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<channel><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/100626-interview-brazil-self-generation-ppas-adapt-to-tighter-rules-growing-curtailment-risks</link><description>Brazilian self-production purchase power agreements (PPAs) have had to adapt to sweeping regulatory changes that have effectively limited new deals to large consumers, creating uncertainty after years of rapid growth. But even so, these arrangements -- which already account for over one-fifth of the country&amp;apos;s electricity generation -- are expected to continue expanding, according to Mario Menel,</description><title>INTERVIEW: Brazil self-generation PPAs adapt to tighter rules, growing curtailment risks</title><pubDate>06 October 2026 17:20:52 GMT</pubDate><author><name>Felipe Peroni</name></author><content><![CDATA[ Electric Power, Energy Transition, Metals &amp; Mining, Renewables, Ferrous, Non-Ferrous, Hydrogen October 06, 2026 INTERVIEW: Brazil self-generation PPAs adapt to tighter rules, growing curtailment risks By Felipe Peroni Editor: Alisdair Bowles Getting your Trinity Audio player ready... HIGHLIGHTS Data centers drive fresh self-production deals New law limits self-generation to big buyers Curtailments cost wind, solar $1.2B in 2025 Brazilian self-production purchase power agreements (PPAs) have had to adapt to sweeping regulatory changes that have effectively limited new deals to large consumers, creating uncertainty after years of rapid growth. But even so, these arrangements -- which already account for over one-fifth of the country's electricity generation -- are expected to continue expanding, according to Mario Menel, president of the Brazilian Association of Investors in Self-Production of Energy, or Abiape. "Self-generation has been the main driver of the expansion of the power system," Menel told Platts in an interview Oct. 5. Energy generation under self-production plants increased by 12.4% year-over-year in 2025, reaching 176 TWh -- equivalent to 22.7% of the total electricity generated in the country -- according to data from the Brazilian Energy Research Bureau, or EPE. "These arrangements are made in a horizon of 15-20 years, so they are long-term commitments involving a continued investment in generation," Menel said. A law approved in November 2025 requires that each partner in new self-generation projects hold at least 30% of the project's shares and that the project contract for a minimum of 30 MW in power demand. The law virtually limits this type of PPA to large consumers that can afford to invest and acquire a large stake in energy projects. However, the emergence of data centers in Brazil is supporting a new round of investments on these arrangements. "Every single new data center is hiring self-production, and already two large data center companies have joined our association," Menel said. Before the law, many small consumers were turning to self-generation projects because these are exempt from costs associated with the wholesale market, such as the CDE, a tax used to subsidize several energy programs. Curtailments Besides the new regulations, widespread curtailments of solar and wind power have made it more costly to comply with self-generation contracts. Curtailments in Brazil have reached 21.3% of the potential generation in the year through Sept. 16, according to figures from the National System Operator, or ONS. Solar curtailments amounted to 25.3%, with wind curtailments at 19.8% in the same period. Abiape estimates that curtailment-related costs will result in losses of 6 billion reais ($1.2 billion) for wind and solar generators in 2025. Considering only self-production companies, losses reached 1.5 billion reais ($300 million). The latest Abiape figures show that its associates have an installed capacity of 35 GW, of which 63% is hydro, 20% solar, 6% wind and 11% thermal. Throughout 2026, small hydro companies have also been affected by occasional generation cuts by the ONS and distribution companies, especially during periods of low energy demand. When a self-generation unit is subject to curtailments, the cost of acquiring energy in the spot market is split between the two parties under the most recent PPA contracts. "In new contractual arrangements, curtailment costs are split between the two parties," Menel said. However, a constant increase in costs associated with the spot market, including the CDE, is expected to continue stimulating large buyers to seek self-generation PPAs, according to Menel. "Without self-production, it would be impossible to produce steel, aluminum, green hydrogen or to operate datacenters," he added. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/natural-gas/092826-path-to-net-zero-us-oil-majors-cast-doubt-on-feasibility-of-net-zero-by-2050</link><description>This is the fifth in a multi-part series on net-zero efforts across industries. The previous article can be found here. Some of the largest US oil and gas companies appear to be growing increasingly doubtful that a net-zero future is attainable by the middle of the century. Among the top 30 US companies in the sector, some reported declining corporate emissions intensities for 2025. Although a</description><title>PATH TO NET ZERO: US oil majors cast doubt on feasibility of net zero by 2050</title><pubDate>28 September 2026 13:45:14 GMT</pubDate><author><name>Jeremy Beaman</name><name>Corey Paul</name></author><content><![CDATA[ Energy Transition, Refined Products, Agriculture, LNG, Crude Oil, Natural Gas, Carbon, Renewables, Hydrogen, Biofuels, Emissions September 28, 2026 PATH TO NET ZERO: US oil majors cast doubt on feasibility of net zero by 2050 By Jeremy Beaman and Corey Paul Editor: Karina Roman Getting your Trinity Audio player ready... HIGHLIGHTS Companies cite tech gaps, policy uncertainty Profits surge on higher oil, products prices This is the fifth in a multi-part series on net-zero efforts across industries. The previous article can be found here. Some of the largest US oil and gas companies appear to be growing increasingly doubtful that a net-zero future is attainable by the middle of the century. Among the top 30 US companies in the sector, some reported declining corporate emissions intensities for 2025. Although a handful said they have already achieved net-zero emissions for at least a segment of their businesses, most have no firm goal, and integrated oil majors are casting doubt on the feasibility of their long-term targets. Amy Myers Jaffe, director of New York University's Energy, Climate Justice and Sustainability Lab, said that growing geopolitical uncertainty may make companies less willing to commit to emissions trajectories decades into the future, citing the sustained loss of energy supplies from the Persian Gulf amid the Middle East war. "The war has created a tremendous amount of uncertainty about what the trend line is," Jaffe said. Jaffe pointed to research conducted with Kalme Moncavo, an NYU graduate student, comparing sustainability reports published in 2021 and 2025 across 100 companies in multiple sectors, including oil and gas. The analysis found that references to 2030 targets increased by about 15%, while references to 2050 targets declined by about 45%, suggesting companies may be more comfortable discussing nearer-term goals than long-range commitments. Jaffe said companies have also become more cautious about discussing Scope 3 emissions because of inconsistent reporting standards and growing litigation related to climate impacts. Dropping 2050 As recently as 2025, Chevron Corp. upheld a target set years earlier to achieve net-zero Scope 1 and 2 emissions for its upstream production by 2050. In the company's latest disclosures, Chevron backed off the fixed 2050 date, saying neither technology nor public policy has advanced sufficiently to make the 2050 target achievable. Although Chevron said it no longer uses 2050 as a timeline, spokesperson Bill Turenne said the company continues to aspire to achieve net-zero Scope 1 and 2 upstream emissions on an equity basis. "We aim to grow our oil and gas business, lower the carbon intensity of our operations and grow new businesses in renewable fuels, carbon capture and offsets, hydrogen, power generation for data centers, and emerging technologies," Turenne said. ConocoPhillips, which introduced a net-zero target in 2020, is on track to reduce its emissions intensity by 50%-60% by 2030, the company said in its latest annual corporate sustainability report. However, slow development of low-carbon technologies and climate policy are among factors that "have led us to remove the 2050 date from our ambition," the company said in the report. "This adjustment reflects current societal, technological and economic realities, as well as evolving stakeholder expectations," ConocoPhillips said. ExxonMobil Corp., the US' largest integrated oil company, similarly cast doubt on the feasibility of net zero, although it has yet to explicitly remove the target. "ExxonMobil is continuing to pursue the net-zero ambition, but we recognize the external challenges of technology and policy play a role in our ability to achieve net-zero," an ExxonMobil spokesperson said. Competing for capital The retrenchment, which began to take shape among some others in the sector in 2025, comes into focus at a time of surging profits for companies with exposure to crude oil and refined products, driven by disruptions from the US-Israel war with Iran. Among the 10 largest US oil producers and refiners, second-quarter 2026 net income came in about 3.5 times higher year over year for the group on average. Profits were much higher on a quarter-over-quarter basis for much of the group. Even before the latest run-up in prices triggered by the war, some large oil companies were chasing production growth and engineering exits from low-carbon investments that, in some cases, had been initiated only years earlier. That trend has continued into 2026. BP PLC reported after-tax impairments of about $4 billion for 2025, which the company largely attributed to its biogas and renewable energy businesses. The company went on to announce plans to sell Archaea Energy Inc., the US renewable gas business it acquired in 2022. Other energy companies headquartered outside the US, including Shell PLC, TotalEnergies SE and Woodside Energy Group Ltd., have cast doubt upon certain decarbonization targets of late or otherwise trimmed low-carbon spending. Of TotalEnergies' roughly $16 billion in 2026 capital expenditures, low-carbon spending is estimated to account for about 20%, which is on the higher end of the company's peer group but represents a decline from 25% in its previous plan, according to S&amp;P Global Energy CERA director of integrated oil equity research Sam Hanna. The decision to cut back is justified by lower return expectations relative to traditional oil and gas businesses, Hanna wrote in a Sept. 8 report. "In addition, it was a challenge for TotalEnergies to balance the capital needed for its ambitious low-carbon targets with the continued need to invest in upstream and LNG assets that provide a significant portion of current cash flow, especially when taking into account that about 40% of cash flow is being distributed to shareholders in the form of dividends and share buybacks," Hanna wrote. Volatile markets, shifting policy The evolution of decarbonization strategies is a response to concerns among some companies that they overshot on low-carbon investments, said Andrejka Bernatova, managing partner of energy sector investor Dynamix Capital Partners. "We definitely have seen over the past couple of years a pretty significant scale down in terms of clean energy interest and investments from companies in the traditional natural resources space," Bernatova said. For investments in the US, a change in sentiment and policy between the Biden and Trump administrations also partly explains decisions to scale back, Bernatova said. For the second time, in January 2025, President Donald Trump withdrew the US from the Paris Agreement. Trump has repeatedly beckoned oil producers to increase production to lower prices and has revoked Biden administration climate policies, such as stricter vehicle tailpipe rules, designed to reduce carbon emissions. Most oil and gas companies have been decreasing low-carbon investment, said Simon Wong, a portfolio manager with Gabelli Funds. "The only areas that are still seeing some investments are biofuels and carbon capture," Wong said. "With the Middle East conflict, the conversation has shifted from climate/net-zero initiatives to energy security." Another factor influencing how companies discuss net zero may be the growing controversy surrounding carbon offsets and voluntary carbon markets since 2023, NYU's Jaffe said. Many net-zero strategies relied on offsets to address residual emissions that could not be eliminated directly. "The collapse of the voluntary offsets market and the collapse in volume of the voluntary offsets market was really probably more material to companies changing how they spoke about net-zero than changes in political or economic views of climate change," Jaffe said. Companies investing in the US will always have to consider the prospect that evolving federal policies will affect investments across energy resources, according to Bernatova. "Sometimes investing in the US is a little bit more risky than investing in emerging markets because obviously, the tide shifting, right, every four years or every eight years pretty significantly," Bernatova said. The role of buyers While the US government has pulled back decarbonization rules and policies of the Biden administration, companies with international operations still need to understand how foreign governments and customers view climate risks and decarbonization, Jaffe said. "The fact that one of those governments, or two of those governments, might have turned on a coal plant in the middle of a national emergency doesn't mean that you're capturing what the long-term concern is for that country," Jaffe said. Absent regulatory pressures from the current administration, reducing emissions is still critical for US energy exporters, especially LNG companies that sell exclusively into foreign markets, said Eric Smith, a business professor at Tulane University and associate director of the Tulane Energy Institute. Emissions reporting requirements under the EU's methane rules for energy imports grow increasingly strict over the next several years, and by August 2030, the bloc will require buyers that import fossil energy under new or renewed contracts to demonstrate that their imports have an associated methane intensity below a specified threshold. "The big international companies and virtually anybody that sells LNG is in the position of having to abide by its customers' rules, not by its country of origin rules," Smith said. Susan Dlin contributed to this article. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/ratings/en/blog/investors-look-beyond-labels</link><description>Sustainable finance is entering a more mature phase as investors continue to support sustainability and transition objectives but increasingly assess issuers through the credibility of their transition strategy, quality of execution, and ability to demonstrate measurable progress. Labels remain relevant but are no longer sufficient on their own to attract capital. </description><title>Investors Look Beyond Labels </title><pubDate>15 July 2026 17:04:00 GMT</pubDate><content><![CDATA[ Investor Relations | 15 July 2026 Investors Look Beyond Labels Insights from European investors on the evolution of sustainable finance Overview Sustainable finance is entering a more mature phase as investors continue to support sustainability and transition objectives but increasingly assess issuers through the credibility of their transition strategy, quality of execution, and ability to demonstrate measurable progress. Labels remain relevant but are no longer sufficient on their own to attract capital. At the same time, market growth continues to be constrained by the lack of consistent transition definitions, metrics, and disclosure standards. As sustainability markets become more fragmented across regions and regulatory zones, investors are placing greater emphasis on issuer-level analysis, robust data, and clear evidence linking financing activity to real-world outcomes. Credibility matters more than labels Investors are increasingly focused on whether issuers can demonstrate a credible transition pathway rather than on the specific label attached to a financing instrument. The conversation is shifting toward implementation, capital allocation, and delivery against stated objectives. Investors recognize that the transition cannot be financed through labelled bonds alone and are placing greater emphasis on how transition considerations are embedded across an issuerâs broader financing strategy. Transition metrics remain elusive Despite strong investor interest in transition finance, the absence of widely accepted definitions and metrics continues to limit market scale. Measuring progress remains particularly challenging for complex sectors and financial institutions, while issues around Scope 3 emissions, avoided emissions, and sector-specific pathways hinder comparability. Investors continue to supplement external frameworks with their own internal assessments. Labeled markets have limits Labelled bonds remain valued by investors but are increasingly viewed as one component of a broader transition toolkit. Structural constraints, including limited market size, concentration in certain sectors, and weak pricing incentives, continue to restrict growth. Investors are paying closer attention to the quality and credibility of structures, particularly in sustainability-linked instruments where KPI design and ambition remain under scrutiny. Data quality is a differentiator Reliable, transparent, and comparable data is becoming increasingly important in investment decision-making. Investors continue to highlight concerns regarding disclosure consistency and methodological differences across providers. External reviews and second-party opinions remain useful reference points, and they are generally used as supporting evidence rather than primary investment decision tools. Increasingly, investors reward issuers that demonstrate transparency, consistency, and measurable progress over time. Water finance gains visibility Water-related financing is attracting growing investor interest owing to its tangible impact and relatively low political sensitivity. However, the market remains small, with a limited investable universe and evolving measurement standards. Investors see long-term potential but acknowledge that broader adoption will require greater issuance volumes and stronger reporting frameworks. Adaptation moves up the agenda While transition remains the dominant theme, adaptation and resilience are receiving increased attention. Investors are beginning to assess how companies address physical climate risks and resilience investments, despite the lack of established adaptation metrics and frameworks. Many expect financing needs related to adaptation to grow significantly over time. Fragmentation is increasing Regional policy divergence, differing regulatory approaches, and varying attitudes toward transition activities are making global standardization more challenging. Broader themes such as energy security, competitiveness, technological transformation, and geopolitics are increasingly influencing sustainability discussions. As a result, investors are relying more heavily on issuer-specific analysis and scenario assessment than on standardized market frameworks. Looking ahead The sustainability finance market is evolving from one driven by labels and frameworks to one focused on credibility, execution, and measurable outcomes. Investors remain committed to supporting transition and sustainability objectives, but increasingly require clear evidence of progress, high-quality data, and transparent reporting to inform investment decisions. As market fragmentation, regulatory divergence, and evolving transition pathways continue to shape the landscape, issuer-specific analysis is becoming more important than standardized approaches. Together, these trends point to a more disciplined and outcome-oriented sustainable finance market, where long-term access to capital will increasingly depend on an issuer's ability to demonstrate credible and measurable impact. S&amp;P Global Geraldine Cametti Director of Market Outreach, EMEA Investor Engagement &amp; Market Insights Investor Engagement &amp; Market Insights S&amp;Pâs analyses, including ratings, are statements of opinion as of the date they are expressed, and are not statements of fact or recommendations to purchase, hold, or sell any securities, and should not be relied on when making investment or other business decisions. S&amp;P obtains information from sources it believes to be reliable, but does not audit and undertakes no duty of due diligence or independent verification of information it receives. S&amp;Pâs opinions and analyses do not address the suitability of any security. Please read our full disclaimer. ]]></content></item><item><link>https://www.spglobal.com/ratings/en/blog/korean-investor-sentiment</link><description>Investors are shifting toward more defensive, quality-income and diversified allocations amid concerns over stretched U.S. valuations, private credit/CLO weakness, higher-for-longer rates, AI-related credit risks, and tight Asian spreads.</description><title>Korean Investor Sentiment: Turning to Defensive, Quality-Oriented Allocation Amid Rising Market Risks</title><pubDate>19 August 2026 17:04:00 GMT</pubDate><content><![CDATA[ Investor Relations | 19 August 2026 Korean Investor Sentiment: Turning to Defensive, Quality-Oriented Allocation Amid Rising Market Risks Favoring high-quality income-generating assets while remaining cautious on private credit, elevated valuations, prolonged higher interest rates, and AI-driven disruption. Overview Investors are shifting toward more defensive, quality-income and diversified allocations amid concerns over stretched U.S. valuations, private credit/CLO weakness, higher-for-longer rates, AI-related credit risks, and tight Asian spreads. It suggests a need to prioritize capital preservation, regional relative value, benchmark-aware portfolio construction, and more selective deployment. What We're Hearing Overall positioning is becoming more defensive: Investors are rotating toward high-quality, income-generating assets that exhibit bond-like characteristics and can offer greater resilience during periods of market volatility. Many participants are also reassessing geographic allocations, reallocating from the U.S. to Europe as well as local market, supported by FX considerations, better relative value, and concerns over stretched U.S. valuations. Investor appetite for private credit and CLOs has weakened: Korean institutional investors remain cautious on private credit and collateralized loan obligation (CLO) investments. While the asset class continues to offer attractive yields relative to many traditional fixed-income sectors, investors are increasingly concerned about the impact of sustained high interest rates on borrower fundamentals. Diversification and benchmark alignment are taking priority: Investors increasingly favor diversified, benchmark-aware portfolio construction rather than concentrated, high-conviction positions. This shift reflects a growing focus on volatility management, risk mitigation, and maintaining flexibility in uncertain market conditions. AI is emerging as a structural credit risk: Artificial intelligence is increasingly viewed not only as an opportunity but also as a long-term credit risk factor. Investors are assessing which sectors could face disruption as AI technologies reshape competitive dynamics, with software and certain service-oriented industries frequently cited as areas of concern. S&amp;P Global Grace Guo Director of Market Outreach, APAC Investor Engagement &amp; Market Insights Investor Engagement &amp; Market Insights S&amp;Pâs analyses, including ratings, are statements of opinion as of the date they are expressed, and are not statements of fact or recommendations to purchase, hold, or sell any securities, and should not be relied on when making investment or other business decisions. S&amp;P obtains information from sources it believes to be reliable, but does not audit and undertakes no duty of due diligence or independent verification of information it receives. S&amp;Pâs opinions and analyses do not address the suitability of any security. Please read our full disclaimer. ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/infographics/horizons-energy-expansion-sustainability/clean-energy-pulse</link><description>S&amp;amp;P Global Energy Horizons Clean Energy Pulse tracks 69 indicators to measure global clean energy growth momentum</description><title>S&amp;amp;P Global Energy Horizons Clean Energy Pulse</title><content><![CDATA[ S&amp;P Global Energy Horizons Horizons Clean Energy Pulse 70 key indicators. One essential outlook. Track the Trends Last updated: 8th October, 2026 Frequently Asked Questions: Horizons Clean Energy Pulse What is the Horizons Clean Energy Pulse? The Horizons Clean Energy Pulse by S&amp;P Global Energy Horizons is a comprehensive market intelligence report that tracks 70 distinct indicators to assess the momentum of the global clean energy expansion. To provide a holistic view of the energy transition, these indicators span a wide range of critical domains, including: Macroeconomics &amp; Policy: Physical climate trends, macroeconomic environment, and international/national climate policies. Markets &amp; Investment: Corporate climate commitments, environmental and carbon markets, and investor trends across the energy and utility sectors. Technologies &amp; Supply Chain: Deployment of renewable power and energy storage, low-carbon hydrogen, CCUS (carbon capture, utilization, and storage), electric vehicles (EVs), and biofuels. Commodities &amp; Emerging Signals: Commodity and component pricing, cleantech supply chains, and emerging trends like AI-driven power demand and advanced nuclear technologies. What question is each indicator of the Horizons Clean Energy Pulse answering? Every indicator in the report is evaluated to answer one core question: âDoes this signal suggest an acceleration (bullish) or a deceleration (bearish) of the clean energy expansion?â Because the energy transition is complex, no single indicator is sufficient to determine the overall pace of the market. Many signals have conflicting direct and indirect implications. By evaluating a diverse set of indicators together, S&amp;P Global analysts provide a directional, judgment-driven view of the market's true momentum. How often will the Horizons Clean Energy Pulse indicators be updated? To ensure clients have access to the most current market intelligence, most indicators are updated on a monthly or quarterly basis. The exact update frequency depends on the availability and reporting cycles of the underlying data. Does the graphic on this page represent the full Horizons Clean Energy Pulse report? No, this graphic offers a high-level summary of our findings. The full data, comprehensive analysis, and underlying metrics of the Horizons Clean Energy Pulse are exclusive to clients of S&amp;P Globalâs services related to clean energy expansion (Clean Energy Technology, Carbon and Scenarios, and Biofuels and Bioenergy). Interested in unlocking the full insights? Please fill out the âSpeak to a Specialistâ form on this page to arrange a trial or request a personalized demo. Who can benefit from the insights and analysis in the Horizons Clean Energy Pulse report? The report is an essential resource for professionals navigating the global energy transition, providing actionable, data-driven insights for: Investors and Asset Managers: Capitalize on transition-linked equity performance, track capital flows, and monitor M&amp;A activities and valuations across the energy, utility and renewables sectors. Investment Bank Coverage Managers: Receive timely industry insights across sectors that enable you to spot deal opportunities, deepen client relationships, and pitch winning strategies to executives. Corporate Sustainability &amp; Procurement Leaders: Stay ahead of evolving corporate climate commitments (such as SBTi frameworks), carbon market trends, and clean energy procurement strategies like corporate PPAs. Energy, Power, and Utility Executives: Monitor near-term project pipelines for solar PV, battery energy storage systems (BESS), low-carbon hydrogen, and CCUS, while tracking emerging power demand drivers like AI data center load growth. Supply Chain &amp; Manufacturing Professionals: Navigate cleantech supply chain risks, monitor critical component and commodity price volatility (e.g., lithium, copper, and solar modules), and track regional EV and biofuel market dynamics. Policymakers &amp; Regulatory Analysts: Track global climate policy developments, including Paris Agreement NDCs, EU ETS carbon market revisions, and regional interventions impacting clean energy deployment. What guidelines are there for the use of the content in the Horizons Clean Energy Pulse? Use of the content on this page is governed by our website Terms of Use. Subscribe to our Horizons Clean Energy Expansion newsletter Sign Up Explore our Thought Leadership and Solutions Speak to a Specialist Ready to take the next step? Complete the form and a team member will reach out to discuss how our solutions can support you. ]]></content></item><item><link>https://www.spglobal.com/ratings/en/blog/takeaways-private-markets-forum</link><description>We recently hosted our inaugural U.S. Private Markets Forum in New York City, convening investors and market participants to discuss the evolving dynamics across private credit, fund finance, and structured solutions.</description><title>Takeaways from S&amp;amp;P Global Ratingsâ&amp;#x80;&amp;#x99; U.S. Private Markets Forum</title><pubDate>08 May 2026 17:04:00 GMT</pubDate><content><![CDATA[ Investor Relations | 08 May 2026 Takeaways From S&amp;P Global Ratingsâ U.S. Private Markets Forum Our annual event took place on Wednesday, May 6, 2026 Overview We recently hosted our inaugural U.S. Private Markets Forum in New York City, convening investors and market participants to discuss the evolving dynamics across private credit, fund finance, and structured solutions. Discussions highlighted the growing role of innovative structuring, the use of fund finance as both an investment opportunity and liquidity tool, and the shifting priorities shaping today's investor landscape. Key Takeaways Investor sentiment toward private credit and structured solutions remains broadly constructive, though capital deployment has become more selective and disciplined. As investors place greater emphasis on downside protection and risk-adjusted returns, competitive differentiation is increasingly defined by structuring expertise, underwriting discipline, and manager capabilities rather than access to capital alone. Market Environment: Demand for yield continues to support private credit; however, investors are prioritizing risk-adjusted returns and capital preservation over headline yield. There is heightened scrutiny on liquidity management, refinancing risk, and the ability of portfolios to withstand stress scenarios, reflecting a more defensive and disciplined investment posture. Structural Underwriting: Structure and alignment have become central to investment decisions. Investors are evaluating opportunities through a holistic lens, focusing not only on asset quality but also on manager quality and track record, incentive alignment, covenant protections, repayment flexibility, and transparency. Structural integrity is a key driver of downside protection. Market Convergence: Boundaries between corporate, project, infrastructure, and structured finance continue to blur, creating a broader and more complex opportunity set. Transactions are becoming more bespoke, often incorporating both debt- and equity-like features to tailor risk-return profiles to investor needs. Structural Innovation: Flexible structures, including fund finance solutions, fund wrappers, hybrid vehicles, joint ventures, and layered capital stacks are becoming increasingly important. Innovation is increasingly occurring through transaction structure, enabling investors to optimize liquidity, risk exposure, and capital efficiency. Role of Insurance Capital: Insurance investors have become an increasingly important source of capital in private credit, influencing not only pricing and transaction terms but also the evolution of deal structures. Their focus on ratings outcomes, regulatory capital efficiency, and long-duration liabilities is driving greater demand for bespoke solutions that balance capital efficiency, robust structuring, and long-term risk-adjusted returns. Investment Conditions: Investors remain willing to pursue complex opportunities where the economic rationale is compelling and risks are clearly understood and appropriately allocated. Complexity itself is not a barrier, provided it is supported by transparency, strong governance, and robust structural protections. Whatâs Next Looking ahead, market differentiation will increasingly depend on the ability to structure transactions that effectively balance flexibility, liquidity, transparency, and long-term investor protection. Managers that can consistently deliver on these dimensions are likely to be best positioned to attract capital and scale in an increasingly selective environment. S&amp;P Global Layla Beyzavi Director of Market Outreach, NAM Investor Engagement &amp; Market Insights Investor Engagement &amp; Market Insights S&amp;Pâs analyses, including ratings, are statements of opinion as of the date they are expressed, and are not statements of fact or recommendations to purchase, hold, or sell any securities, and should not be relied on when making investment or other business decisions. S&amp;P obtains information from sources it believes to be reliable, but does not audit and undertakes no duty of due diligence or independent verification of information it receives. S&amp;Pâs opinions and analyses do not address the suitability of any security. Please read our full disclaimer. ]]></content></item><item><link>https://www.spglobal.com/ratings/en/blog/pdi-apac-2026</link><description>This summer, the PDI APAC Forum 2026 brought together more than 300 private markets professionals in Singapore, including limited partners (LPs), general partners (GPs), intermediaries, and law firms.</description><title>Private Credit Momentum Builds Across APAC: Key Takeaways from the PDI APAC</title><pubDate>24 July 2026 17:04:00 GMT</pubDate><content><![CDATA[ Investor Relations | 24 July 2026 Private Credit Momentum Builds Across APAC Key takeaways from the PDI APAC Forum 2026 Overview This summer, the PDI APAC Forum 2026 brought together more than 300 private markets professionals in Singapore, including limited partners (LPs), general partners (GPs), intermediaries, and law firms. The event offered a valuable opportunity to connect with investors and industry leaders while exploring the trends shaping private credit across the region. S&amp;P Global Ratings colleagues also joined discussions on topics such as Middle Market Lending and Future-Proofing Portfolios Through Private Debt, providing perspectives on the evolving market landscape. What We Heard Investor demand remains strong, but selective: Private credit continues to attract investor interest across APAC as market participants seek opportunities to enhance portfolio yield. However, investors are approaching the asset class with caution, placing greater emphasis on collateral quality, sponsor strength, covenant protections, and downside mitigation. Growing interest in asset-backed finance in Australia: Australia emerged as a key area of focus throughout the discussions. Investors and market participants highlighted opportunities in senior secured direct lending, Australian real estate, and infrastructure-related investments. India is attracting attention for structured and mid-market credit: Indiaâs private credit market continues to gain momentum, with panelists pointing to growth over the past decade. As traditional bank lending has become more constrained, private credit providers have stepped in to finance middle-market companies and structured lending opportunities. AI, digital infrastructure, and energy transition drive financing needs: The rapid expansion of AI technologies and digital infrastructure is creating substantial financing requirements across the APAC region. Forum speakers highlighted growing demand for investment in data centers and connectivity infrastructure, as energy needs associated with these developments are also accelerating investment in renewable energy solutions. Looking Ahead The discussions at the PDI APAC Forum 2026 underscored the continued evolution of the private credit market across APAC. From the growth of asset-backed finance in Australia and expanding credit opportunities in India to rising demand for AI-related infrastructure and transition financing, investors are navigating a market shaped by both innovation and selectivity. S&amp;P Global Vijay Chandler Director of Market Outreach, APAC Investor Engagement &amp; Market Insights Investor Engagement &amp; Market Insights S&amp;Pâs analyses, including ratings, are statements of opinion as of the date they are expressed, and are not statements of fact or recommendations to purchase, hold, or sell any securities, and should not be relied on when making investment or other business decisions. S&amp;P obtains information from sources it believes to be reliable, but does not audit and undertakes no duty of due diligence or independent verification of information it receives. S&amp;Pâs opinions and analyses do not address the suitability of any security. Please read our full disclaimer. ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/natural-gas/100726-germany-eyes-aib-hub-following-state-run-gas-registry-launch</link><description>The German Environment Agency (UBA) intends to apply for gas membership of the Association of Issuing Bodies once it establishes a national statutory registry for renewable gas certificates, a spokesperson from the body told Platts, part of S&amp;amp;P Global Energy. The agency has been designated by the government as the competent authority responsible for establishing and managing Germany&amp;apos;s central,</description><title>Germany eyes AIB Hub following state-run gas registry launch</title><pubDate>07 October 2026 13:14:35 GMT</pubDate><author><name>Irina Breilean</name></author><content><![CDATA[ Agriculture, Energy Transition, Natural Gas, Electric Power, Biofuels, Renewables, Hydrogen October 07, 2026 Germany eyes AIB Hub following state-run gas registry launch By Irina Breilean Editor: Jonathan Loades-Carter Getting your Trinity Audio player ready... HIGHLIGHTS UBA prepares state-run gas GO registry AIB volumes surge in wake of France entry German volumes seek alternative destinations The German Environment Agency (UBA) intends to apply for gas membership of the Association of Issuing Bodies once it establishes a national statutory registry for renewable gas certificates, a spokesperson from the body told Platts, part of S&amp;P Global Energy. The agency has been designated by the government as the competent authority responsible for establishing and managing Germany's central, state-administered statutory registry for Guarantees of Origin (GOs) covering biomethane, hydrogen and other renewable gases. State-appointment is a requirement for a country/registry to join the AIB Hub. "Once the UBA's gas registry becomes fully operational, the UBA is expected to apply to expand its AIB membership to include the Gas Scheme Group and connect to the AIB Hub for cross-border GO trading," the spokesperson said. The agency told Platts it is "intensively preparing the administrative, technical and legal foundations" to set the GO registry up. "The UBA gas registry is being developed in parallel to and independent of the existing biomethane registry managed by Dena," the spokesperson added. The German Energy Agency, or Dena, is a privately-run company working on topics such as energy efficiency, renewable energy sources and intelligent energy systems. It operates a biomethane GO registry, but it cannot apply for AIB membership as it is not the authorized body in Germany to administer the gas certificates. UBA said it cannot specify a "concrete launch date for full operational service and connection to the AIB Hub," but it was "already actively involved in the AIB's Gas Scheme Group to help shape the European transfer system." UBA is already a full AIB member for the Electricity Scheme Group, managing electricity GOs via its registry. AIB gas grows The hub boasts 42 members and six observers from 36 countries, as of Oct. 7. The national registries of six new member states joined this year alone, boosting cross-border transfer capacities and GO fungibility among participating members. France â the bloc's largest biomethane producer â officially joined the AIB Hub in June, boosting the significance of AIB membership as spot transactions among member countries increase. Between June and September, France exported a total of 624 gigawatt-hours of gas GOs and received 15.7 GWh, with Spain and the Netherlands as the largest recipients. "One painful question for everybody in Germany is the AIB connection," said a European biomethane trader from Germany. "[The German Environment Agency] will operate a registry, but we don't know when. They are not speeding up the connection to the AIB hub." Lacking connectivity to other AIB member states, German volumes will continue to seek alternative destinations, such as domestic consumption for transport compliance or transfer to member countries of the European Renewable Gas Registry, such as the UK. One use case is transferring German unsubsidized waste-derived GOs to meet obligations under the UK's Renewable Transport Fuel Obligation, which requires major suppliers of transport fuel to ensure a specific percentage of their supplied fuel comes from sustainable, low-carbon sources. Platts last assessed the European Unsubsidized Biomethane (EUB) spot prices â reflecting the most competitive EU waste-derived GO prices â at â¬35.125/megawatt-hour on Oct. 7. The EUB price is currently being set by German volumes, which trade at a discount to Dutch or Danish unsubsidized production. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/natural-gas/100626-dutch-green-gas-blending-obligation-passes-lower-house-of-parliament</link><description>The lower house of the Dutch parliament passed the national green gas blending obligation on Oct. 6, with the rules expected to take effect in 2027. Lawmakers voted on the main legislative package, including 12 proposed amendments, four of which were passed, covering rules on the suspension of the rules determining the blending obligation and buy-out price, on the use of buy-out fees, on</description><title>Dutch green gas blending obligation passes lower house of parliament</title><pubDate>06 October 2026 18:21:52 GMT</pubDate><author><name>Irina Breilean</name></author><content><![CDATA[ Natural Gas, Energy Transition, Agriculture, Carbon, Renewables, Biofuels October 06, 2026 Dutch green gas blending obligation passes lower house of parliament By Irina Breilean Editor: Mariana Castro Getting your Trinity Audio player ready... HIGHLIGHTS Parliament approves 2027 green gas mandate Lawmakers reject feedstock caps and delays Buyout fees to return to energy customers The lower house of the Dutch parliament passed the national green gas blending obligation on Oct. 6, with the rules expected to take effect in 2027. Lawmakers voted on the main legislative package, including 12 proposed amendments, four of which were passed, covering rules on the suspension of the rules determining the blending obligation and buy-out price, on the use of buy-out fees, on evaluation proceedings, and on annual monitoring. A September proposal to cap the maximum total reduction that can be mandated at 1.425 million metric tons of CO2 equivalent starting in 2031 was rejected, along with proposals to exclude manure feedstocks and to delay the entry into force of the obligation until 2028. One approved amendment gives the parliament four weeks to review key implementing rules before the government formally adopts them. Another amendment to direct price support will require buyout fees to be returned to energy customers through methods such as direct payments, rebates, or a funded support program that reduces energy bills. The evaluation deadline will be brought forward from five years to three years, and the final text will also include annual monitoring reports to be submitted to both chambers of the Dutch parliament. The bill was initially submitted to parliament in May and outlines the renewable gas blending obligations Dutch suppliers must meet. The legislative text will now move to the upper house, the Senate, for review. The rules require annual reductions in emissions by supplying biomethane into the national gas grid, starting with a 0.63 million metric tons of CO2 chain-emission reduction in 2027 and rising to 2.85 MMtCO2 by 2031. The bill introduces a separate tradable unit -- the Green Gas Unit, or GGE -- to comply with the blending obligation. Suppliers may buy out all or part of their annual obligation, acting as a price ceiling if GGEs become scarce. The buyout price has been set at â¬450/mtCO2e. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/2026/10/who-is-challenging-the-valuation</link><description>In May 2026, the Monetary Authority of Singapore (MAS) published an information paper on valuation practices for fund management companies (FMCs). </description><title>Who Is Challenging the Valuation?</title><pubDate>29 September 2026 12:00:00 GMT</pubDate><author><name>Peter Alleston</name></author><content><![CDATA[ Research â Sep 29, 2026 Who Is Challenging the Valuation? By Peter Alleston What MASâs findings mean for private market fund managers In May 2026, the Monetary Authority of Singapore (MAS) published an information paper on valuation practices for fund management companies (FMCs). The paper sets out MASâs expectations across four areas: governance, policies and procedures, ongoing price validation, and valuation approaches and methodologies. It draws on inspections of selected fund managers across several investment strategies, with some inspections conducted by external auditors appointed by MAS. Although the paper covers a broad range of funds, several findings are particularly relevant to managers of private equity, venture capital and private credit funds. Investments held by these funds are often classified as Level 3 because their valuations rely significantly on unobservable inputs and professional judgement, including forecasts, portfolio company or borrower information, capital structures, proxy benchmarks and expected exits or recoveries. For private market fund managers, the findings highlight six areas to consider when assessing whether valuations are properly supported and challenged. 1. Governance must provide effective challenge MAS found that some smaller fund managers appointed senior managers involved in portfolio management to oversee the valuation of certain assets, creating potential conflicts of interest. Some valuation committees also lacked formal or sufficiently detailed terms of reference. Deal teams often have the best knowledge of an asset, but they are also involved in the original investment decision and its ongoing management. Their input is important, but the resulting valuation should be reviewed outside the deal team. Those reviewing the valuation need sufficient expertise, information and authority to question the methodology and material assumptions. They should be able to request further analysis and escalate matters that cannot be resolved. The key test is whether the governance process results in informed challenge and a clear record of how material judgements were resolved. 