulatory Policy Management, Vale S.A.
Amir Mesquita, Professor, CDTN/Cnen.
Daniel Palma, Regulatory Management, Cnen.
Walmir Souza, Regulatory Manager for Energy, Oil and Gas, Vale S.A.
Bruno Pereira, Regulatory Analyst, Vale S.A.
Mahdieh Askarian
Speaker
Head of Technology Policy Making
Ministry of Petroleum, Ministry of Petroleum, National Iranian Oil Company
Iran
This study proposes a novel national framework for just transition financing, grounded in a financial leadership pathway within cross-sectoral coordination. Embedding the principles of just transition into banking activities emerges as an effective strategy to develop clean energy supply-demand chains while ensuring equitable economic and social outcomes. Key roles and responsibilities for public and private stakeholders are outlined in a structured business plan (BP), supported by Delegation of Authority (DOA) provisions: 1) Ministry of Petroleum: Identifies and prioritizes projects with high GHG reduction potential (Scope 1 & 2 emissions) based on techno-economic analyses and Greenium effects; 2) Ministry of Economy: Assesses project alignment with just transition criteria, including regional economic diversification, governance strengthening, human capital development, and workforce justice; 3) Designated Green Bank: Implements industry-leading environmental and social safeguards. It issues tradable green certificates for Sustainable Development Goals (SDG) compliant processes and products. Financing mechanisms linked to certificate trading between different stakeholders are proposed; 4) Private Sector Engagement: Energy-demanding entities co-finance clean energy operations through incentives like green-labeled products. Financial support includes direct investments, credit facilitation, and corporate social responsibility (CSR) budgets, with green certificate credits weighted by participation level. Green loans (lower interest rates) and debt instruments further incentivize adoption to support projects utilizing green products. The mentioned framework is applied to CO₂-based Enhanced Oil Recovery (EOR) projects. Different scenarios configured various reservoirs and CO₂ source -including carbon capture from refineries, steel, and power plants- are evaluated. Downstream industries (e.g., steelworks) benefit from cleaner energy streams and green-certified products. Industries such as steel manufacturers and subsidiaries may engage financially due to market incentives for green-labeled products. Additionally, green loans for infrastructure (e.g., green pipelines/vessels) of EOR-CO₂ projects, with a traded green project portfolio facilitated by circulating green certificates. The cash flow of these interconnected projects is analyzed, and a green credit flow model is proposed accordingly. Results show that depend on characteristic of each scenario, specific projects can be successfully financed within this integrated circular system. Ultimately, this innovative approach illustrates how financial leadership can foster large-scale sustainable energy projects, advancing both decarbonization and just transition objectives.
Mohammad Sajjad Erfani
Speaker
Senior Expert of the Research and Development
Iran Energy Exchange (IEE)
Iran
Green finance also has a significant role to play in speeding the global energy transition by facilitating mobilization of funds to low-carbon and clean energy projects. This study assesses the key role that has been played by green financing towards encouraging energy transition activities and addresses existing investment patterns, with special emphasis on changing dynamics between public and private sectors' roles. It also addresses key challenges, such as policy and market uncertainties, technological risks, and the barriers to capital availability that emerging markets face. It presents in-depth analysis on these issues, drawing from conclusions of case studies in Europe, the MENA region, and Southeast Asia, which demonstrate best practices in green finance and their applications in reality. Additionally, several creative financing structures, such as green bonds, blended finance approaches, and products tied to environmental, social, and governance (ESG) metrics, are evaluated for their effectiveness in promoting investment in clean energy. The research refers to global frameworks, like the EU Sustainable Finance Taxonomy and the United Nations Sustainable Development Goals (SDGs), to position green finance against the broader sustainability objectives. Studies show that while green finance has come a long way, with substantial deployment of clean energy solutions, there needs to be a more integrated strategy to overcome the barriers to investment, improve public-private sector partnerships, and increase financing scale in order to meet climate objectives. The conclusion determines best practices and policy implications and emphasizes the requirement for strong financial frameworks and collaborative partnerships to set up the sustainable energy supplies to provide a robust and stable energy future.
The global energy transition demands inclusive financing to achieve sustainability, affordability, and security, engaging individuals, communities, and institutions in transformative climate action. This study proposes a Company-Managed Sustainability Investment Platform (CMSIP), enabling employees to invest salaries or bonuses in corporate-led green projects, such as solar microgrids, waste-to-energy systems, or carbon capture pilots, while leveraging India’s ₹1 lakh crore annual CSR pool. Unlike provident funds or REITs, CMSIP harnesses corporate expertise—technical, regulatory, and R&D—to deploy innovative technologies, including those requiring Patent and Technology Rights (PTR), fostering grassroots innovation and societal impact.
CMSIP aligns with schemes like PM Suryaghar Muft Bijli Yojana of India, targeting solar panels for 100 million households with ₹30,000–₹78,000/kW subsidies, and the National Solar Mission, aiming for 100 GW solar capacity by 2030. Employees and their families, including unemployed children, participate in project implementation, gaining hands-on experience in technologies like advanced solar inverters or biomass gasifiers. This exposure equips them with real-time knowledge for higher studies or careers in new companies, fostering employability. Mutual MoUs between employee unions of different firms pool engineering and construction skills, enabling billion-dollar projects driven by employee contributions and voluntary time, strengthening workplace and community bonds.
By facilitating PTR acquisition, CMSIP revives globally transferred but underutilized technologies, such as energy storage or carbon-sequestering materials, scaling them for public good. Small-scale pilots, funded by CMSIP and CSR, test innovations like a 100 kW solar-battery system, offsetting 120 tons of CO₂ annually and saving 60% on energy costs. Weekend brainstorming and sub-committees drive community-specific solutions, like rural off-grid systems. Redirecting 50% of CSR funds could support 500 MW of renewable projects yearly, creating 10,000 jobs, including opportunities for employee families, and cutting emissions by 600,000 tons. Collaborations with institutes like IITs or MIT refine technologies, enhancing reliability.
Public-private synergies, supported by green bonds and blended finance, mitigate policy volatility and costs, while corporate governance ensures transparent fund management. CMSIP transforms workplaces into green innovation hubs, aligning with India’s 2070 net-zero goal, empowering communities, enhancing employability, and redefining investment as a catalyst for equitable, sustainable energy access and resilience.
CMSIP aligns with schemes like PM Suryaghar Muft Bijli Yojana of India, targeting solar panels for 100 million households with ₹30,000–₹78,000/kW subsidies, and the National Solar Mission, aiming for 100 GW solar capacity by 2030. Employees and their families, including unemployed children, participate in project implementation, gaining hands-on experience in technologies like advanced solar inverters or biomass gasifiers. This exposure equips them with real-time knowledge for higher studies or careers in new companies, fostering employability. Mutual MoUs between employee unions of different firms pool engineering and construction skills, enabling billion-dollar projects driven by employee contributions and voluntary time, strengthening workplace and community bonds.
By facilitating PTR acquisition, CMSIP revives globally transferred but underutilized technologies, such as energy storage or carbon-sequestering materials, scaling them for public good. Small-scale pilots, funded by CMSIP and CSR, test innovations like a 100 kW solar-battery system, offsetting 120 tons of CO₂ annually and saving 60% on energy costs. Weekend brainstorming and sub-committees drive community-specific solutions, like rural off-grid systems. Redirecting 50% of CSR funds could support 500 MW of renewable projects yearly, creating 10,000 jobs, including opportunities for employee families, and cutting emissions by 600,000 tons. Collaborations with institutes like IITs or MIT refine technologies, enhancing reliability.