2. Policies must reflect the investments held MAS expects valuation policies to cover all relevant asset classes and financial instruments. Its inspections found cases where firms did not follow their policies, did not explain deviations or failed to keep policies aligned with current practice. For a private market fund, a general requirement to measure investments at fair value may not provide enough practical guidance. The policy should address the instruments and risks in the portfolio, including different equity rights, convertible instruments, impaired private credit exposures, collateral and complex capital structures. It should also set out responsibilities, approved approaches, review frequency, escalation requirements and the treatment of exceptions. Additional review may be needed following a financing round, restructuring, covenant breach, material underperformance or change in expected exit or recovery. The policy needs to convert valuation principles into procedures that can be applied consistently to the fundâs investments. 3. Portfolio company and borrower information must be tested MAS found that several fund managers did not critically assess information supplied by portfolio companies prior to using it in their valuation models. Private market valuations commonly rely on financial statements, forecasts, budgets, cap tables, operating metrics and collateral information provided by portfolio companies or borrowers. This may be the most recent information available, but it should still be reviewed. Checks may include comparisons with historical results, audited financial information and previous forecasts. Material forecast shortfalls, inconsistencies or changes in assumptions should be understood before the information is used. The information does not always need to be produced independently. However, the manager should be able to explain how the information was assessed and how any limitations were reflected in the valuation. 4. Validation should test the supporting evidence MAS expects fund managers to cross-check key valuation inputs and assumptions against independent data and relevant benchmarks where appropriate. For Level 3 investments, there may be no quoted price against which to check the valuation. Validation therefore needs to examine the evidence supporting the result. For venture capital, a recent funding round may provide useful evidence, but its terms, investor rights and circumstances should be understood before the transaction price is applied to other share classes. For private equity, validation may cover forecasts, comparable companies and changes in market multiples. For private credit, it may cover expected cash flows, credit spreads, collateral values and recovery assumptions. The valuation policy should state who performs these checks, how differences are investigated and when issues need to be escalated. The objective is not simply to produce another number. It is to test whether the valuation is properly supported. 5. Methodologies must respond to new information MAS identified one case in which a fund manager reclassified restructured non-performing loans as performing without making corresponding valuation adjustments. MAS reported that this overstated NAV and resulted in excessive management fees. This shows the risk of leaving the valuation unchanged when the economics of the investment have changed. For private credit, a covenant breach, restructuring, deterioration in borrower performance or change in expected recovery may affect cash flows, discount rates, scenarios, collateral analysis and the choice of methodology. For private equity and venture capital, a new financing round, revised forecast, shorter cash runway or change in exit expectations may also require the valuation approach to be reconsidered. Consistency is important, but it should not prevent a justified change. Any decision to change or retain the methodology should be supported, challenged and documented. 6. The role of external providers must be clear MAS found that most inspected firms used external valuers or fund administrators to support valuation or NAV reporting. It also identified weaknesses in the selection and oversight of some providers, including their independence, expertise and valuation methodologies. Different providers perform different roles. A fund administrator may calculate NAV using values supplied by the manager. An external valuation specialist may independently review selected assets, inputs or assumptions. An auditor reviews valuations for financial reporting purposes. Managers should therefore understand the scope of each providerâs work, the information received from the deal team and the material judgements that fall outside that providerâs scope. A clearly defined scope enables an external valuation specialist to provide focused, independent challenge over the assets, inputs and assumptions presenting the greatest valuation risk. Questions for private market fund managers Who is accountable for each material valuation, and does the reviewer have the independence and capability needed to challenge it effectively? Do the valuation policies reflect the investments and risks in the current portfolio, and is there evidence that they are followed in practice? How are portfolio company and borrower information, key assumptions and other Level 3 inputs tested, and how are identified limitations reflected in the valuation? What developments trigger reassessment of the valuation, and how are the resulting decisions challenged, approved and documented? How are valuation differences, exceptions and overrides investigated, escalated and resolved? Where an external provider is involved, what has it assessed independently, and how are its independence, expertise, methodology and performance evaluated? Why this matters A private market valuation should be able to withstand scrutiny. That requires reliable information, appropriate methodologies, clear accountability and effective challenge of material judgements. Weaknesses in these areas can affect NAV, performance, fees and investor reporting. MAS expects FMCs to benchmark their valuation arrangements against its supervisory expectations and promptly address any gaps identified. Managers should therefore be able to explain not only how a valuation was calculated, but also how its key assumptions were tested and significant differences or exceptions were resolved. S&amp;P Global Private Market Valuations provides independent valuations and assurance reviews to help FMCs strengthen the review and challenge of private equity, private credit and other Level 3 valuations. Learn more about Private Market Valuations Click Here ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/blog/energy-transition/100726-et-highlights-denmark-hydrogen-pipeline-eu-cbam-us-renewables-goals</link><description>Energy transition highlights: Our editors and analysts bring you the biggest stories from the industry this week, from renewables to storage to carbon prices.</description><title>ET Highlights: Denmark eases hydrogen pipeline rules, EU rebuffs Russiaâ&amp;#x80;&amp;#x99;s CBAM challenge, US states cut renewables goals</title><pubDate>06 October 2026 20:05:00 GMT</pubDate><author><name>Staff </name></author><content><![CDATA[ Energy Transition, Renewables, Emissions, Carbon October 7, 2026 ET Highlights: Denmark eases hydrogen pipeline rules, EU rebuffs Russiaâs CBAM challenge, US states cut renewables goals Energy Transition Highlights: Our editors and analysts bring together the biggest stories in the industry this week, from renewables to storage to carbon prices. Top story Denmark eases hydrogen pipeline rules to derisk producer commitment Denmark has overhauled key terms governing capacity bookings for its planned hydrogen pipeline backbone, easing financial commitments on producers and sharply increasing state operating support, in a move designed to unblock a project critical to connecting Danish green hydrogen output with German and broader European demand. The Danish Ministry of Climate, Energy and Utilities revised the original deal on the country's hydrogen infrastructure after producers flagged heavy financial obligations ahead of a final investment decision on the pipeline. Under the revised terms, the initial 500 megawatt booking requirement as of Dec. 1, 2026, is retained, but bookings will no longer be binding at that stage. Producers now have until Nov. 1, 2027 â nearly a year longer than under the original schedule â to formally book capacity in the hydrogen pipeline. A binding guarantee of at least 100 MW must be in place by Dec. 31, 2027, for the project to proceed. Benchmark of the Week â¬84.30/mt Platts nearest December EU ETS carbon allowances on Oct. 2, falling from a recent peak of â¬88.25/metric ton in mid-September. Explore Platts Energy Transition Price Assessments Editor's Picks: Free and premium content SPGlobal.com/energy PATH TO NET ZERO: US states cut renewable goals on affordability concerns US states are pulling back on clean energy goals or reclassifying what qualifies as a clean energy resource, as concerns about energy affordability grow. "The repeals and the backtracking of the targets started last year," S&amp;P Global Energy CERA senior principal analyst Monica Hlinka said. Asia emerging as key market for green ammonia power: Amogy CEO Asian countries are emerging as key early markets for distributed green ammonia power, as rising electricity demand from AI, data centers, and industrial users is supporting the deployment of behind-the-meter clean power solutions, Amogy co-founder and CEO Seonghoon Woo told Platts. Such clean power solutions can serve local demand while reducing the need for large-scale grid infrastructure such as transmission cables, Woo said. S&amp;P Global Energy Core Brussels confident CBAM will survive Russia's WTO challenge The European Commission said it is confident its Carbon Border Adjustment Mechanism fully complies with World Trade Organization rules, as it prepared to defend the landmark climate trade measure before a formal dispute panel established at Russia's request. "We are confident that CBAM is designed in full compliance with WTO rules," a commission spokesperson told Platts, adding that Brussels would engage with the panel proceedings but would hold no direct negotiations with Moscow. Indian fertilizer body in talks for renewable ammonia tender round: FAI official The Fertiliser Association of India (FAI) is discussing a potential new round of renewable ammonia tenders with the government, although any new auction would depend on the progress made by developers awarded capacity in the first round, an FAI official told Platts. India allocated subsidies for 724,000 mt/year of renewable ammonia production under the 174.90 billion rupees ($1.83 billion) Strategic Interventions for Green Hydrogen Transition scheme to 11 fertilizer firms in 2025 auctions. Vichada ARR project issues 565,544 Gold Standard carbon removal credits The Vichada Climate Reforestation Project in Colombia has issued 565,544 Gold Standard carbon removal credits across 2022-2025 vintages, adding fresh supply from an established afforestation and reforestation project to the voluntary carbon market. The issuance, completed Sept. 28, was the projectâs fifth and included 398,796 credits from vintage 2025, accounting for 70.5% of the total, project developers Forliance, InverBosques and Aldea Forestal said. ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/sustainability-insights-behind-the-shades-energy-efficiency-measures-s101703482</link><description>This report does not constitute a rating action. Chart 1 Energy efficiency--broadly defined as achieving the same outcomes with less energy--is a key part of the transition to a low-carbon, climate resilient future across a range of activities, including building performance, transportation systems, industrial processes, equipment and appliances, and data centers and other digital infrastructure. An S&amp;amp;P Global Ratings Shade of Green (shade) represents our qualitative opinion on how consistent an</description><title>Sustainability Insights: Behind The Shades: Energy Efficiency Measures</title><pubDate>05 October 2026 09:25:48 GMT</pubDate></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/highlights-from-sp-global-ratings-european-private-markets-conference-2026-s101708955</link><description>This report does not constitute a rating action. The 3rd annual European Private Markets Conference on Sept. 23, 2026, in London highlighted the credit fundamentals underlying this evolving and expanding market, and the global challenges it faces from trade conflicts, energy and supply chain disruptions, geopolitical fragmentation, and rapid technological change. The market expansion reflects rising volume and increasing diversity in funding sources and geographies. The proliferation of speciali</description><title>Highlights From S&amp;amp;P Global Ratings&amp;apos; European Private Markets Conference 2026</title><pubDate>05 October 2026 20:11:49 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/natural-gas/100626-lng-remains-attractive-despite-tough-patches-shell-ceo</link><description>Shell PLC CEO Wael Sawan argued Oct. 6 that the fundamentals underpinning LNG remain &amp;quot;very attractive,&amp;quot; even as global prices hover around recent peaks during the second major supply-side disruption to rock the global market this decade. &amp;quot;LNG continues to be diversified, it continues to be reliable, it continues to be flexible,&amp;quot; Sawan said at the Energy Intelligence Forum in London. Shell is a</description><title>LNG remains attractive despite &amp;apos;tough patches&amp;apos;: Shell CEO</title><pubDate>06 October 2026 14:54:02 GMT</pubDate><author><name>Matt Hoisch</name><name>Charlie Mitchell</name></author><content><![CDATA[ LNG, Natural Gas, Refined Products, Energy Transition, Coal, Chemicals, Crude Oil, Renewables, Diesel-Gasoil October 06, 2026 LNG remains attractive despite âtough patchesâ: Shell CEO By Matt Hoisch and Charlie Mitchell Editor: Jonathan Loades-Carter Getting your Trinity Audio player ready... HIGHLIGHTS Highlights expected price dip amid supply wave Chevron CEO sees more LNG headwinds, uncertainty Sawan warns of oil shock absorber limits Shell PLC CEO Wael Sawan argued Oct. 6 that the fundamentals underpinning LNG remain "very attractive," even as global prices hover around recent peaks during the second major supply-side disruption to rock the global market this decade. "LNG continues to be diversified, it continues to be reliable, it continues to be flexible," Sawan said at the Energy Intelligence Forum in London. Shell is a major LNG player. Last week, the company announced a final investment decision to develop a second phase of the LNG Canada export facility, which it operates. The expansion is set to double the project's capacity to 28 million metric tons/year, with commercial operations expected to begin in the early 2030s. Sawan allowed that the international LNG market has faced "a couple of tough patches" amid the ongoing Middle East war and Russia's full-scale invasion of Ukraine. Still, he highlighted the projected price dip expected across the coming years as an anticipated wave of new supply hits the market. Sawan also voiced continued confidence in the long-term viability of Middle Eastern energy supplies, despite the ongoing war. "Those resources will get to the market," he said. "We continue to work with government partners in the Middle East to be able to figure out what I hope will be a post-conflict world will look like." In addition to diversification, Sawan said he expects market players to "build resilience" into energy value chains. Chevron CEO Mike Wirth offered a more tempered assessment of LNG market growth at another session during the London forum. While he also said demand would likely grow, Wirth cautioned that he sees "a wider range of error bars around the forecast." LNG faces challenges from alternatives, Wirth argued, such as liquid petroleum products, which, he said, have energy density and portability advantages relative to the super chilled fuel. Different energy sources pose other challenges, Wirth asserted. "When you look at natural gas and LNG in particular, it's not as clean as renewables, and it's not as affordable as coal," he said. Platts, part of S&amp;P Global Energy, assessed the JKM benchmark for LNG delivered into Northeast Asia at $26.159/million British thermal unit on Oct 6. The index is 137% higher than the same time last year. Venezuela gas push Sawan also discussed Shell's growing efforts in Venezuela. He explained the company sees more opportunities to differentiate itself in gas rather than heavy oil as it re-enters the resource-rich country in the months since US forces removed then-President NicolÃ¡s Maduro in January. Sawan highlighted Shell's work to develop phase 1 of the Loran gas field and the Dragon gas field. "Those are offshore, which addresses some of the potential security issues," he said, adding they would be "hardwired" into infrastructure linked to the company's nearby Manatee gas project in Trinidad and Tobago. That gas will then feed into the Atlantic LNG export facility in Trinidad and Tobago. "The nature of that broader opportunity is one that we feel very confident in," he said. Shock absorber limits When it comes to the oil market, Sawan said industry players had been "positively surprised by the strength of the [market's] shock absorbers when truly tested" after eight months of the US-Iran war. Chinese consumption dynamics, bumper refining runs, high inventories, improved exports by Gulf states in recent weeks and large quantities of oil on water have been cited as factors softening the impact of the crisis, which sent Platts Dated Brent beyond $140/b in April and diesel cracks to record highs. However, "there is a limit to how much those shock absorbers can continue to take," Sawan said, particularly with the Ukraine war also roiling markets. With increased volatility, Shell is focused on the fundamentals, Sawan said, and the "basics of needing diverse sources of supply [and] diverse customers," as well as a resilient balance sheet. The company will therefore "triple down" on the basins where it is a "world class" operator, he said, adding that he was "disappointed" with Shell's historic track record on exploration. That means "a bit more in Namibia, a bit more in Angola, looking further at Brazil," Sawan said. Its Graff discovery in Namibia â alongside TotalEnergies' Venus find â put the Orange Basin on the exploration map, while its Brazilian output has neared 500,000 barrels/day of oil equivalent this year. Beyond oil, Sawan said the company's integrated trading team had allowed it to create value in a "more volatile world," and said he was bullish about both the downstream and chemicals sectors. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/refined-products/100626-eu-to-delay-methane-law-assess-refining-strategy-to-combat-fuel-costs</link><description>The European Union hopes to bring down winter fuel costs with a one-year delay to its incoming methane regulation, strategic talks on refining, and a new taskforce to bundle its energy demand, European Commission President Ursula von der Leyen said Oct. 6. In a live address from Brussels, von der Leyen said the EU would &amp;quot;give flexibility to exporters&amp;quot; for another year on methane, extending a</description><title>EU to delay methane law, assess refining strategy to combat fuel costs</title><pubDate>06 October 2026 17:30:40 GMT</pubDate><author><name>Kelly Norways</name></author><content><![CDATA[ Energy Transition, Natural Gas, Coal, Refined Products, Electric Power, Crude Oil, Emissions, Diesel-Gasoil, Gasoline October 06, 2026 EU to delay methane law, assess refining strategy to combat fuel costs By Kelly Norways Editor: Richard Rubin Getting your Trinity Audio player ready... HIGHLIGHTS Delayed methane regulation offers 'flexibility' to exporters Energy and defense commissioners to assess refining sector Bloc faces â¬100B extra fossil fuel bill due to Middle East war The European Union hopes to bring down winter fuel costs with a one-year delay to its incoming methane regulation, strategic talks on refining, and a new taskforce to bundle its energy demand, European Commission President Ursula von der Leyen said Oct. 6. In a live address from Brussels, von der Leyen said the EU would "give flexibility to exporters" for another year on methane, extending a January 2027 deadline for oil, natural gas and coal importers to demonstrate compliance with the bloc's internal monitoring, reporting and verification standards. With diesel prices now double their pre-war levels, the bloc is also launching a strategic dialogue on European refineries co-chaired by its energy commissioner, Dan JÃ¸rgensen, and commissioner for defense, Andrius Kubilius, von der Leyen said, aimed at cutting costs and ensuring supplies for both civilians and military purposes. "Families and industries are paying the cost of the crisis," she told the European Parliament, estimating that the EU has shouldered an additional â¬100 billion cost for its imported fossil fuels as a consequence of the Middle East conflict. Faced with the prospect of intensifying cost pressures into the winter season, the bloc has agreed to additionally launch a new task force to bundle energy demand. The new model would mirror emergency measures implemented in the aftermath of Russia's invasion of Ukraine in 2022, according to von der Leyen, but would go from "simple matchmaking" to a more sophisticated process aggregating demand and delegating joint procurement to market operators, she said. In the coming months, the commission will additionally be coming forward with its electricity action plan, which aims to cut fossil fuel imports by doubling the share of electricity in its energy mix, the commission president said. Electricity currently makes up 25% of final EU energy use, offering a potential for â¬260 billion in annual savings if the target is met, according to commission estimates. Von der Leyen praised a recent G7 decision to release 100 million barrels of diesel and crude oil from its members' strategic reserves, announced on Oct. 2, which set a four-month deadline for new supplies to reach the market. "This will help stabilize the global crisis," she said, without providing further detail on the contribution of the group's European members. Responding to the announcement in Brussels, MEP Christian Ehler offered support for the methane delay, but called a one-year suspension "unrealistic" and argued that the EU should go further. "We need a three-year postponement of import requirements, until 2030, to give businesses legal certainty to secure stable energy supplies," Ehler said. Warning on state support On an EU level, the bloc plans to prolong its "AccelerateEU" initiative, a temporary state aid framework aimed at supporting the region's industrial sectors through the crisis, although national support schemes should remain temporary and targeted, von der Leyen warned. "There should be no blanket handouts, as that would only increase the demand," von der Leyen said, praising energy voucher schemes in France and Romania as examples of good policies that have specifically targeted low-income families. Her comments come as several EU member states have decided to extend temporary fuel tax cuts, while other countries, such as Poland, have opted to impose windfall taxes on fuel companies to respond to soaring prices. From a pure supply perspective, EU officials maintain that the region does not currently face any energy shortages, although representatives have amplified warnings of a "tough winter" ahead due to elevated prices. ICE low sulfur gasoil futures markets have cooled since G7 members agreed to avoid energy export bans in a statement Oct. 2, helping to allay fears of potential US restrictions. Physical prices have also come off from all-time highs but remain elevated. Platts, part of S&amp;P Global Energy, assessed CIF Northwest European ULSD cargoes at $1,398/mt on Oct. 5, down from a high of $1,642/mt on Sept. 15. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/podcasts/energy-evolution/100626-ais-power-boom-tests-big-techs-net-zero-promises</link><description>In this week&amp;apos;s episode of Energy Evolution, host Camilla Naschert turns the spotlight on Big Tech as part of S&amp;amp;P Global Energy&amp;apos;s annual series examining how the world&amp;apos;s largest companies are faring on their paths to net-zero emissions. The AI infrastructure boom has driven the sector&amp;apos;s energy appetite to new heights, and its carbon footprint is rising in tandem. Tech reporter Stefan Modrich of S&amp;amp;P</description><title>AI&amp;apos;s power boom tests Big Tech&amp;apos;s net-zero promises</title><pubDate>06 October 2026 22:18:20 GMT</pubDate><author><name>Camilla Naschert</name><name>STEFAN MODRICH</name><name>Karin Rives</name></author><content><![CDATA[ Natural Gas, Electric Power, Energy Transition, Emissions October 06, 2026 AI's power boom tests Big Tech's net-zero promises Featuring Camilla Naschert, STEFAN MODRICH, and Karin Rives HIGHLIGHTS Tech firms' AI expansion increases emissions Survey finds utilities miss climate targets Power demand surge drives gas capacity growth In this week's episode of Energy Evolution, host Camilla Naschert turns the spotlight on Big Tech as part of S&amp;P Global Energy's annual series examining how the world's largest companies are faring on their paths to net-zero emissions. The AI infrastructure boom has driven the sector's energy appetite to new heights, and its carbon footprint is rising in tandem. Tech reporter Stefan Modrich of S&amp;P Global Market Intelligence surveyed the top 30 IT companies by market cap, tracking targets across Scopes 1, 2 and 3. He found genuine ambition sitting uneasily alongside a commercial race to secure power at any cost. Senior reporter Karin Rives completes the picture from the utility side. Five years into her survey of the 30 largest US electric utilities, she found that two-thirds are either not on pace to meet their climate goals, have delayed them or have scrapped them entirely. Some companies cited reliability and affordability as justification, while others are pressing ahead with new gas capacity to keep pace with a surge in electricity demand. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/credit-faq-how-will-the-middle-east-war-reshape-dubais-residential-property-market-in-2027-s101707425</link><description>This report does not constitute a rating action. Dubai&amp;apos;s residential real estate market has seen a significant drop in transaction volumes as a result of the Middle East war. However, specific segments of the market are now experiencing a price correction, albeit a moderate one. Thatâ&amp;#x80;&amp;#x99;s because of a change in market dynamics over the past several years, with the United Arab Emirates&amp;apos; (UAE&amp;apos;s) visa reforms supporting a higher proportion of long-term investors and end users. S&amp;amp;P Global Ratings&amp;apos; ba</description><title>Credit FAQ: How Will The Middle East War Reshape Dubai&amp;apos;s Residential Property Market In 2027?</title><pubDate>06 October 2026 11:56:18 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/agriculture/093026-india-saf-premium-needs-shared-cost-market-architecture-saf-association</link><description>India should develop multiple sustainable aviation fuel pathways and prioritize domestic processing of feedstocks before exporting surplus fuel, while creating price-support and financing mechanisms to distribute SAF&amp;apos;s green premium across the value chain, according to industry platform SAF Association. The country should not select between hydroprocessed esters and fatty acids-based SAF and</description><title>India SAF premium needs shared-cost market architecture: SAF Association</title><pubDate>30 September 2026 12:38:08 GMT</pubDate><author><name>Samyak Pandey</name></author><content><![CDATA[ Agriculture, Refined Products, Energy Transition, Biofuels, Jet Fuel, Vegetable Oils, Renewables, Carbon September 30, 2026 India SAF premium needs shared-cost market architecture: SAF Association By Samyak Pandey Editor: Ribhu Ranjan Getting your Trinity Audio player ready... HIGHLIGHTS India needs multipathway SAF strategy Cost premium requires shared market structure Process feedstocks domestically before export India should develop multiple sustainable aviation fuel pathways and prioritize domestic processing of feedstocks before exporting surplus fuel, while creating price-support and financing mechanisms to distribute SAF's green premium across the value chain, according to industry platform SAF Association. The country should not select between hydroprocessed esters and fatty acids-based SAF and alcohol-to-jet production because neither waste lipids nor ethanol can alone support long-term aviation demand, Rohit Kumar, secretary general of the SAF Association, said in written responses to Platts, part of S&amp;P Global Energy. "I would not frame this as an either-or question," Kumar said. "India will need a multipathway SAF strategy, because no single feedstock can realistically support the scale of aviation fuel demand over the long term." HEFA produced from used cooking oil and other eligible waste fats has the strongest immediate commercial proposition because the technology is comparatively mature and recognized under international SAF frameworks. ATJ provides a strategic medium- and longer-term opportunity by using India's established ethanol production and supply infrastructure, he said. India's indicative roadmap targets SAF blending on international flights of 1% in 2027, 2% in 2028 and 5% in 2030. The roadmap remains a proposal or policy target rather than a fully enforced mandate, Kumar said. Feedstock potential to certified supply India has developed significant ethanol capacity concentrated in major production states, giving ATJ a foundation that few other emerging SAF markets possess, Rohit Kumar said. However, the relevant test is not total nameplate ethanol capacity, but whether the feedstock can deliver competitive lifecycle emissions, reliable availability and certification for aviation use. HEFA and refinery co-processing could establish near-term supply, while ATJ would help India move beyond the physical limits of waste-lipid availability. Fischer-Tropsch routes based on agricultural residues and municipal waste, alongside power-to-liquid or e-SAF, could progressively broaden the feedstock portfolio as technology and commercial conditions mature. The industry must evaluate each route against sustainable feedstock availability, lifecycle carbon performance, certification, technology maturity, cost and international market access, rather than headline theoretical output, Kumar said. IndianOil's Panipat refinery has already obtained India's first ISCC CORSIA certification for SAF production. The certification covers lifecycle emissions and traceability and creates a pathway for Indian airlines to integrate certified SAF into their operations. The facility is expected to support initial SAF availability through UCO co-processing, while IndianOil is also developing a commercial ATJ plant with initial co-processing volumes to support India's first 1% target. Green premium requires shared solution The cost difference between SAF and conventional jet fuel cannot be sustainably borne by airlines alone, particularly in a price-sensitive aviation market, according to Kumar. "The SAF price gap is fundamentally a market-creation problem as much as a technology problem," he said. India would need a combination of long-term offtake agreements, production incentives, concessional and blended finance, contracts for difference or similar revenue-support mechanisms, carbon-value recognition and SAF certificates or book-and-claim systems, he added. Those mechanisms would need clear rules governing ownership of lifecycle-emissions benefits and other environmental attributes to prevent the same reduction from being claimed more than once. The objective should be to shift the policy discussion from identifying a single party to pay the premium toward creating a market structure that progressively reduces it through scale, improved technology, mature supply chains and lower financing costs, Kumar said. The recommendation supports conclusions in the joint S&amp;P Global Energy-SAF Association report, which said blending requirements should be complemented by supply-side measures such as grants, tax credits, or revenue certainty, and by offtaker support, including levies or cost-sharing mechanisms. Export fuel, retain domestic value and feedstocks India could participate across the Asia-Pacific SAF chain through feedstock aggregation, technology, certified production, logistics and environmental-attribute management, but should avoid building an export model centered primarily on shipping unprocessed feedstocks, Kumar said. "We should not build an export industry that simply ships away our best feedstocks while domestic aviation remains dependent on imported energy." India should instead collect and process waste domestically, manufacture certified SAF, develop local technology and skills, meet domestic requirements and export surplus volumes and related capabilities, he added. Platts, part of S&amp;P Global Energy, assessed Sustainable Aviation Fuel HEFA-SPK FOB Straits, reflecting CORSIA-certified cargoes, at $2,420/metric ton on Sept. 29, down $20/mt from Sept. 28. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/092526-india-ppa-market-shifts-toward-hybrid-and-bess-backed-projects-amid-grid-risks</link><description>India&amp;apos;s corporate renewable power market is increasingly shifting toward hybrid and storage-backed projects as transmission constraints, curtailment risks and varied state-level tariffs shape power purchase agreement pricing, market participants told Platts, part of S&amp;amp;P Global Energy, on Sept. 24. Generators and independent power producers said buyers are increasingly favoring hybrid renewable</description><title>India PPA market shifts toward hybrid and BESS-backed projects amid grid risks</title><pubDate>25 September 2026 14:31:27 GMT</pubDate><author><name>Ahmad afiq Muhammad zahir</name></author><content><![CDATA[ Energy Transition, Electric Power, Renewables September 25, 2026 India PPA market shifts toward hybrid and BESS-backed projects amid grid risks By Ahmad afiq Muhammad zahir Editor: Ankit Ajmera Getting your Trinity Audio player ready... HIGHLIGHTS IPPs eye BESS to help mitigate solar curtailment ALMM mandates could raise baseline solar tariffs Virtual PPAs face contract pricing uncertainty India's corporate renewable power market is increasingly shifting toward hybrid and storage-backed projects as transmission constraints, curtailment risks and varied state-level tariffs shape power purchase agreement pricing, market participants told Platts, part of S&amp;P Global Energy, on Sept. 24. Generators and independent power producers said buyers are increasingly favoring hybrid renewable projects over standalone solar and wind assets to better match their consumption profiles. "Developers are evaluating battery energy storage systems to mitigate solar curtailment and improve supply reliability, although high capital costs remain a constraint," said a Tamil Nadu-based PPA broker. Solar-plus-BESS projects are expected to fetch a premium of about 1.00-1.50 rupees/kilowatt-hour over standalone solar, depending on storage duration, battery capacity and discharge profile, according to independent power producers. In September, market participants reported indicative 15-year ex-busbar prices for projects exceeding 100 megawatts in the 3.00-4.50 rupees/kWh range for solar, 4.50-5.50 rupees/kWh range for wind and solar-wind hybrids and 5.00-7.00 rupees/kWh range for solar-plus-BESS projects with an 80:20 solar-to-storage mix. "Ex-busbar prices are generally stable, with generators and independent power producers typically only revising the tariff on a quarterly basis," the Tamil Nadu-based PPA broker said. Grid risks, regulation Transmission congestion, evacuation constraints and forced reductions in renewable generation remain key risks. In some regions of the country, clean energy capacity has outpaced grid expansion, creating transmission bottlenecks that limit how much power the network can absorb. As a result, generators are sometimes required to curtail output, resulting in lost revenue. "Grid infrastructure has not expanded quickly enough in some regions to match renewable generation growth, exposing developers to stranded capacity and lost revenue," a Gurugram-based independent power producer said. Compounding these physical grid risks are evolving regulatory requirements, with independent power producers saying the government's updated Approved List of Models and Manufacturers List-II, which specifies domestic solar cell manufacturers and cell models, could increase solar PPA prices from around 3.50 rupees/kWh currently to higher levels over the near to medium term by narrowing procurement options and increasing the cost of compliant modules. Solar PPA prices could rise to around 3.90 rupees/kWh in the near term, according to independent power producers. A second Gurugram-based independent power producer said the gradual phaseout of Inter-State Transmission System waivers, introduced in 2016 to reduce the cost of interstate renewable power sales, and evolving state-level energy banking rules could add to commercial uncertainty around long-term investments in the near term. PPA prices Market participants said that while ex-busbar solar PPA prices were generally indicated at a baseline of 3.50-5.00 rupees/kWh nationwide, landed PPA tariffs varied across states after factoring in local transmission, grid and open-access charges. "Ex-bus prices are broadly similar across India, but landed economics vary significantly by state," the second Gurugram-based IPP said. A 15-year solar PPA was indicated at around 2.50-3.70 rupees/kWh ex-bus, with local transmission, grid and open-access charges adding 1.50-2.00 rupees/kWh, according to a Mumbai-based independent power producer and a Gujarat-based corporate buyer on Sept. 24. Three- to five-year solar PPAs were indicated at around 4.00 rupees/kWh ex-bus, with transmission and grid charges adding about 2.00 rupees/kWh, according to a Tamil Nadu-based PPA broker on Sept. 11. A Noida-based trader said Sept. 11 that landed renewable power costs could reach as high as 9.90 rupees/kWh after accounting for transmission and open-access charges, compared with conventional "brown power" electricity tariffs of about 2.20-3.50 rupees/kWh. Limited vPPA activity Virtual PPA activity remains limited due to uncertainty over pricing and contract structures. With conventional power prices at around 2.20-3.50 rupees/kWh, a Tamil Nadu-based broker said vPPA strike prices would need to be lower than physical PPA tariffs to attract wider corporate participation. "Data centers could support future growth," the Mumbai-based independent power producer said. However, market participants said most data center buyers currently prefer to procure renewable power directly through bundled arrangements, such as green tariffs or PPAs paired with International Renewable Energy Certificates. Upstream cost benchmarks Underpinning these tariff dynamics are volatile upstream costs. Independent power producers said solar modules, land acquisition, local taxes, BESS components and wind turbines remain key sources of uncertainty in capital expenditure. The Tamil Nadu-based power broker estimated that solar modules account for 60%-70% of total project costs, adding that significant volumes of modules are currently imported from China, leaving project economics exposed to global supply chain disruptions and foreign exchange fluctuations. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/natural-gas/100526-dutch-parliament-set-to-vote-on-key-biomethane-blending-obligation-amendments</link><description>The Dutch parliament is preparing to vote on a package of amendments to the proposed green gas blending obligation, including a one-year postponement of its start. The House of Representatives is scheduled to vote Oct. 6 on 10 amendments proposed in September, including provisions that would mean the obligation would apply no earlier than Jan. 1, 2028. A separate amendment seeks to cap the buy-out</description><title>Dutch parliament set to vote on key biomethane blending obligation amendments</title><pubDate>05 October 2026 15:01:34 GMT</pubDate><author><name>Irina Breilean</name></author><content><![CDATA[ Energy Transition, Natural Gas, Agriculture, Emissions, Renewables, Biofuels October 05, 2026 Dutch parliament set to vote on key biomethane blending obligation amendments By Irina Breilean Editor: Anoop Menon Getting your Trinity Audio player ready... HIGHLIGHTS Parliament to vote on blending delay to 2028 Buy-out price cap of â¬450/mtCO2e proposed New package seeks to limit eligibility to domestic gas The Dutch parliament is preparing to vote on a package of amendments to the proposed green gas blending obligation, including a one-year postponement of its start. The House of Representatives is scheduled to vote Oct. 6 on 10 amendments proposed in September, including provisions that would mean the obligation would apply no earlier than Jan. 1, 2028. A separate amendment seeks to cap the buy-out price â the compensation payment suppliers must make instead of acquiring green gas units (GGE) â at â¬0.45/GGE, equivalent to reductions of â¬450/metric ton of carbon dioxide equivalent. The ceiling would be nominal rather than automatically increasing through indexation, as in the current draft law submitted to parliament in May. Any increase would require further legislative amendments. The proposed changes would also introduce stronger limits on the scheme's scale and cost by establishing a statutory upper limit on greenhouse gas emissions reductions. The proposed maximum would rise from 315,000 mtCO2e reductions in 2027 to 955,000 mtCO2e in 2030, then reach 1.425 million mtCO2e annually from 2031 through 2035. The same ceiling would then continue from 2036 unless the Dutch Parliament approves an amendment. The government would retain the ability to set lower annual quantities. The package would further require an annual government report to both chambers of parliament on the scheme's effects, and would bring forward the evaluation deadline from five years to three years. The evaluation would consider affordability, the development of the green gas market, the impact on Dutch gas consumption and the role of manure digestion in the agricultural transition. Other amendments seek to strengthen parliamentary oversight. Draft regulations that determine the level of the blending obligation and the buyout price would have to be submitted to both chambers four weeks before adoption, except for the initial regulations. Finally, one proposal from Sept. 25 seeks to restrict eligible green gas to gas produced at facilities in the Netherlands and injected into the Dutch gas transmission or distribution network. The proposal, which was brought forward by Andre Flach of the Reformed Political Party, seeks to support domestic green gas production. But the government previously broadened eligibility to include green gas produced elsewhere in Europe, a move welcomed by the market. This came after the European Commission expressed concerns that prioritizing domestic Dutch production was contrary to Article 34 of the Treaty on the Functioning of the EU (TFEU), which prohibits quantitative import restrictions across the bloc. Platts, part of S&amp;P Global Energy, assesses a wide range of biomethane Guarantees of Origin prices, including those for Dutch waste and manure, both subsidized and unsubsidized feedstocks. Dutch spot certified, subsidized waste was last assessed at â¬30.95/MWh on Oct. 2, while certified, unsubsidized waste was assessed at â¬43.925/MWh. Spot-certified, unsubsidized manure was assessed at â¬150.125/MWh on the same day, with demand coming from the Dutch ERE emissions-reduction scheme for land transport. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/natural-gas/100526-european-carbon-prices-drop-to-7-week-low-as-market-eyes-upcoming-policy-agenda</link><description>European carbon prices reached their lowest levels since late August in the early hours of Oct. 5, with market participants citing the end of compliance, a technical break, and prevailing policy risk. EU Allowances for the nearest December traded at â&amp;#x82;¬82.40/metric tons of CO2 equivalent ($91.87/mtCO2e) at 0750 GMT Oct. 5, down 2.39% compared to Friday&amp;apos;s close, according to the Intercontinental</description><title>European carbon prices drop to 7-week low as market eyes upcoming policy agenda</title><pubDate>05 October 2026 12:10:53 GMT</pubDate><author><name>Irina Breilean</name></author><content><![CDATA[ Energy Transition, Emissions, Carbon October 05, 2026 European carbon prices drop to 7-week low as market eyes upcoming policy agenda By Irina Breilean Editor: Surbhi Prasad Getting your Trinity Audio player ready... HIGHLIGHTS Compliance deadline ends, support breaks EUAs fall to â¬82.40/mtCO2e Policy risk remains ahead of ENVI deadline European carbon prices reached their lowest levels since late August in the early hours of Oct. 5, with market participants citing the end of compliance, a technical break, and prevailing policy risk. EU Allowances for the nearest December traded at â¬82.40/metric tons of CO2 equivalent ($91.87/mtCO2e) at 0750 GMT Oct. 5, down 2.39% compared to Friday's close, according to the Intercontinental Exchange. This was the lowest EUA price since Aug. 19, a seven-week low. "The compliance bid vanished," said Stefan Kermer, founder of analytics provider Carbon Insights. "Free allocation ran late this year, with roughly a quarter of the 2026 volume still untransferred in late September, so installations had to buy in the market to cover the 2025 surrender." Companies covered by the EU Emissions Trading System had until the end of September to surrender permits for 2025 emissions, with data from the Union Registry showing a compliance rate of 96.9% as of Oct. 5. Separately, a status table from Sept. 24 showed that free allocation transfers stood at 344.38 million as of Sept. 24, out of a total of 444.54 million scheduled for distribution for the 2026 period. "Quite a technical move," said an EUA trader with an energy trading firm, agreeing that the compliance deadline also played a role. Kermer added that "the chart broke," driving prices lower. "The rising support off the April and August lows sat around â¬84.5, and Friday went through it." Allowances for the nearest December were down 1.59% by 1630 London time on Oct. 2, according to Platts, part of S&amp;P Global Energy. This was followed by a bearish Monday open, with the price down a further 0.72% at 0600 am London time. Speaking on the outlook for October, the trader said he does not anticipate significant moves, barring policy announcements. "Probably range-trading between here and â¬87/mtCO2e," he said, adding that â¬95/mtCO2e is the highest he thinks the market will go this year. Policy risk remains as EU ETS negotiations continue in Brussels, with key milestones on the horizon, including the Oct. 6 deadline for the environmental parliamentary committee to submit amendments to the European Commission's July proposal. "Policy is the backdrop," said Stefan Kermer. "Italy and Czechia have tabled a paper for the European Council on 15 and 16 October asking to suspend the reserve intake, about 190 million allowances, which is roughly 39% of a year's auction volume." EU environment ministers are scheduled to meet for the Environment Council on Oct. 12, where they are expected to discuss the EU ETS review and other climate topics. Following this, the European Council is scheduled to meet on Oct. 15-16. "We have several significant political meetings coming up that could be potentially bearish," said Jan Ahrens, co-founder at analytics firm Transition Metrics. "Both the EU Economy Council on [Oct. 9] as well as the Environment Council on [Oct. 12] could bring negative news on the EU ETS Reform, and further calls to delay ETS2. All of this supports a rather bearish picture, which we generally expect to remain." Heads of state previously committed to completing the ETS review by the first quarter of 2027, but market participants have cast doubt on the feasibility of this timeline. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/100526-interview-china-tightens-green-certificate-rules-eyes-hourly-matching-energytag</link><description>China&amp;apos;s green electricity certificate market is evolving as prices recover and the market tests storage-linked and hourly-matched certificates, Annie Wong, APAC Manager of EnergyTag, an independent non-profit organization, said in an interview with Platts, part of S&amp;amp;P Global Energy, last week. What is changing in China&amp;apos;s use of green electricity certificates under the Renewable Portfolio Standard?