Public-private synergies, supported by green bonds and blended finance, mitigate policy volatility and costs, while corporate governance ensures transparent fund management. CMSIP transforms workplaces into green innovation hubs, aligning with India’s 2070 net-zero goal, empowering communities, enhancing employability, and redefining investment as a catalyst for equitable, sustainable energy access and resilience.
By 2050, global oil investment will be shaped by the transition to renewable energy, geopolitical shifts, and evolving demand dynamics. Despite the rise of clean energy, oil is expected to remain relevant in certain sectors, such as petrochemicals and aviation, though overall demand may decline. Investment strategies will prioritize cost efficiency, carbon capture technologies, and sustainable extraction methods to align with net-zero commitments. Emerging markets in Asia and Africa may drive demand growth, while developed economies accelerate decarbonization. Geopolitical risks, technological advancements, and climate policies will heavily influence investment decisions, leading to a more selective and strategic approach in the oil sector. The industry’s future will depend on balancing profitability with environmental responsibility, navigating a complex energy landscape.In this article, the global oil investment outlook is examined and statistically analyzed.
Yongjin Shen
Speaker
Engineer
China University of Petroleum (East China)
United States of America
Objectives
With an axisymmetric connected fracture model, this paper discovers that the resonance of acoustic waves within the connected fractures yields reflected Stoneley waves of many oscillation cycles. The inherent frequency of the resonant waves changes with the extension length of the fracture and with the depth of mud invasion for gas layer. Stemming from these discoveries, this paper proposes a method for identifying connected fractures and gas layers using the attenuation coefficient of Stoneley waves.
Methodology
Using the axisymmetric connected fracture model to study the Stoneley waves that enter the fracture, it is found that the waves propagate radially within the fracture invasion zone and are totally reflected at the liquid-gas boundary. The reflected waves propagate continuously towards the opposite opening of the same fracture system. Upon reaching the liquid-gas interface again, they are reflected once more. The consecutively reflected waves superimpose, resulting in a resonance with the inherent frequency of the fracture. This specific cross-borehole resonance exhibits as a barrier against the Stoneley waves of the same inherent frequency.
Conclusion
This barrier produces total reflection for the Stoneley wave of the inherent frequency. The reflection spectrum peaks at the inherent frequency, while the transmission Stoneley waves lack the inherent frequency components. The inherent frequency components are severely attenuated when passing through the connected fractures, and the attenuation coefficient of the transmitted Stoneley waves peaks at the inherent frequency, and it is referred to as an anomaly. When the extension length of the fracture or invasion length of gas zone is limited, the abnormal values of the attenuation coefficient are evenly distributed with frequency. Therefore, the distribution of abnormal values can be used to determine the presence of fractures and the invasion depth of the fracture zone.Using the improved matrix method to process the waveform of array acoustic logging to obtain the image of the Stoneley wave attenuation coefficient varying with frequency. From the image, it can be seen that at some depth intervals, the value of the Stoneley wave attenuation coefficient is significantly larger, showing an anomaly with red areas. The anomalous values indicate the presence of connected fractures and gas layer.
Additive Information
The figure shows an example of fracture in dolomite, with the far right being the image of the Stoneley wave attenuation coefficient. There are many densely distributed red areas on the image, indicating that there are connected fractures here.
With an axisymmetric connected fracture model, this paper discovers that the resonance of acoustic waves within the connected fractures yields reflected Stoneley waves of many oscillation cycles. The inherent frequency of the resonant waves changes with the extension length of the fracture and with the depth of mud invasion for gas layer. Stemming from these discoveries, this paper proposes a method for identifying connected fractures and gas layers using the attenuation coefficient of Stoneley waves.
Methodology
Using the axisymmetric connected fracture model to study the Stoneley waves that enter the fracture, it is found that the waves propagate radially within the fracture invasion zone and are totally reflected at the liquid-gas boundary. The reflected waves propagate continuously towards the opposite opening of the same fracture system. Upon reaching the liquid-gas interface again, they are reflected once more. The consecutively reflected waves superimpose, resulting in a resonance with the inherent frequency of the fracture. This specific cross-borehole resonance exhibits as a barrier against the Stoneley waves of the same inherent frequency.