</description><title>INTERVIEW: China tightens green certificate rules, eyes hourly matching: EnergyTag</title><pubDate>05 October 2026 08:22:26 GMT</pubDate><author><name>Rachel Tan</name></author><content><![CDATA[ Energy Transition, Electric Power, Metals &amp; Mining, Chemicals, Emissions, Ferrous, Renewables, Non-Ferrous October 05, 2026 INTERVIEW: China tightens green certificate rules, eyes hourly matching: EnergyTag By Rachel Tan Editor: Namrata Srivastava Getting your Trinity Audio player ready... HIGHLIGHTS China tightens GEC temporal matching rules Aluminum faces mandatory renewable quotas Hourly certificate pilots test storage value China's green electricity certificate market is evolving as prices recover and the market tests storage-linked and hourly-matched certificates, Annie Wong, APAC Manager of EnergyTag, an independent non-profit organization, said in an interview with Platts, part of S&amp;P Global Energy, last week. What is changing in China's use of green electricity certificates under the Renewable Portfolio Standard? China is increasingly using green electricity certificates, or GECs, within the Renewable Portfolio Standard, or RPS, framework, Annie said. "More requirements are being introduced, but for most sectors compliance is still not fully mandatory," she said. "That has meant the market still faces oversupply, especially in the voluntary segment." RPS obligations are mainly met through renewable power delivered via the grid, with GECs serving as a supplementary tool. Annual targets have risen, increasing the importance of certificates, she said. Temporal matching is tightening, limiting buyers' use of older certificates for current-year compliance. "Authorities are moving toward stricter annual matching, so only certificates from the relevant compliance year can be used," Annie said. Geographic matching is also tightening. Grid interconnection and provincial rules increasingly constrain cross-provincial GEC transactions, limiting buyers' ability to source certificates from certain provinces and within set limits. "That reduces flexibility and makes the compliance market more location-specific," she said. How is this affecting GEC prices and market behavior? Average monthly GEC prices in China have doubled from 2025 levels as policymakers intensified their use within the RPS framework, Annie said, after prices fell sharply in 2024-25 and remained low until tighter compliance rules supported a recovery. Spreads between certificate vintages also widened. "The stricter temporal matching rules are making current-year certificates more valuable for compliance," Annie said. "Older vintages still have value in the voluntary market, but they are less useful for regulated buyers." Most GEC buying comes from RPS-covered industries, with the remainder tied to voluntary demand. Voluntary buyers have more flexibility to use older vintages and face fewer restrictions, but expanding compliance demand could give voluntary procurement a larger role in price formation. Why is aluminum the main sector to watch? Aluminum is the only sector subject to a mandatory RPS-related requirement, Annie said, while other sectors generally face no strict penalties for noncompliance. That could change if carbon border adjustment mechanism-style measures expand. "The policy is still more like an index or a direction of travel for many sectors," she said. "But aluminum is already facing a stronger obligation." "If similar measures expand across steel, cement and fertilizers, those sectors would face stronger incentives to procure renewable power and comply more closely with RPS-related rules," Annie said.. How closely are GECs starting to reflect power market fundamentals? Annie said GEC supply increasingly mirrors the power market, with storage likely to shape future market development. "The next critical step is storage," she said. "Without storage, you still have a mismatch between renewable generation and the hours when power is most valuable." Participants expect hourly matching to link GEC prices more closely to power conditions, with heavier issuance and lower prices during solar-heavy daytime hours and tighter supply and higher prices at night. "Once hourly matching becomes mandatory, the price shape could look very similar to the duck curve seen in power markets," Annie said. What role could storage-linked certificates play? Storage-linked GECs could improve battery economics, align storage with policy goals and provide operators with additional revenue for shifting renewable electricity into evening hours, Annie said. Some markets still rely on feed-in tariff-type arrangements or mandated solar-plus-storage ratios, while policymakers explore storage-related certificates. "That could help restore arbitrage economics for battery energy storage systems and improve bankability," Annie said. "It would also support grid integration and system balancing." Such a mechanism could help operators monetize nighttime delivery rather than rely mainly on ancillary services or regulated arrangements. Are granular and hourly certificates already being tested? "Yes," Annie said. EnergyTag-style granular certificates are available in several markets, building on existing energy attribute certificate systems. "Most markets already issue energy attribute certificates, so those can become the base layer," she said. "Then hourly certificates can be limited to accredited assets and specific use cases." Exporters facing carbon border adjustment mechanism-related scrutiny are one expected user group. Pilot projects are underway, including one involving a Chinese chemical manufacturer that matched consumption and generation hourly using GECs. In Hong Kong, CLP China has introduced a 24/7 hourly-matching renewable electricity product, although corporate interest remains limited. EnergyTag is working toward a five-year goal of moving compliance systems closer to hourly matching, with the next year focused on tracking developments among regulators, companies and certificate markets, Annie said. What comes next for the market? China's GEC market remains marked by tighter compliance requirements and persistent oversupply, but Annie said the policy direction is becoming clearer. Stricter temporal and geographic rules and broader industrial decarbonization pressure could bring more sectors into the market, while further development of these mechanisms could link certificate prices more closely to when and where renewable electricity is generated, stored and consumed. "The market is moving away from a flat certificate concept," Annie said. "Over time, it is becoming more connected to the actual shape of the power system." US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/093026-us-midwest-southwest-lead-clean-power-purchasing-in-2026</link><description>Rising US power demand continues to drive momentum for clean energy offtake agreements in 2026, especially in the Midwest and Southwest. Utilities, hyperscale cloud-computing giants and other corporations signed about 31.2 gigawatts of clean power contracts from January through August, according to S&amp;amp;P Global Energy CERA data. &amp;quot;The big takeaway from us is momentum isn&amp;apos;t slowing,&amp;quot; said Tony Lenoir,</description><title>US Midwest, Southwest lead clean power purchasing in 2026</title><pubDate>30 September 2026 20:23:54 GMT</pubDate><author><name>Nushin Huq</name></author><content><![CDATA[ Electric Power, Energy Transition, Renewables September 30, 2026 US Midwest, Southwest lead clean power purchasing in 2026 By Nushin Huq Editor: Richard Rubin Getting your Trinity Audio player ready... HIGHLIGHTS Corporate buyers sign 31.2 GW through August Solar dominates Southwest contract activity Rising US power demand continues to drive momentum for clean energy offtake agreements in 2026, especially in the Midwest and Southwest. Utilities, hyperscale cloud-computing giants and other corporations signed about 31.2 gigawatts of clean power contracts from January through August, according to S&amp;P Global Energy CERA data. "The big takeaway from us is momentum isn't slowing," said Tony Lenoir, associate director at 451 Research by S&amp;P Global. "There were questions around that last year because of the new administration, the [One Big Beautiful Bill Act], and the acceleration of the tax credit phase-out and so forth, but it's not slowing down at all." The Midcontinent Independent System Operator region had the most clean energy dealmaking this year, with 23 contracts signed through August, totaling almost 8.3 GW. About half of the contracts were corporate deals, including a 1.9-GW contract between Google LLC and Xcel Energy Inc. in Minnesota for a mix of solar, wind and battery storage, and a nearly 1.5-GW agreement between Google and Cypress Creek Renewables LLC for a portion of a large-scale solar-plus-storage project in Arkansas. "Every time I talk to a developer, usually the first thing that they're trying to do is find offtake for a MISO project," Owen Glubiak, vice-president of markets at Resurety, told Platts, part of S&amp;P Global Energy. Resurety provides advisory and consulting services to offttakers. It also has a regulated trading platform for virtual power purchase agreements. S&amp;P Global Energy partners with Resurety for certain environmental and renewable energy price assessments in North American markets, including power purchase agreements. Clean energy developers remain active in the Electric Reliability Council of Texas region, though solar buyers have begun to shy away from the ERCOT market. "It's not to say that the big four hyperscalers have," Glubiak said. "I know they are still buying in ERCOT, but the rest of the corporate buyers candidly have started to look elsewhere." By volume, the non-ISO Southwest followed MISO with nearly 5.7 GW of utility and corporate contracts signed through August, according to CERA data. The total was led by a 3-GW solar development agreement between Salt River Project and NextEra Energy Resources LLC, the competitive generation arm of NextEra Energy Inc. In total, nine PPAs and tolling contracts were signed in the non-ISO Southwest through August, including four with utilities and five with corporate offtakers. Much of the non-ISO activity is centered around digital infrastructure and energy resources, Adam Wilson, senior principal research analyst at S&amp;P Global Energy, told Platts. "It's relatively close to areas of operation where data center locations are, but it's also a function of, particularly in the West, [being] resource-driven," Wilson said. "Solar is very attractive in those markets because they produce a ton of power and they're highly efficient, and that helps the power purchase agreement contracts be much more financially viable than [in] other areas." From January through August, solar and storage deals accounted for the bulk of contracts in the Southwest. There was also one onshore wind deal between Salt River Project and Pattern Energy Group LLC for 600 megawatts from the Sunzia Wind Project. In ERCOT and the PJM Interconnection, corporate buyers accounted for the majority of signed contracts. "There's just a lot in [ERCOT] that makes sense for corporate buyers in terms of the regulatory structure ... and just the sheer abundance of projects to pick from and the relatively approachable cost they can get with those PPAs," Wilson said. The strongest markets for corporate contracts are also the ones with the most data center growth, Paul Eory, director of utilities and corporates at Ascend Analytics, told Platts. "You're seeing ERCOT, the load growth, the asks are way beyond what is reasonably feasible," Eory said. "PJM has always been a hotbed and MISO is growing as well." Interest in PJM is more location-driven, with companies looking to procure energy in close proximity to major areas of operation, such as Northern Virginia and Ohio, Wilson said, pointing to nuclear power opportunities. From 2024 through August 2026, corporate buyers signed deals for over 7 GW of new and existing nuclear capacity in PJM, according to CERA data, including three Meta Platforms Inc. offtake agreements signed this year for a total of 3.8 GW of capacity. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/100126-path-to-net-zero-states-cut-back-on-renewable-goals-amid-affordability-concerns</link><description>This is the final in a multi-part series on net-zero efforts across industries. The previous article can be found here. As concerns about energy affordability grow, states are pulling back on their clean energy goals or reclassifying what qualifies as a clean energy resource. Connecticut scaled back its renewable portfolio standard targets in November 2025. Arizona officials are trying to repeal</description><title>PATH TO NET ZERO: States cut back on renewable goals amid affordability concerns</title><pubDate>01 October 2026 13:45:06 GMT</pubDate><author><name>Kassia Micek</name></author><content><![CDATA[ Electric Power, Energy Transition, Renewables October 01, 2026 PATH TO NET ZERO: States cut back on renewable goals amid affordability concerns By Kassia Micek Editor: Karina Roman Getting your Trinity Audio player ready... HIGHLIGHTS Arizonaâs REST repeal in limbo as AG pushes back Offshore wind delays threaten state goals This is the final in a multi-part series on net-zero efforts across industries. The previous article can be found here. As concerns about energy affordability grow, states are pulling back on their clean energy goals or reclassifying what qualifies as a clean energy resource. Connecticut scaled back its renewable portfolio standard targets in November 2025. Arizona officials are trying to repeal the state's renewable standard rules. North Dakota repealed its voluntary renewables goal after meeting it. New Jersey paused annual increases in the state's overall renewables target in 2025. Pennsylvania reintroduced legislation to replace its RPS requirement. "The repeals and the backtracking of the targets kind of started last year," said Monica Hlinka, senior principal analyst at S&amp;P Global Energy CERA. "Another trend that we were noticing is states that had the more ambitious RPS targets already on the books, are now expanding into stand-alone energy targets." Arizona repeal in limbo The Arizona Corp. Commission in March repealed the state's Renewable Energy Standard and Tariff (REST), which required utilities to generate 15% of their energy from renewable sources by 2025. Commissioners said the REST policy "served its purpose." However, Arizona Attorney General Kris Mayes (Democrat), who was a member of the commission in 2006 when it approved the rules, has challenged the repeal decision and has not yet finalized the rule change. Technically, the repeal is not codified into law until the attorney general publishes the rule change through the secretary of state. "Right now, it's still just in limbo," Hlinka said. "The attorney general is on the ballot this year. So, it might be another thing to wait and see since that could change." Two seats on the five-member commission, all currently held by Republicans, are up for a statewide vote in November, even though Commissioner Nick Myers finished third in a Republican primary in July. Two Republican candidates, including Commissioner Kevin Thompson, and two Democratic candidates will be on the ballot for the two seats. "We could possibly see some changes there, and that may impact the outcome," Hlinka said. If the results of the district board election in April for the Salt River Project (SRP) are any indication, a political-party change could be coming in Arizona. SRP, a Phoenix-area public power and water utility, is controlled by a board elected by landowners and experienced a historic shift in which pro-clean-energy candidates were elected to the board for the first time in years. The on-the-ground momentum from having Democrats elected to the SRP board could provide a push to get Democrats elected to the corporation commission, Hlinka said. "With the incumbent losing in the primary, we might see an upset," Hlinka said, adding that the commission had both Republican and Democratic members in the past. Arizona is one of the leading US states for solar and battery storage projects. Shayne Willette, a CERA senior research analyst, said the state is a market to keep an eye on as "significant levels of solar-plus-storage configurations are becoming increasingly common." Arizona ranks third in the US for total clean energy generating capacity, with nearly 16 gigawatts as of the end of the second quarter of 2026, according to S&amp;P Global Market Intelligence data. The state accounted for 14.3% of US clean energy additions in the second quarter, behind only New Mexico and Texas. Arizona added 1.7 GW of energy storage, second only to Texas; 504 megawatts of wind, the third-largest amount; and 389 MW of solar, the sixth-largest amount, according to the data. In total, Arizona ranks third in the country for energy storage, with 6.8 GW; fourth for solar, with 7.5 GW; and 21st for wind, with 1.7 GW. Trend of pauses, repeals emerging "Arizona kind of follows a trend we've been noticing in the past couple of years where states have now been repealing or putting a pause on their RPS standards or clean energy standards," Hlinka said. In Pennsylvania, legislation has been introduced several times in recent years, including during the current legislative session that ends Nov. 20, to replace the state's energy standard. Politics also plays into the mix, as the Senate has a Republican majority (27-23), while the House of Representatives has a Democratic majority (103-100), and the governor is a Democrat. "They just can't get anything done when it comes to passing any energy legislation or meaningful pieces of legislation altogether," Hlinka said. However, half the Senate, all 203 House seats and Governor Josh Shapiro are up for election this year. "Depending on the outcome of the election, it could either get reintroduced or just completely forgotten about," Hlinka said, referring to renewables repeal legislation. Pennsylvania ranks 31st in the US for total clean energy capacity, with 2.8 GW, according to Market Intelligence data. The state added 3 MW of solar in the second quarter. The PJM Interconnection footprint, which includes Pennsylvania, had the biggest year-over-year increase in solar generation output, at 29%, up to an average of 107.2 gigawatt-hours per day of solar output, according to PJM data. In neighboring New Jersey, the Board of Public Utilities reduced the state's RPS compliance level for 2026 and 2027, keeping it at 35% instead of raising it to 38% and 41%, respectively, according to CERA's report on renewable and clean energy targets and goals by state. While the 2028 target was set at 40%, that is still below the initial target of 44%. "They can't actually change the final end target in New Jersey," Hlinka said, adding that the final target is 52.5% by 2030. "It has to be done through the legislature, but they can kind of like massage the numbers a bit. ... They're holding it for the next two years. They're increasing it for 2028, but it's going to be at a much lower level than what it was initially." There is a separate proceeding looking at the remaining target years. "They're looking at other avenues that they can, because it all kind of comes down to the affordability aspect of it," Hlinka said. "That was one of the main reasons they were looking to freeze and pause their RPS standards." New Jersey ranks 37th in the US for total clean energy capacity with 1.5 GW, according to Market Intelligence data. The state added 37 MW of solar in the second quarter. Affordability is one of the main reasons behind clean energy policy changes in many states. "It's just way too high for ratepayers," Hlinka said. "And so, they're ... putting a pause on it." States coming short of goals States that enacted renewable or clean energy targets a decade or more ago are approaching their final target years, but, in some cases, are not near those goals. "It was really ambitious at the time and they were hopeful they were going to at least come close to it, but I don't think they were anticipating some of the changes at the federal level," Hlinka said. "I wouldn't be too surprised if a majority of them did not make their targets." Several Northeast and mid-Atlantic states had planned to rely on offshore wind resources as a major part of their renewables mix, but the Trump administration has delayed some projects and prompted others to be canceled. New York, for example, called for 9 GW of offshore wind by 2035 in its 2019 Climate Leadership and Community Protection Act. New York ranks 16th in the US for total clean energy capacity with about 6.7 GW, according to Market Intelligence data. The state added 16 MW of solar and 8 MW of storage in the second quarter. Two offshore wind projects are under construction and are due to be completed in 2027. Similarly, Maryland is nowhere close to reaching its goal of 100% clean energy by 2035. Its offshore wind target is 8.5 GW by 2031. "They were banking a lot of their renewable energy targets to be met with offshore wind, and there's just no way that they're going to make it without that generation source," Hlinka said. "So that's why they were looking at possible alternatives, and that's why they were looking to nuclear." Baltimore-based developer US Wind Inc. has the only remaining offshore wind project under development in Maryland. Constellation Energy Corp., the operator of the 1,800-MW, two-unit Calvert Cliffs Clean Energy Center nuclear plant, has expressed interest in expanding the facility. Maryland ranks 40th in the US for total clean energy capacity at about 1.5 GW, according to Market Intelligence data. The state added 4 MW of solar in the second quarter. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/093026-infographic-europe-enters-q4-under-cloud-of-high-gas-power-prices-supply-woes</link><description>European gas and power prices have risen to highs not seen since 2022, with the fourth quarter set to test markets amid low gas storage and continued LNG supply disruptions due to the war in the Middle East. For much of 2026, Europe has grappled with a tighter global LNG market; seven months into the Middle East conflict, those pressures are growing as winter looms. Analysts at S&amp;amp;P Global Energy</description><title>INFOGRAPHIC: Europe enters Q4 under cloud of high gas, power prices, supply woes</title><pubDate>30 September 2026 15:46:02 GMT</pubDate><author><name>Andreas Franke</name></author><content><![CDATA[ Electric Power, Coal, Natural Gas, LNG, Energy Transition, Thermal Coal, Carbon, Emissions September 30, 2026 INFOGRAPHIC: Europe enters Q4 under cloud of high gas, power prices, supply woes By Andreas Franke Editor: Alisdair Bowles Getting your Trinity Audio player ready... HIGHLIGHTS EU gas storage to reach only 74% by Nov 1 Wind volatility, low hydro to impact generation Carbon prices rally on compliance demand in Q3 European gas and power prices have risen to highs not seen since 2022, with the fourth quarter set to test markets amid low gas storage and continued LNG supply disruptions due to the war in the Middle East. For much of 2026, Europe has grappled with a tighter global LNG market; seven months into the Middle East conflict, those pressures are growing as winter looms. Analysts at S&amp;P Global Energy CERA project EU gas storage will be just 74% full by Nov. 1. In power, the focus is on volatile wind and reduced hydro stocks, while nuclear is forecast to be little changed year over year. Gas generation could see the largest year-over-year declines, despite limited potential for gas-to-coal/lignite switching following plant closures. European carbon prices, meanwhile, rallied through the third quarter, carried higher by robust compliance demand. Heading into the fourth quarter, EU Emissions Trading System trilogue negotiations emerged as the dominant policy flashpoint for the carbon market. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/refined-products/100226-interview-geopolitics-reframes-saf-as-strategic-asset-not-just-green-fuel-vopak</link><description>Geopolitical instability has recast sustainable aviation fuel as a strategic energy security asset, beyond being a clean fuel transition, but fragmented EU pipeline regulations are hampering supply chains, an official at storage firm Royal Vopak said. Higher conventional jet fuel prices driven by global instability have shifted the industry&amp;apos;s perception of SAF, elevating it from a green-transition</description><title>INTERVIEW: Geopolitics reframes SAF as strategic asset, not just green fuel: Vopak</title><pubDate>02 October 2026 14:53:26 GMT</pubDate><author><name>Thomas Washington</name></author><content><![CDATA[ Refined Products, Agriculture, Energy Transition, Jet Fuel, Biofuels, Renewables October 02, 2026 INTERVIEW: Geopolitics reframes SAF as strategic asset, not just green fuel: Vopak By Thomas Washington Editor: Ribhu Ranjan Getting your Trinity Audio player ready... HIGHLIGHTS EU traceability rules seen restricting Rotterdam-Schiphol flows Dutch HBE scheme drives localized voluntary SAF blending ReFuelEU review should tackle logistics bottlenecks Geopolitical instability has recast sustainable aviation fuel as a strategic energy security asset, beyond being a clean fuel transition, but fragmented EU pipeline regulations are hampering supply chains, an official at storage firm Royal Vopak said. Higher conventional jet fuel prices driven by global instability have shifted the industry's perception of SAF, elevating it from a green-transition instrument to a tool for national and regional fuel autonomy, Nikki Schutte, senior vice president for business development in the Netherlands at Vopak, told Platts, part of S&amp;P Global Energy, in an interview Oct. 2. "Geopolitical instability has driven conventional jet fuel prices higher and transformed the role of SAF," Schutte said. "It elevated energy security, shifting the view of SAF from purely a green fuel to a strategic asset for fuel security." Platts assessed jet fuel cargoes on a CIF basis in Northwest Europe at $1,603.5/metric ton Oct. 1, up 93% from Feb. 27, before the war in the Middle East upended jet fuel trade flows. Platts assessed SAF on an equivalent basis at $2,903.25/mt, up 27% over the same timeframe. The spread between jet and CIF has narrowed from 176% before the war to 81% Oct. 1, Platts data showed. While the end goal remains the broad adoption of clean fuels, the geopolitical landscape has accelerated the transition by framing SAF as a security tool rather than just a sustainability one, Schutte said. Global SAF demand is forecast to reach 80,000 barrels/day in 2027, up from 62,000 b/d in 2026, driven by higher demand in the UK and Asia, analysts at S&amp;P Global Energy Horizon said Sept. 7. Policy remains the main driver of SAF adoption, with uneven ambitions at the regional level, Ina Chirita, associate director, biofuels analytics at S&amp;P Global Energy, said on a webinar Sept. 30. "Although the Strait of Hormuz has created the incentives for more biofuels blending in general, we have not really seen this facilitating a higher adoption of SAF," Chirita said. Logistics bottleneck Despite strategic momentum, critical regulatory friction within European pipeline infrastructure risks undermining the scale-up, Schutte said. One issue is the Central Europe Pipeline System, or CEPS, the NATO-operated multi-connected pipeline network linking major fuel import hubs, including Rotterdam, to key aviation centres such as Amsterdam's Schiphol Airport. Differing interpretations across EU member states of how SAF deliveries into CEPS should be treated are creating a critical choke point. "Current European rules on traceability in multi-connected pipeline systems, such as NATO's Central Europe Pipeline System, restrict efficient transport from primary import hubs like Rotterdam to major aviation hubs like Schiphol," Schutte said. "Different member states interpret delivery into CEPS differently." Vopak advocates a book-and-claim approach within logistics networks as the most operationally and commercially effective solution. Under such a system, the sustainable attributes of a fuel â such as its carbon-reduction credentials â would be decoupled from the physical movement of molecules, allowing supply and demand to be matched administratively rather than requiring SAF to physically travel to each specific point of use. This approach would deliver three concrete benefits, she said. These are eliminating inefficient physical routing to hubs where SAF is available; enabling economies of scale by allowing blending in larger volumes at major hubs, thereby lowering overall transport costs; and streamlining accounting processes while preventing double-counting of sustainability credits. "To keep clean fuels affordable and flowing, regulatory rules need full harmonization within the EU and therewith acceptance of at least mass balancing across pipeline networks," Schutte said, adding that for CEPS entry specifically, this means "decoupling administrative traceability from physical molecule tracking." The ReFuelEU Aviation regulation requires SAF to account for 2% of aviation fuel supplied at EU airports from 2025, rising to 70% by 2050. Mandate momentum Despite the regulatory complexity, Vopak's own experience in the Netherlands points to strong underlying demand when the right incentives are in place. In 2025, driven by national incentive schemes known as HBEs â Hernieuwbare Brandstofeenheden, or Renewable Fuel Units â the Netherlands recorded voluntary SAF blending volumes that significantly exceeded the volumes required under the ReFuelEU mandate, Schutte said. The broader market will ultimately be mandate-driven, with voluntary uptake remaining a localized and secondary force, Schutte said. "Long-term regulatory stability is a non-negotiable prerequisite for developing physical supply chain infrastructure, and even more important to ensure producers and end-consumers will invest in the new SAF production technology. Shifting target lines creates market uncertainty that halts investment decisions right when infrastructure needs to scale," she said. The European Commission had made its decarbonization trajectory clear, and proposals such as the 2027 revision of the EU Emissions Trading System reaffirm that aviation decarbonization remains a top policy priority, she said. "While we recognize the gap between ambition and current production levels, the upcoming review of ReFuelEU Aviation should also focus on resolving logistical bottlenecks and setting realistic operational rules," Schutte said. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/100226-mexico-power-expansion-faces-execution-test-as-investors-warm-to-new-framework-panelists</link><description>Mexico&amp;apos;s power-sector challenge is shifting from policy to execution as developers embrace a more flexible framework for private investment, but warn that delivering the required generation will strain project, equipment and financing capacity. Mexico needs to add roughly 7 GW of generation annually to meet government targets, industry executives said Oct. 1 during S&amp;amp;P Global Energy&amp;apos;s 2026 Mexico</description><title>Mexico power expansion faces execution test as investors warm to new framework: panelists</title><pubDate>02 October 2026 17:27:34 GMT</pubDate><author><name>Sheky Espejo</name></author><content><![CDATA[ Energy Transition, Electric Power, Renewables October 02, 2026 Mexico power expansion faces execution test as investors warm to new framework: panelists By Sheky Espejo Editor: Giselle Rodriguez Getting your Trinity Audio player ready... HIGHLIGHTS Mexico targets 7 GW annual power capacity Developers praise flexible investment rules Energy storage remuneration lacks clarity Mexico's power-sector challenge is shifting from policy to execution as developers embrace a more flexible framework for private investment, but warn that delivering the required generation will strain project, equipment and financing capacity. Mexico needs to add roughly 7 GW of generation annually to meet government targets, industry executives said Oct. 1 during S&amp;P Global Energy's 2026 Mexico Market Briefing. "Mexico has to build roughly 7 GW per year," JosÃ© Luis GarcÃ­a, CEO of Yeltica Energy said. "Few countries have been able to execute that much in such a short period of time." The challenge extends beyond financing to equipment availability, port logistics, labor and the maturity of projects entering development. Many projects are still at a very early stage of development, GarcÃ­a said. "What concerns me is the availability of resources to execute." Developers welcome new framework Executives were broadly positive about recent procurement processes, saying they showed greater flexibility toward private investment. The processes have provided greater clarity around storage costs, corporate governance and other project conditions while showing an "interest in making conditions more flexible," said Saavi EnergÃ­a CEO Francisco Garza. Executives also pointed to greater alignment between government and developers as Mexico combines a central role for state utility CFE with private investment through mixed projects. "What excites me is that there are projects," Diana Sasse, an independent legal expert said. "There is alignment of interests rather than confrontation." Mexico will nevertheless need additional private investment beyond mixed projects, Garza said. "It is still necessary to trigger private projects and private PPAs," he said, noting that many large corporate consumers remain dependent on CFE. Storage remains unresolved Energy storage remains one of the outstanding issues as Mexico expands renewable generation. "We need to give greater visibility to storage and clarify how it is going to be remunerated," Garza said. The question is becoming more pressing as batteries increasingly provide an option for supporting grid reliability alongside solar and wind generation. "Batteries remove the stigma of intermittency," Sasse said, referring to one of the longstanding criticisms of renewable generation. "Work is being done to improve the offer of renewable energies into the system, and that is a positive step," she said. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/agriculture/100226-india-can-cut-saf-project-timelines-through-refinery-integration-replication-honeywell</link><description>India can accelerate sustainable aviation fuel supply by expanding refinery co-processing, standardizing plant designs, and ordering long-lead equipment before projects become trapped in lengthy development cycles, Ranjit Kulkarni, â&amp;#x80;&amp;#x8f;President - Africa, Honeywell Technologies, said Sept. 29 at the India SAF Conclave in New Delhi. HEFA technology has led early SAF deployment because oils and fats</description><title>India can cut SAF project timelines through refinery integration, replication: Honeywell</title><pubDate>02 October 2026 03:35:33 GMT</pubDate><author><name>Samyak Pandey</name></author><content><![CDATA[ Agriculture, Refined Products, Energy Transition, Metals &amp; Mining, Biofuels, Jet Fuel, Renewables, Hydrogen October 02, 2026 India can cut SAF project timelines through refinery integration, replication: Honeywell By Samyak Pandey Editor: Adithya Ram Getting your Trinity Audio player ready... HIGHLIGHTS HEFA technology leads early SAF deployment Refinery co-processing builds initial volumes India can accelerate sustainable aviation fuel supply by expanding refinery co-processing, standardizing plant designs, and ordering long-lead equipment before projects become trapped in lengthy development cycles, Ranjit Kulkarni, âPresident - Africa, Honeywell Technologies, said Sept. 29 at the India SAF Conclave in New Delhi. HEFA technology has led early SAF deployment because oils and fats are close to jet fuel in their physical and processing characteristics and can use established refinery and logistics infrastructure, Kulkarni said. However, HEFA should be regarded as the best available starting point, not necessarily the optimum long-term solution for India. The Honeywell executive pointed out that the country's ethanol and biomass resources could support ATJ and biocrude pathways, while renewable power could eventually create opportunities for power-to-liquids. Kulkarni said India's refineries could begin with limited quantities of renewable feedstock in hydroprocessing units and gradually expand by identifying metallurgical, catalyst, hydrogen, and operating constraints. Refinery integration would allow producers to build initial volumes without waiting for every standalone project to be completed. For greenfield plants, the schedule would directly influence project economics. Kulkarni contrasted the execution periods of around 20 months in China with timelines reaching five years elsewhere. Developers often lose time by expanding the project feedstock envelope in an attempt to eliminate every supply risk before FID, he said. A faster strategy would select a proven plant size, build the first unit, and then reproduce the configuration rather than redesigning every project. Government-supported insurance or risk-sharing arrangements could help inexperienced developers finance new technologies, particularly when project investment exceeds the sponsor's existing financial capacity. Kulkarni also identified agricultural residues, ethanol aggregation, and preprocessing as areas where India could combine global technologies with local feedstocks. Platts, part of S&amp;P Global Energy, assessed sustainable aviation fuel HEFA-SPK FOB Straits at $2,445/metric ton Oct. 1, up $15/mt from the previous week. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/091626-google-to-partner-with-terradot-in-brazil-methane-solutions</link><description>Google has announced its partnership with Terradot to deploy climate solutions at Brazilian rice farms, Google said on Sept. 16. Google&amp;apos;s purchase from Terradot, a carbon removal company specializing in Enhanced Rock Weathering, or ERW, will pair methane avoidance in Brazilian rice farming with carbon dioxide removal. The partnership aims to deliver &amp;quot;megatron-scale climate impact by 2030,&amp;quot; with</description><title>Google to partner with Terradot in Brazil methane solutions</title><pubDate>16 September 2026 19:40:10 GMT</pubDate><author><name>Alise Pruitt</name><name>Daniel Weeks</name></author><content><![CDATA[ Agriculture, Energy Transition, Carbon, Emissions, Rice September 16, 2026 Google to partner with Terradot in Brazil methane solutions By Alise Pruitt and Daniel Weeks Editor: Marieke Alsguth Getting your Trinity Audio player ready... HIGHLIGHTS Google purchases 1 million mt of CO2e Two technologies to be deployed in Brazil Partnership targets superpollutants, carbon removal Google has announced its partnership with Terradot to deploy climate solutions at Brazilian rice farms, Google said on Sept. 16. Google's purchase from Terradot, a carbon removal company specializing in Enhanced Rock Weathering, or ERW, will pair methane avoidance in Brazilian rice farming with carbon dioxide removal. The partnership aims to deliver "megatron-scale climate impact by 2030," with Google purchasing 1 million metric tons of CO2e of methane elimination by 2030 and 1 million mt of permanent carbon removal by 2040. The deal is the largest carbon removal purchase to date and the first project that combines "near-term methane elimination with durable carbon removal at this scale," the company said. Two technologies will be deployed on over 200,000 hectares of rice farms located in southern Brazil, targeting both superpollutant elimination and carbon removal. Terradot will aid farmers in adopting an irrigation technique known as Alternate Wetting and Drying to periodically drain flooded paddies, while also spreading naturally-sourced volcanic rock over the same fields. The rock will dissolve over time, removing CO2 from the atmosphere in a process known as ERW, according to Google. "We are pairing two proven technologies and deploying them together at a massive scale," James Kanoff, CEO of Terradot, said. "With this new model, every tonne of removal meets the same rigorous standard, and delivers climate impact faster than ever." Platts, part of S&amp;P Global Energy, assessed Methane Management Current Year prices stable on the day at $1.85/mtCO2e on Sept. 16. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/shipping/100126-interview-war-risk-insurance-costs-rise-as-sanctions-complicate-casualty-response</link><description>Shipping companies operating in contested waters are facing higher requirements for war coverage and legal complications, as attacks spread across multiple military conflicts and sanctions threaten to delay casualty response, according to Neil Roberts, head of marine and aviation at the Lloyd&amp;apos;s Market Association. The Joint War Committee of LMA, which represents insurers in the world&amp;apos;s largest</description><title>INTERVIEW: War-risk insurance costs rise as sanctions complicate casualty response</title><pubDate>01 October 2026 17:37:12 GMT</pubDate><author><name>Max Lin</name></author><content><![CDATA[ Crude Oil, Maritime &amp; Shipping, Refined Products, Chemicals, Energy Transition, Wet Freight, LPG, Hydrogen, Dry Freight October 01, 2026 INTERVIEW: War-risk insurance costs rise as sanctions complicate casualty response By Max Lin Editor: Giselle Rodriguez Getting your Trinity Audio player ready... HIGHLIGHTS Listed areas expand in Black Sea, Middle East Sanctions delay casualty response, worsen losses Nuclear propulsion faces liability framework gaps Shipping companies operating in contested waters are facing higher requirements for war coverage and legal complications, as attacks spread across multiple military conflicts and sanctions threaten to delay casualty response, according to Neil Roberts, head of marine and aviation at the Lloyd's Market Association. The Joint War Committee of LMA, which represents insurers in the world's largest marine market, has expanded the "listed areas" -- where they see heightened operational risks -- in the Black Sea, the Red Sea, the Persian Gulf, and the Arabian Sea this year. With a rising number of ship attacks in the Iran-US, Houthis-Saudi and Russia-Ukraine conflicts, Roberts, who chairs the committee, told Platts in a recent interview that the revisions to London market war-risk zones reflected a changing threat environment. "There have been quite a significant number of attacks that have fallen outside of the [earlier] listed area," said Roberts, referring to intensifying attacks of Russia and Ukraine on commercial ships linked to each other's trades before nearly all of the Black Sea was listed last month. Higher insurance expenses The move exposes a wider range of voyages to additional insurance procedures and costs, as marine insurers would charge additional war risk premiums in the high-risk waters. Higher insurance costs have ultimately affected the delivered cost of energy and commodity cargoes. The additional war risk premium (AWRP) for crude oil shipments from the Black Sea rose from $2 per barrel on July 17 to $3.7/b on July 29, the highest in recent years, before easing to $2.9/b on Sept. 30, according to Platts assessments. Platts is part of S&amp;P Global Energy. For shipowners and charterers, Roberts said one practical implication of listed-area changes is the need to communicate with insurers before entering designated locations. "If an area is listed and the vessel wishes to go there, yes, they should notify their underwriter," he said. "Otherwise, they won't have cover." The warning comes as vessel operators continue to navigate evolving risks in the Black Sea, Red Sea and Persian Gulf waters, where over 100 merchant ships have been attacked so after this year, based on estimates of International Maritime Organization, national governments and security consultancies. In the Middle East, tanker operators and charterers have faced a more than 40-fold increase in headline AWRP rates, calculated as a percentage of hull value, for transiting the Strait of Hormuz, while coverage periods have shortened amid rapidly evolving risks since the Iran war began in late February. The companies are also receiving fewer no-claim bonuses â which could amount to 50% in peace times â because of the severity of industry losses, according to Roberts. The International Union of Marine Insurance, the world's largest trade association representing marine insurance companies, recently estimated that insurers could have lost $2 billion in the Middle East war. Sanction complications Roberts also highlighted rising operational risks for the shipping industry as the number of sanctioned vessels grew, particularly complicating responses to marine casualties. Western governments had sanctioned a total of 1,226 oil tankers and LPG carriers as of Aug. 31, according to S&amp;P Global Energy Horizons data, and those ships -- mainly designated due to their links to Iranian or Russian trades -- regularly operated in conflict zones. In August, Omani authorities reported about 390 square kilometers of oil spilled from the sanctioned Suezmax Caroline Bezengi, which had been stranded after being damaged in an attack two months prior. "It wasn't insured at all, I don't think ... because of its designation," Roberts said. "It's the one we've been, the industry as a whole, predicting and now it's happened." When sanctioned parties are involved, responders will need government permits before conducting certain activities, potentially slowing salvage operations and pollution response efforts. "If there's a sanction involved, you need to get licenses before you can do anything, and that delay can make the loss worse," Roberts said. The problem has implications for shipowners, cargo owners and coastal authorities alike because delays can increase environmental damage, prolong shipping disruptions and raise overall costs. "You can't begin to deal with the sanctioned company until you've got the official permission to do it," he said. "You have to get the license first, which may or may not be given." Nuclear questions Beyond geopolitical risks, Roberts said shipowners pursuing decarbonization will also face evolving insurance and liability considerations. While much of the shipping industry's attention has focused on alternative fuels such as methanol, ammonia and hydrogen, insurers are also examining how future technologies could affect risk profiles and coverage requirements. Roberts said marine nuclear propulsion may eventually require changes to existing liability frameworks, with safety regulations for its adoption in commercial shipping yet to be fully developed. "As I understand it, there's a need for change in the liability regime," he said. "In insurance, there would be a need to look at our wordings, which almost all of them exclude nuclear." For ship operators evaluating long-term investment decisions, he said the challenge goes beyond fuel technology itself. "The main problem is the infrastructure," Roberts said. "If your vessel is powered by one of these new fuels, you are limited to where you can get supplies." US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/agriculture/092926-interview-saf-needs-feedstock-sandbox-more-eligibility-fathopes-ceo</link><description>The sustainable aviation fuel industry needs a regulatory testing framework that allows novel waste and residue feedstocks to be collected, characterized and commercially evaluated before determining their formal eligibilities, says Vinesh Sinha, founder and CEO of Malaysia-based renewable energy company FatHopes Energy. Without such a pathway, potentially useful materials may disappear from</description><title>INTERVIEW: SAF needs feedstock &amp;apos;sandbox,&amp;apos; more eligibility: FatHopes CEO</title><pubDate>29 September 2026 19:02:08 GMT</pubDate><author><name>Samyak Pandey</name></author><content><![CDATA[ Agriculture, Energy Transition, Biofuels, Renewables, Vegetable Oils September 29, 2026 INTERVIEW: SAF needs feedstock 'sandbox,' more eligibility: FatHopes CEO By Samyak Pandey Editor: Richard Rubin Getting your Trinity Audio player ready... HIGHLIGHTS Industry proposes sandbox for testing feedstocks Regulatory stability drives supply chain investment Existing operators lead near-term growth potential The sustainable aviation fuel industry needs a regulatory testing framework that allows novel waste and residue feedstocks to be collected, characterized and commercially evaluated before determining their formal eligibilities, says Vinesh Sinha, founder and CEO of Malaysia-based renewable energy company FatHopes Energy. Without such a pathway, potentially useful materials may disappear from supply chains before certification systems have enough information to assess them, Sinha said in a Sept. 28 interview with