Conclusion
This barrier produces total reflection for the Stoneley wave of the inherent frequency. The reflection spectrum peaks at the inherent frequency, while the transmission Stoneley waves lack the inherent frequency components. The inherent frequency components are severely attenuated when passing through the connected fractures, and the attenuation coefficient of the transmitted Stoneley waves peaks at the inherent frequency, and it is referred to as an anomaly. When the extension length of the fracture or invasion length of gas zone is limited, the abnormal values of the attenuation coefficient are evenly distributed with frequency. Therefore, the distribution of abnormal values can be used to determine the presence of fractures and the invasion depth of the fracture zone.Using the improved matrix method to process the waveform of array acoustic logging to obtain the image of the Stoneley wave attenuation coefficient varying with frequency. From the image, it can be seen that at some depth intervals, the value of the Stoneley wave attenuation coefficient is significantly larger, showing an anomaly with red areas. The anomalous values indicate the presence of connected fractures and gas layer.
Additive Information
The figure shows an example of fracture in dolomite, with the far right being the image of the Stoneley wave attenuation coefficient. There are many densely distributed red areas on the image, indicating that there are connected fractures here.
Objectives/Scope:
India’s pledge to achieve net-zero carbon emissions by 2070 has elevated green hydrogen to a strategic priority in its energy transformation. As a clean fuel produced via electrolysis powered by renewable energy, green hydrogen holds the key to deep decarbonization in hard-to-abate sectors such as steel, cement, fertilizers, and oil refining. Unlike grey hydrogen derived from fossil fuels, green hydrogen offers a zero-emissions alternative, aligning with India’s sustainable development goals. However, its current production cost—$5 to $6 per kg—remains a major barrier, significantly higher than grey hydrogen's $1 to $2 per kg. The primary objective of this study is to assess India's roadmap for reducing the Levelized Cost of Hydrogen (LCOH) and catalyzing market growth by leveraging renewable energy, technological advancements, policy incentives, and industrial initiatives, with Bharat Petroleum Corporation Limited (BPCL) as a case in focus.
Methods, Procedures, Process:
The study analyzes the cost structure of green hydrogen production, primarily focusing on Capital Expenditure (CAPEX) and Operational Expenditure (OPEX). CAPEX comprises electrolyzer systems and associated infrastructure, estimated between $700 and $1,200 per kW in the Indian context. OPEX is predominantly influenced by electricity costs, accounting for 60–70% of the LCOH. India’s globally competitive renewable tariffs—ranging from $0.02 to $0.03 per kWh—are a pivotal advantage for cost minimization. The analysis also reviews national policies under the ₹19,744 crore ($2.4 billion) National Green Hydrogen Mission, including Production-Linked Incentives (PLI) for electrolyzers, Viability Gap Funding (VGF), and tax exemptions on green energy. Additionally, state-level policies in Rajasthan, Gujarat, and Maharashtra offering concessional power and water support have been evaluated for their role in facilitating large-scale hydrogen projects.
BPCL’s leadership has been studied through its flagship 5 MW green hydrogen plant at Bina Refinery and its strategic R&D investments. The company is also focusing on infrastructure development such as hydrogen pipelines and mobility applications to create a complete hydrogen ecosystem.
Results, Observations, Conclusions:
India’s green hydrogen ecosystem is rapidly evolving through a synergy of industrial leadership, policy reform, and technological innovation. BPCL’s commitment to producing 30 KTPA of green hydrogen by 2030 signals robust industry momentum. Technological advancements, particularly in electrolyzer efficiency, localization of manufacturing, and renewable integration, are poised to reduce LCOH to $1–$2 per kg by 2030. BPCL’s hydrogen mobility initiatives, such as commissioning India’s first hydrogen fueling station in Kerala, and plans for similar projects in Lucknow and Varanasi, demonstrate scalable models for urban transport decarbonization.
India’s ambition to become a green hydrogen exporter to the Middle East, Japan, and Europe—with estimated delivered prices of $1.5–$2 per kg—is both realistic and strategic, positioning it as a global hub. However, challenges remain, including water usage for electrolysis, storage, transport logistics, and high initial investments. With proactive policy implementation, industry collaboration, and continued investment in R&D, India is on a promising trajectory to unlock the full potential of green hydrogen—enabling clean industrial growth, energy security, and global climate leadership.
Keywords: Green hydrogen, cost reduction, renewable energy, electrolyzer technology, sustainable decarbonization
India’s pledge to achieve net-zero carbon emissions by 2070 has elevated green hydrogen to a strategic priority in its energy transformation. As a clean fuel produced via electrolysis powered by renewable energy, green hydrogen holds the key to deep decarbonization in hard-to-abate sectors such as steel, cement, fertilizers, and oil refining. Unlike grey hydrogen derived from fossil fuels, green hydrogen offers a zero-emissions alternative, aligning with India’s sustainable development goals. However, its current production cost—$5 to $6 per kg—remains a major barrier, significantly higher than grey hydrogen's $1 to $2 per kg. The primary objective of this study is to assess India's roadmap for reducing the Levelized Cost of Hydrogen (LCOH) and catalyzing market growth by leveraging renewable energy, technological advancements, policy incentives, and industrial initiatives, with Bharat Petroleum Corporation Limited (BPCL) as a case in focus.
Methods, Procedures, Process:
The study analyzes the cost structure of green hydrogen production, primarily focusing on Capital Expenditure (CAPEX) and Operational Expenditure (OPEX). CAPEX comprises electrolyzer systems and associated infrastructure, estimated between $700 and $1,200 per kW in the Indian context. OPEX is predominantly influenced by electricity costs, accounting for 60–70% of the LCOH. India’s globally competitive renewable tariffs—ranging from $0.02 to $0.03 per kWh—are a pivotal advantage for cost minimization. The analysis also reviews national policies under the ₹19,744 crore ($2.4 billion) National Green Hydrogen Mission, including Production-Linked Incentives (PLI) for electrolyzers, Viability Gap Funding (VGF), and tax exemptions on green energy. Additionally, state-level policies in Rajasthan, Gujarat, and Maharashtra offering concessional power and water support have been evaluated for their role in facilitating large-scale hydrogen projects.
BPCL’s leadership has been studied through its flagship 5 MW green hydrogen plant at Bina Refinery and its strategic R&D investments. The company is also focusing on infrastructure development such as hydrogen pipelines and mobility applications to create a complete hydrogen ecosystem.
Results, Observations, Conclusions:
India’s green hydrogen ecosystem is rapidly evolving through a synergy of industrial leadership, policy reform, and technological innovation. BPCL’s commitment to producing 30 KTPA of green hydrogen by 2030 signals robust industry momentum. Technological advancements, particularly in electrolyzer efficiency, localization of manufacturing, and renewable integration, are poised to reduce LCOH to $1–$2 per kg by 2030. BPCL’s hydrogen mobility initiatives, such as commissioning India’s first hydrogen fueling station in Kerala, and plans for similar projects in Lucknow and Varanasi, demonstrate scalable models for urban transport decarbonization.
India’s ambition to become a green hydrogen exporter to the Middle East, Japan, and Europe—with estimated delivered prices of $1.5–$2 per kg—is both realistic and strategic, positioning it as a global hub. However, challenges remain, including water usage for electrolysis, storage, transport logistics, and high initial investments. With proactive policy implementation, industry collaboration, and continued investment in R&D, India is on a promising trajectory to unlock the full potential of green hydrogen—enabling clean industrial growth, energy security, and global climate leadership.
Keywords: Green hydrogen, cost reduction, renewable energy, electrolyzer technology, sustainable decarbonization