Platts, part of S&amp;P Global Energy. "The tragedy of discovering new materials is that if they do not find a commercially viable opportunity before certification or acceptance, they are going to die as a waste stream and will not become a feedstock for [sustainable aviation fuel," he said. FatHopes aggregates and converts SAF feedstock in Asia, while securing cross-border partnerships and supply pacts, with a focus on powering its upcoming 300,000 metric ton/year SAF refinery project in Port Klang, expected to be commissioned in mid-2030. The biofuels industry should create an incubation structure through which waste streams can be identified, tested and profiled without requiring an immediate eligibility decision, Sinha said. The resulting database would allow regulators, certification bodies and refiners to reassess materials as technology, economics and sustainability criteria evolve, he explained. "We are working toward a sandbox-type model where feedstocks can be presented, tested, evaluated and profiled," Sinha said. "The conclusion does not have to be whether they can or cannot be used. It is about creating a database, because perspectives and technologies may change." The central target should be to reduce lifecycle emissions rather than to prescribe a narrow set of raw materials or technologies, he added. Stability needed for investment Long-term regulatory consistency is critical because collectors, processors and project developers cannot commit capital without visibility over whether a feedstock will remain eligible, Sinha said. "If you do not have a stable framework, it is difficult for an organization to put significant investments behind building the supply chain," he said. Feedstock availability is not simply a question of theoretical volume, Sinha said: Waste materials must be identified, separated, collected repeatedly and delivered with consistent quality and documentation. New streams may initially exist in small, dispersed quantities, making dedicated collection uneconomic until demand assigns them value. "Fifteen years ago, UCO was worth about $80/metric ton," he said. "It is demand that increased the value." Other agricultural, industrial and household residues could follow the same progression, Sinha said. Once a material develops a reliable commercial outlet, collection can expand outward from areas where supply, processing and demand are already integrated. Waste and residue availability should also grow with population and economic activity because the materials originate from the human consumption footprint, he added. Technology broadens feedstock pool Refining technology has become capable of processing a wider range of feedstock qualities, while catalysts, pretreatment systems and operating practices have improved, Sinha said. However, producers must still understand each material's origin, quality and physical composition before determining whether it can be processed economically. Collaboration between suppliers, refiners and technology licensors will therefore remain important as plants expand their feedstock portfolios. Sinha said biofuels regulation has historically moved between two extremes: conventional materials that are easy to process but have weaker sustainability attributes, and highly constrained waste feedstocks that receive favorable policy treatment. This leaves insufficient room for byproducts and intermediate categories that may deliver useful emissions reductions but do not fit neatly into existing eligibility lists. "If we create a wider range within that middle ground, it gives greater optionality for investment," Sinha said. Prescriptive certification creates silos Current certification systems require an emerging material to be assigned to a recognized category before sufficient data may exist to classify it properly, according to Sinha. This can encourage suppliers to place new materials into the established category, offering the easiest route to commercialization, rather than assessing their environmental, social and economic characteristics independently, he said. A more flexible model, he added, would profile those attributes separately, allowing refiners and buyers to select materials suited to the markets they serve while maintaining supply-chain integrity. Different regional rules also separate feedstocks and finished fuels into market-specific certification silos, increasing operational requirements for traders and refiners, Sinha said. Additional certification routes provide commercial options, but companies must still select the destinations and systems offering the strongest economic returns. Asked which emerging feedstock could reach meaningful scale by 2030, Sinha declined to identify a single material, arguing that diversification was more important than making a concentrated bet. Existing operators and supply chains are likely to lead near-term growth because they already have collection, logistics, processing and market-access experience, he said. "I am not someone who would pick one material," Sinha said. "Diversifying the portfolio is key. Existing operators are best placed because keeping material in the market and circulating it is extremely important." US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/refined-products/092526-interview-repsols-cabra-sees-eu-rules-holding-back-saf-investment-beyond-2030</link><description>Europe&amp;apos;s sustainable aviation fuel market is on track to meet its 2030 blending targets, but fragmented regulation across feedstocks, processing technologies and end markets risks choking off the investment needed to hit more ambitious post-2030 goals, a senior Repsol executive said Sept. 24. The EU&amp;apos;s ReFuelEU Aviation regulation has provided a workable framework so far, with the 2025 SAF blending</description><title>INTERVIEW: Repsol&amp;apos;s Cabra sees EU rules holding back SAF investment beyond 2030</title><pubDate>25 September 2026 12:54:51 GMT</pubDate><author><name>Thomas Washington</name></author><content><![CDATA[ Agriculture, Energy Transition, Refined Products, Biofuels, Vegetable Oils, Renewables, Jet Fuel, Gasoline, Diesel-Gasoil September 25, 2026 INTERVIEW: Repsol's Cabra sees EU rules holding back SAF investment beyond 2030 By Thomas Washington Editor: James Leech Getting your Trinity Audio player ready... HIGHLIGHTS Europe's 6% SAF mandate for 2030 achievable Voluntary market accounts for up to 50% of Repsol SAF sales Refinery co-production key to competitive SAF economics Europe's sustainable aviation fuel market is on track to meet its 2030 blending targets, but fragmented regulation across feedstocks, processing technologies and end markets risks choking off the investment needed to hit more ambitious post-2030 goals, a senior Repsol executive said Sept. 24. The EU's ReFuelEU Aviation regulation has provided a workable framework so far, with the 2025 SAF blending obligation of 2% already exceeded at 2.8%. Luis Cabra, deputy CEO at Repsol and president of FuelsEurope, the European refining industry association, told Platts, part of S&amp;P Global Energy. The 6% target for 2030 was "at hand," but cautioned that the regulatory architecture governing renewable fuels needs reform to unlock the scale of capital spending required for the decade that follows, he said. "I believe that the positive is that we will be well served until 2030," Cabra said. "But if we look at the regulation, I see some barriers that need to be eliminated in order to confront successfully the 2035 indicative objectives," he said. Regulatory barriers There are three interlocking areas where European rules are impeding investment, Cabra said. These are feedstock eligibility, technology neutrality and market access for renewable fuels in road transport. On feedstocks, the Renewable Energy Directive imposed unnecessary restrictions on the range of inputs that refiners could use, he said, citing caps on used cooking oil as an example of rules designed to prevent fraud that instead constrained supply. "Let's try to control fraud, but do not unnecessarily restrict," he said. On technology, there are questions about the European Commission's emphasis on synthetic fuels at the expense of more commercially mature biofuel pathways, Cabra said. The cost of producing synthetic SAF, or eSAF, is currently five to ten times that of conventional jet fuel, making it unbankable at scale before 2030, he said. "Technology is not mature enough for synthetic fuels; technology is now quite mature for biofuels, and the cost is a factor of 2 or so," Cabra said. Platts, part of S&amp;P Global Energy, assessed SAF, produced via the hydroprocessed esters and fatty acids pathway, on a CIF basis in Northwest Europe, at $2,955.25/metric ton Sept. 24, 84% costlier than $1,607.75/mt for jet fuel cargoes on an equivalent basis. The spread between them is slightly below where it was when the Middle East war started on Feb. 28, since when it has caused tighter jet fuel markets. Analysts at S&amp;P Global Energy Horizons forecast the levelized cost of eSAF at $7,500/mt in 2026, falling to $6,200/mt in 2030. The third barrier is the effective exclusion of renewable fuels from road transport markets under EU vehicle emissions policy. Because refineries co-produce a range of fuels from the same feedstocks and processing units, restricting the market for renewable diesel and gasoline directly undermines the investment case for SAF production from the same facilities, Cabra said. "If I cannot co-produce gasoil for road or gasoline for road, I will have less investment cases for SAF," he said. European policymakers should treat renewable fuels as a single integrated value chain â covering feedstocks, processing and applications â rather than regulating each element in isolation through separate directives covering aviation, shipping, road transport and energy, he said. A leaked European Commission impact assessment report for the Renewable Energy Directive IV suggests a shift from rigid transport mandates toward domestic production, feedstock flexibility and resilience, analysts at S&amp;P Global Energy Horizons said Sept. 21. For biofuels markets, the shift is from imposing ambitious renewable fuels targets, the analysts said. Compliance and voluntary markets Repsol's own sales illustrate the current health of the voluntary SAF market, with between 25% and 50% of the company's SAF volumes sold outside mandatory blending obligations, depending on the season, Cabra said. He attributed this partly to airlines using free allowances from the EU Emissions Trading System to offset up to 50% or more of the SAF price premium, depending on the airport. At some island airports, such as those in the Balearic Islands, allowances could cover the full cost gap, he said. Airport infrastructure access is also a constraint on market development, with supply arrangements at some airports affecting pricing and competition, Cabra said. This is something that airports can develop and book-and-claim mechanisms â which allow SAF producers to sell volumes at the most logistically efficient location and transfer the environmental credit to buyers elsewhere â could also help address this, but require a clearer regulatory framework to function at scale, he said. On the role of conventional refining in SAF production, integrated refinery sites offered a structural cost advantage over greenfield SAF plants, given shared infrastructure for tankage, utilities and distribution, Cabra said. Repsol has increased jet fuel output at its Spanish refineries by 25% to 35% during recent periods of European supply tightness, and a healthy refining base is a prerequisite for competitive SAF supply, he said. "If we keep oil refining healthy, we will progress quite a lot and much better on renewable fuels supply," he said. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/shipping/092926-path-to-net-zero-shipping-companies-face-slow-low-carbon-bunker-transition</link><description>This is the sixth in a multi-part series on net-zero efforts across industries. The previous article can be found here. Major shipping companies have made progress in reducing the greenhouse gas emissions intensity of their operations but are struggling to achieve emission cuts in absolute terms. In their latest annual reports, the world&amp;apos;s top 10 maritime companies by market capitalization â&amp;#x80;&amp;#x94; all</description><title>PATH TO NET ZERO: Shipping companies face slow low-carbon bunker transition</title><pubDate>29 September 2026 13:30:29 GMT</pubDate><author><name>Max Lin</name></author><content><![CDATA[ Refined Products, Maritime &amp; Shipping, LNG, Energy Transition, Crude Oil, Chemicals, Agriculture, Fuel Oil, Emissions, Biofuels September 29, 2026 PATH TO NET ZERO: Shipping companies face slow low-carbon bunker transition By Max Lin Editor: Bill Montgomery Getting your Trinity Audio player ready... HIGHLIGHTS Intensity reduced, not total emissions Cost of green fuel much higher Cargo owners less willing to pay premiums This is the sixth in a multi-part series on net-zero efforts across industries. The previous article can be found here. Major shipping companies have made progress in reducing the greenhouse gas emissions intensity of their operations but are struggling to achieve emission cuts in absolute terms. In their latest annual reports, the world's top 10 maritime companies by market capitalization â all of which have some degree of net-zero targets by 2050 or earlier â reported long-term declines in GHGs per transport work but rising emissions overall in 2025. The development came as many ships were forced to take longer routes amid geopolitical conflicts and consumed more fuel, even as vessel operators were willing to invest in energy-efficiency measures that could yield healthy financial returns in a bullish oil market. "With longer distances, the emissions per ton-mile goes down, but the total emissions of course go up," Tore Longva, decarbonization director of classification society and maritime advisory DNV, told Platts, part of S&amp;P Global Energy. "A lot of the low-hanging energy efficiency measures are implemented ... but a 25% further energy efficiency improvement is [still] possible towards 2050. Ultimately, however, low-GHG fuels will be needed to reach net-zero." Longva and all other industry experts interviewed for this article responded by email. Green marine energy remains much more costly than conventional, oil-based fuels due to its limited availability. July's average delivered bunker price for 0.5%-sulfur fuel oil â the most popular marine fuel â was $18.66 per gigajoule in Singapore, compared with $20.05/GJ for LNG, $22.72/GJ for B24 bioblend, and $48.69/GJ for 100% sustainable methanol, according to the Platts Global Bunker Cost Calculator. Regulatory drivers To reduce the price gap, the European Union has, since 2024, extended its emissions trading system to cover shipping and introduced the FuelEU Maritime rules in 2025 to cap GHG bunker fuel intensity. The International Maritime Organization earlier approved the Net-Zero Framework, designed to place a cost on GHGs from ship operations globally from 2028. But its implementation is facing delays as fierce US opposition has prompted many of the UN agency's member states to discuss revisions. "IMO's [Net-Zero Framework] is critical for what happens next," said Tristan Smith, a professor at UCL Energy Institute in London. "Regional policy lacks the stringency to make a significant impact on shipping's energy transition. ... It is hard to see how it will enable any mass market participation in energy transition for the foreseeable future." Some in the shipping industry have echoed Smith's view. Wolfram Guntermann, director for regulatory affairs at German container line Hapag-Lloyd AG, one of the world's largest listed shipping firms, said the IMO framework is highly important because shipping is a cross-border industry that requires globally aligned regulations. "A common international fuel standard and emissions-pricing mechanism would provide greater investment certainty, support the scaling of low- and zero-emission fuels and reduce regulatory fragmentation," Guntermann said. Simon Bergulf, vice president for environment and climate at World Shipping Council, said the liner industry â represented by his organization â has invested $180 billion in ships capable of running on sustainable fuels such as bio-LNG and low-carbon methanol. "[But] global regulations for a global industry are necessary to make it possible for carriers to operate on green fuels at scale, and to incentivize fuel and energy providers to invest in new production capacity," Bergulf said. Voluntary demand Without sufficient global regulatory drivers, shipping companies have been seeking to provide sustainable freight services at higher prices in their pursuit of a financially viable energy transition. But demand on that front, often arising from cargo owners' voluntary decarbonization efforts, has been falling. A.P. MÃ¸ller-MÃ¦rsk A/S reported that its biofuel and green methanol use nearly halved to 1,524 GWh in 2025, from 3,034 GWh in 2024, reversing an upward trend in recent years. The world's largest listed shipping company cited lower voluntary demand as one of the reasons for the decline. In the latest annual Shipping Decarbonization Survey by Boston Consulting Group, the organization found that cargo owners, on average, were willing to pay a 3% premium to transport goods on ships running on green fuels in 2025, down from 4.5% in 2024 and the lowest since 2022. The share of cargo owners unwilling to pay any premiums increased by 4 percentage points in 2025, while those inclined to pay premiums of over 20% fell to zero from 3% in the prior year, according to the survey of 125 logistics executives. "Cost management has moved to the top of the agenda, while other priorities include energy security and resilience," Boston Consulting Group said. "Low-carbon shipping is increasingly deprioritized." Outlook for shipping sector Although long-term deep decarbonization requires large amounts of green fuels at affordable prices, major Japanese shipping firms Nippon Yusen Kabushiki Kaisha and Mitsui O.S.K. Lines Ltd. said they could achieve substantial GHG cuts through improved energy efficiency and use of currently available alternative fuels â such as LNG and biofuels â for the interim period. "We believe meaningful emissions reductions remain achievable through measures within our direct control, including energy-efficiency improvements, fleet modernization, retrofits and operational optimization," NYK told Platts in an email. MOL said the company's goal is to reduce emissions without relying "excessively" on uncertain regulatory developments or technological breakthroughs. "We are currently advancing decarbonization primarily through the use of LNG, while working toward a future transition to zero-emission fuels such as ammonia," the company said. Fotios Katsoulas, research director for alternative fuels at S&amp;P Global Energy Horizons, said shipping companies are likely to focus more on decarbonization means at hand if regulators continue to have difficulties implementing GHG rules. "Some moderation in the pace of transition is possible," Katsoulas said. "The most likely outcome is not a reversal of decarbonization targets but rather a slower transition pathway." Susan Dlin contributed to this article. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/092826-hcee-india-2026-india-europe-clean-energy-trade-hinges-on-reliability-infrastructure-delivered-costs</link><description>European countries are deepening clean energy partnerships with India, focusing on supply reliability, infrastructure readiness and delivered prices as they explore opportunities for renewable hydrogen and ammonia trade, while expanding technology cooperation. Industry and policy experts at the S&amp;amp;P Global Energy Horizons Clean Energy Expansion India Conference 2026 in New Delhi on Sept. 24-25</description><title>HCEE INDIA 2026: India-Europe clean energy trade hinges on reliability, infrastructure, delivered costs</title><pubDate>28 September 2026 05:12:17 GMT</pubDate><author><name>Ruchira Singh</name></author><content><![CDATA[ Energy Transition, Natural Gas, Chemicals, Metals &amp; Mining, Hydrogen, Renewables September 28, 2026 HCEE INDIA 2026: India-Europe clean energy trade hinges on reliability, infrastructure, delivered costs By Ruchira Singh Editor: Ankit Ajmera Getting your Trinity Audio player ready... HIGHLIGHTS Europe prioritizes trust in India energy trade Infrastructure readiness critical for supply Policy certainty needed for clean H2 trade European countries are deepening clean energy partnerships with India, focusing on supply reliability, infrastructure readiness and delivered prices as they explore opportunities for renewable hydrogen and ammonia trade, while expanding technology cooperation. Industry and policy experts at the S&amp;P Global Energy Horizons Clean Energy Expansion India Conference 2026 in New Delhi on Sept. 24-25 discussed the next steps needed to advance clean energy trade. "We concluded this partnership, which covers a wide range of areas that we were already working on -- trade and investment, energy and climate, health, agriculture, water management," Huib Mijnarends, deputy ambassador of the Netherlands to India, said in a fireside chat. "There is also a new element in it, and that is security ... [it is] broader than just green hydrogen, but we are talking about different ways of providing clean energy to the Netherlands and Europe." India and the Netherlands agreed in May to elevate relations to a strategic partnership and adopted the 2026-2030 roadmap, covering renewable energy, renewable hydrogen and an India-Netherlands green and digital sea corridor. The EU's revised Renewable Energy Directive requires at least 42% of hydrogen used in industry to be renewable by 2030. The EU has a non-binding target to produce 10 million metric tons/year of renewable hydrogen by that date, and import a further 10 million mt/y. Prioritizing trust Europe prioritizes production methods, trusted supply relationships and environmental standards alongside price, Hans-Joerg Hoertnagl, Austria's trade commissioner and commercial counselor to India, said during the fireside chat. "It is important to understand there is a major change going on in internal trade with the EU," Hoertnagl said, highlighting Austria's previous dependence on Russian gas. Hoertnagl said the continent imported the cheapest energy product, but "now we look at how it was manufactured," which involves considering "human rights" and "environmental standards." In addition, infrastructure readiness remains critical to establishing an India-Europe trade corridor, with adequate port capacity, storage facilities, logistics networks and shipping connectivity, industry experts said. European "buyers do not look at one specific thing -- they look at the complete value chain behind a molecule," Daljit Singh Kohli, India representative of Port of Antwerp-Bruges, said during a panel discussion at the event. Kohli said European buyers will evaluate suppliers' ability to reliably deliver the required volumes, the competitiveness of delivered prices in Europe and the robustness of supporting infrastructure. Platts, part of S&amp;P Global Energy, assessed the India renewable hydrogen term contract at $3.19/kg on Sept. 24, down 0.9% from a month earlier. Policy uncertainty a concern Michael Whiteley, global head of clean hydrogen and chemicals at HSBC, said uncertainty around European regulations and demand mandates cast a shadow over project financiers in the nascent clean energy market. He said the relevant H2Global tender required suppliers to deliver the product to a designated European terminal, while many Indian developers preferred to sell on an FOB basis, leaving shipping and logistics to another party. The Asia lot, part of Hintco's second H2Global supply-side auction, covers a 10-year contract for RFNBO-compliant renewable ammonia or methanol delivered to Northwest Europe, with an annual contract value capped at â¬58.7 million ($67.3 million) and total funding of up to â¬484 million over the contract term. Bids closed July 16. "There is some uncertainty now, and that is something that we cannot really deal with," Whiteley said during a panel discussion. "India has got really great potential for low-cost molecules, and Japan and the EU are looking likely for the import of those molecules. But how does it get to be? Where is the import infrastructure in the EU? And who is picking up for that?" Earlier in 2026, India's AM Green signed a long-term binding offtake agreement to supply up to 500,000 mt/y of renewable ammonia to Germany's Uniper, with the first shipments expected as early as 2028 from its Kakinada project in Andhra Pradesh. Technology supply, manufacturing India and the EU concluded negotiations on a free trade agreement on Jan. 27, creating a broader framework to expand trade, investment and industrial cooperation, including in sustainability. "Looking forward to the future, especially now with this free trade agreement, we see more potential," Hoertnagl said, adding that there is potential for more Austrian companies to establish factories in India in partnership. For instance, in Austria, most cement plants use alternative fuels produced from industrial and household waste. "That technology we want to offer to India," he said. Hoertnagl said Austria has a network of 300 to 400 small and medium-sized enterprises, including companies specializing in environmental technologies, that could find business opportunities in India. Austrian engineering group ANDRITZ operates two hydropower equipment manufacturing facilities in India through ANDRITZ Hydro Pvt. Ltd., located in Prithla, Haryana, and Mandideep, Madhya Pradesh. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/092826-hcee-india-2026-interview-reliance-to-start-renewable-hydrogen-output-in-2027-ramp-up-by-2028</link><description>Reliance Industries Ltd. expects to begin renewable hydrogen production at Jamnagar next year, ramping up to fulfill a commercial offtake deal by 2028, as the Indian conglomerate moves to anchor its new energy ambitions around a coastal production hub in Gujarat. Rahul T.R., vice president, strategy and planning, new energy at Reliance Industries, told Platts, a part of S&amp;amp;P Global Energy, the</description><title>HCEE INDIA 2026 INTERVIEW: Reliance to start renewable hydrogen output in 2027, ramp up by 2028</title><pubDate>28 September 2026 08:20:59 GMT</pubDate><author><name>Ruchira Singh</name></author><content><![CDATA[ Energy Transition, Hydrogen, Renewables September 28, 2026 HCEE INDIA 2026 INTERVIEW: Reliance to start renewable hydrogen output in 2027, ramp up by 2028 By Ruchira Singh Editor: Jim Levesque Getting your Trinity Audio player ready... HIGHLIGHTS Renewable H2 units planned at Jamnagar, Kandla Transmission infrastructure poses key delay risk Working toward $1/kg renewable H2 by 2031 vision Reliance Industries Ltd. expects to begin renewable hydrogen production at Jamnagar next year, ramping up to fulfill a commercial offtake deal by 2028, as the Indian conglomerate moves to anchor its new energy ambitions around a coastal production hub in Gujarat. Rahul T.R., vice president, strategy and planning, new energy at Reliance Industries, told Platts, a part of S&amp;P Global Energy, the company is targeting production in phases, driven by commitments under India's production-linked incentive (PLI) scheme and an around $3 billion Samsung C&amp;T offtake deal. Renewable hydrogen "production should start next year in Jamnagar, ramping up to meet the offtake by '28," Rahul said on the sidelines of S&amp;P Global Energy's Horizons Clean Energy Expansion India Conference 2026 in New Delhi on Sept. 24-25. "We have qualified for various PLIs by the Ministry of New and Renewable Energy. So, in line with those, we'll be commissioning our projects to keep up with all those commitments," he said. Rahul did not state the production volume, but Reliance Industries announced earlier that it aims to build a 3 million mt/year of renewable hydrogen production capacity at Jamnagar by 2035. The renewable energy generation will be in Kutch on about 500,000 acres, while the company plans to set up the renewable hydrogen/ammonia facilities in Jamnagar, Kandla, and other locations near the ports, he said. Reliance Green Hydrogen and Green Chemicals Ltd. won 138,000 mt/year renewable hydrogen production capacity under the government's Rupees 174.90 billion ($1.82 billion) Strategic Interventions for Green Hydrogen Transition scheme in 2024 and 2025, according to Solar Energy Corp. of India. Transmission hurdles Power transmission network infrastructure is the single biggest risk to the production timeline for renewable hydrogen, owing to the connectivity required with the producing zones, Rahul said. "Availability of transmission, be it captive -- that is, Reliance setting up its own transmission -- or set up by the central transmission utility, is one of the biggest challenges that we are seeing and trying to address," Rahul said. "It's the longest lead time also," he said. As per plan, renewable generation in Kutch will feed electrolyzers in Jamnagar and Kandla, near the coast, creating a physical distance that will require dedicated transmission infrastructure, he explained. He said the opening of transmission development to private parties through tariff-based competitive bidding, alongside a more commercially oriented Power Grid Corp of India, was helping accelerate build-out. However, he acknowledged that physically erecting towers, lines, and transformers remained time-consuming activities. The renewable hydrogen produced will be converted into renewable ammonia, with logistics handled via sea routes from nearby ports including Mundra and Kandla, he said. Use case captive, exports Reliance is pursuing both export and domestic offtake, though Rahul said no fixed ratio between the two has been determined, citing the volatility that has characterized the global hydrogen market since the COVID-19 pandemic, the Russia-Ukraine war, and more recent Middle East tensions. "This industry was sort of born at a time when there is a lot of volatility," Rahul said. "Export is looking at decarbonizing hard-to-abate sectors in Europe, Japan and [South] Korea," he said, noting they are "those kinds of places, where... demand fluctuates based on whatever is the geopolitical reality." On the domestic side, renewable hydrogen would partly replace conventional hydrogen in Reliance's Jamnagar refinery, contribute to renewable ammonia production, and potentially supply hydrogen mobility applications, Rahul said. The company targets net-zero carbon emissions in 2035. Reliance has licensed alkaline electrolyzer technology from Norwegian manufacturer Nel and is establishing a gigafactory in Baroda, Gujarat, to manufacture the units for deployment at Jamnagar, Rahul said. Reliance is in talks with European offtakers and believes its production model â using new renewable capacity, battery storage for time-matching, and India's grid â meets the additionality and temporal correlation requirements under the EU's Renewable Fuels of Non-Biological Origin framework, he said. $1/kg goal eyed On pricing, Rahul said that dynamics in renewable energy prices, battery storage, grid surcharges, and cross-subsidies are the factors that would influence renewable hydrogen costs in India. He pointed to the company's "1-1-1" vision â $1 per kg of renewable hydrogen within one decade â first announced by Chairman Mukesh Ambani at the 2021 annual general meeting, as the target the new energy team is working toward. "Our chairman's vision is $1 per kg of hydrogen in one decade," Rahul said. "I would still say we, as a team (at) new energy, still have about four to five years to achieve it," Rahul said. The 2031 deadline implied by that vision, Rahul said, remains "the North Star that we aspire to," adding that achieving it "is going to unlock a lot of opportunities for the industry." Platts, part of S&amp;P Global Energy, assessed the India renewable hydrogen term contract at $3.19/kg on Sept. 24, down 0.9% from a month earlier. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/sustainability-insights-our-take-on-new-york-climate-week-2026-strategic-shifts-build-resilience-s101709301</link><description>This report does not constitute a rating action. Adaptation and resilience emerged across New York Climate Week (NYCW) as vital to long-term value. This event drew over 100,000 participants to more than 1,000 climate-related sessions and coincided with the United Nations General Assembly (UNGA). At the UNGA, alongside talks on international security and AI, African nations called for two permanent Security Council seats. S&amp;amp;P Global Ratings believes Africaâ&amp;#x80;&amp;#x99;s strategic importance in climate disc</description><title>Sustainability Insights: Our Take On New York Climate Week 2026: Strategic Shifts Build Resilience</title><pubDate>01 October 2026 11:33:05 GMT</pubDate></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/new-york-climate-week-2026sustainability-growth-and-energy-security-are-no-longer-at-odds-s101710164</link><description>Climate Week, held on the sidelines of the UN General Assembly last week, united bankers, assetmanagers , investors , and multilateral banks. Front of mind was the deployment of climatetechnologies, especially for AI expansion and growth in emerging markets. So too was theimportance of understanding and accounting for rising physical risks, which are increasinglyaffecting the broader economy.</description><title>New York Climate Week 2026:Sustainability, Growth, And Energy Security Are No Longer At Odds</title><pubDate>01 October 2026 14:14:47 GMT</pubDate></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/how-private-credit-is-navigating-potential-ai-disruption-in-software-lending-s101708242</link><description>This report does not constitute a rating action. As technological advancement in AI--with the potential to disrupt the software industry--shows no signs of slowing down, investors continue to question how this will affect credit quality in private credit. In our view, the impact of AI disruption on software companies poses more of a threat over the medium term, particularly considering the rise in maturities in 2028 and after, and the risks vary across the sector. Earlier this year, capital mark</description><title>How Private Credit Is Navigating Potential AI Disruption In Software Lending</title><pubDate>29 September 2026 19:57:37 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/093026-european-gas-power-markets-enter-q4-under-cloud-of-high-prices-supply-concerns</link><description>European energy prices have risen to highs not seen since 2022, with the fourth quarter set to test markets amid low gas storage and continued LNG supply disruptions due to the war in the Middle East. For much of 2026, Europe has grappled with a tighter global LNG market; seven months into the Middle East conflict, those pressures are growing as winter looms. High prices and persistently</description><title>European gas, power markets enter Q4 under cloud of high prices, supply concerns</title><pubDate>30 September 2026 15:33:07 GMT</pubDate><author><name>Matt Hoisch</name><name>Andreas Franke</name><name>Eklavya Gupte</name></author><content><![CDATA[ Electric Power, Coal, Energy Transition, LNG, Natural Gas, Carbon, Renewables September 30, 2026 European gas, power markets enter Q4 under cloud of high prices, supply concerns By Matt Hoisch, Andreas Franke, and Eklavya Gupte Editor: Surbhi Prasad Getting your Trinity Audio player ready... HIGHLIGHTS Gas demand core uncertainty amid lagging storage El Nino could be key to gas, power demand in Q4 Gas-carbon link tightens as ETS reform risk looms European energy prices have risen to highs not seen since 2022, with the fourth quarter set to test markets amid low gas storage and continued LNG supply disruptions due to the war in the Middle East. For much of 2026, Europe has grappled with a tighter global LNG market; seven months into the Middle East conflict, those pressures are growing as winter looms. High prices and persistently backwardated forward curves have hampered gas stocking in many parts of the continent throughout the filling campaign. Analysts at S&amp;P Global Energy CERA now project the EU will enter the coming heating season with storage just 74% full on Nov. 1. This would be the lowest fill level at that point in records dating back to 2011, according to data from Gas Infrastructure Europe. The storage shortfall is linked to lagging EU LNG imports, which are trailing 2025 levels in the year to date, per CERA figures. However, CERA analysts forecast a pivot, with fourth-quarter European LNG imports projected to come in some 6.5% higher than those across Q4 2025, at roughly 491 million cubic meters/day. That would be among the highest levels in recent years, amid heightened competition with Asia for scarcer cargoes, they said. EU gas experts have repeatedly assessed that the continent's gas supply remains secure, most recently at a meeting on Sept. 24. Even if molecules are available, though, elevated prices remain a growing concern, with gas demand a core uncertainty in the months ahead. "The re-escalation of conflict in the Middle East and the resulting disruption to LNG tanker movements through the Strait of Hormuz have embedded a substantial risk premium across the European gas curve, while Europe's increasingly precarious storage position has reinforced concerns over winter supply adequacy," the CERA analysts said. Demand-side shifts could offer headroom. Indeed, the European Commission pushed in late September for member states to take measures to reduce gas and power demand, while also urging caution around moves targeting prices. Market watchers will be vigilant for any further policy interventions as temperatures decline. CERA analysts see gas demand across the EU and UK in the fourth quarter sliding 5.4% year over year to 1.233 billion cubic meters/day. The analysts highlighted a host of factors driving the expected decline in gas demand, including demand destruction amid elevated wholesale prices and a drop in gas-for-power usage on an annual basis over the coming quarter as increased renewables output and high costs temper Northwest Europe's gas dispatch. While a resolution to the war in the Middle East could exert rapid downward pressure on prices from the supply side, such a bearish shift is far from certain. "The balance of risks remains firmly skewed to the upside," the CERA analysts said. Focus on wind, nuclear, hydro For Europe's main power markets, CERA forecasts a 1% year-over-year increase in Q4 demand, assuming average temperatures. Demand so far this year is up about 3% as the hot summer and cold winter boosted consumption, but underlying structural demand only gained about 1%. "If 2026 has had echoes of 2022, it is worth remembering that forward power prices went into Winter-22 with a huge risk premium that dissipated at outturn, largely due to benign weather conditions and price-driven demand destruction. But as we have noted before, 2026 is not 2022," said Glenn Rickson, head of near-term power analytics at CERA, noting limited potential for demand destruction. On the supply side, wind and nuclear are set to lead the European winter mix. Assuming average wind speeds, Q4 wind output is forecast to rise 4 gigawatts year over year across the 10 major markets closely covered by CERA. Daily swings in wind supply are set to cause more volatility in spot markets, with more than 300 GW of wind now installed across the EU27 and the UK, but that can't negate the risk of Dunkelflaute episodes. Nuclear output is forecast to be unchanged year over year, just behind wind, with improved availability in Switzerland, Spain and the UK, balanced by reduced French reactor availability, with the new 1.6 GW Flamanville-3 reactor set to be offline until September 2027 for maintenance work and repairs. Belgium's last two 1-GW reactors are to resume operations from Nov. 2. Overall, French nuclear output is forecast to average about 45.5 GW in the fourth quarter, down just 1 GW year over year, according to CERA. The summer rally in gas prices lifted winter power prices to levels not seen in over three years, with Italian Q4 peaking above â¬200/megawatt-hour. Gas generation could see the largest year-over-year declines, despite limited potential for gas-to-coal/lignite switching following plant closures. Hydropower is also seen sharply lower in the core region, as well as across the Nordics and the Balkans. CERA analysts see "greater downside risk to demand in Q1 2027, balanced by El NiÃ±o risk of milder and possibly windier conditions weighted to Q4." Another uncertainty is the risk of market intervention and the impact of existing policy measures. Asked whether governments should intervene with more regulation, Marco Saalfrank, head of Merchant Trading at Axpo, made it clear that the market should be left to correct itself. "Regulation can potentially help, but only if it provides a clear overarching framework that still allows the market to function as a market," he said. ETS talks intensify Meanwhile, European carbon prices rallied through the third quarter, carried higher by surging gas prices and robust compliance demand. With the correlation between gas and carbon tightening, EU Allowances are increasingly trading in step with the broader energy complex, a dynamic that looks set to persist as the market enters a politically charged final quarter. Analysts at CERA expect EUAs to range between â¬82 and â¬86/metric tons of CO2 equivalent in the fourth quarter, with upside risk from "persistent high gas prices, colder low-wind weather and firm investor length" and downside risk from "a looser ETS reform outcome, easing geopolitical energy pressure" and "greater renewable output." Heading into the fourth quarter, EU Emissions Trading System trilogue negotiations have emerged as the dominant policy flashpoint for the carbon market, with sharply diverging institutional positions and intense industry lobbying set to drive allowance price volatility through year-end. The Alliance of Energy Intensive Industries demanded Parliament strip out conditionality entirely, warning it "causes new asymmetries" and undermines the financial capacity to decarbonize. Parliament rapporteur Peter Liese is pushing in the opposite direction, calling for stricter conditions than the Commission proposed and for 75% of ETS revenues to be reinvested in ETS sectors. Member state positions add further complexity: Poland called conditionality "illogical and counterproductive," Italy warned the timetable was unworkable, and France called for simplicity. A parallel dispute over the Market Stability Reserve â where the Council wants an 800 million allowance cancellation threshold from 2031 against Parliament's 650 million from 2027 â will shape future auction supply volumes. European leaders have committed to completing ETS reform by the first quarter of 2027. "More free allocation could reduce near-term industrial auction buying; tighter investment conditions could change plant decisions; MSR rules could alter future auction supply and market liquidity," CERA analysts said in a recent note. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/agriculture/093026-india-saf-scale-up-hinges-on-finance-feedstock-contracts-executives</link><description>India has sufficient feedstock resources, refining capabilities and conversion technologies to develop a large sustainable aviation fuel industry, but projects will struggle to secure financing without long-term blending targets, price-support mechanisms and bankable supply and offtake contracts, industry executives said at the India SAF Conclave in New Delhi from Sept. 28-29. Developers,</description><title>India SAF scale-up hinges on finance, feedstock contracts: executives</title><pubDate>30 September 2026 19:23:04 GMT</pubDate><author><name>Samyak Pandey</name></author><content><![CDATA[ Agriculture, Refined Products, Energy Transition, Biofuels, Jet Fuel, Renewables September 30, 2026 India SAF scale-up hinges on finance, feedstock contracts: executives By Samyak Pandey Editor: Juan Tolentino Getting your Trinity Audio player ready... HIGHLIGHTS Developers need long-term contracts to secure loans Multiple SAF technologies suit regional resources Modular plants cut transport and construction costs India has sufficient feedstock resources, refining capabilities and conversion technologies to develop a large sustainable aviation fuel industry, but projects will struggle to secure financing without long-term blending targets, price-support mechanisms and bankable supply and offtake contracts, industry executives said at the India SAF Conclave in New Delhi from Sept. 28-29. Developers, technology licensors and aviation representatives said the country's proposed blending trajectory of 1% in 2027, 2% in 2028 and 5% by 2030 provides an initial demand signal, but does not by itself distribute the risks associated with capital-intensive SAF projects. "The business and any commercial activity is all about how the risks are distributed and how stakeholders see their own benefits," Vibhav Agarwal, CEO of Essar Future Energy, said. Developers must evaluate SAF projects through the perspective of lenders, who will examine whether feedstock supply can be secured through long-term contracts, whether binding demand will exist, and whether airlines or fuel suppliers will sign durable offtake agreements, Agarwal said. Banks would also assess blending access, airport infrastructure and the long-term economics of projects before committing capital, he added. A two- or three-year blending trajectory is insufficient for investments intended to operate over several decades, according to Vibhav Agarwal, who called for visibility about how India's blending requirement could increase during the next 10-15 years. He urged the government to add SAF and other advanced biofuel facilities to its harmonized master list of infrastructure projects, thereby improving their access to long-term capital. Essar Future Energy is developing a greenfield complex intended to produce SAF, hydrotreated vegetable oil and other low-carbon fuels. Pathways to follow regional resources Speakers highlighted that India would require multiple technologies rather than a single nationally preferred SAF pathway. Ranjit Kulkarni, President of Honeywell Technologies Africa, said policy creates the market, mandates determine its size, technology responds to that demand, and finance controls the pace of deployment. HEFA and refinery co-processing provide the most immediate opportunities because oils and fats are comparatively close to conventional aviation fuel and can use much of the existing refining, logistics and fuel-handling system, he said. However, the most readily commercial option today would not necessarily be the optimum long-term solution. India's ethanol, biomass and renewable-energy resources could support alcohol-to-jet, biocrude and power-to-liquids pathways as those markets mature. Ranjit Kulkarni has previously said India's agricultural residues and ethanol ecosystem creates an advantage, but requires local aggregation, preprocessing and partnership models connecting farmers, aggregators and fuel producers. He compared construction schedules of around 20 months in China with development cycles that can reach five years elsewhere, saying the three-year difference could determine a project's internal rate of return. Distributed FT plants proposed Sachin Joshi, chief commercial officer of Velocys, identified biogas produced from agricultural, dairy and sugar-sector waste as a promising feedstock for Fischer-Tropsch SAF in India. Converting organic residues into biogas would allow projects to use established reforming, FT synthesis and fuel-upgrading processes while avoiding some of the syngas-quality challenges associated with direct biomass gasification, he said. Smaller modular plants could be located near feedstock rather than transporting dispersed biomass over long distances. The resulting liquid intermediate could then be aggregated more easily for centralized upgrading. Sachin Joshi pointed to the NovaSAF 1 project in Uruguay as a model that could be replicated in India. The project is designed to convert dairy biogas and renewable electricity into about 1,500 mt/year of SAF, with Trafigura identified as the offtaker. Velocys currently says the project is in development, with FID expected in 2026 and operations expected in 2028. Sachin Joshi said India could begin with about 5,000-10,000 mt/year modular FT facilities matched to local biogas output, then replicate the configuration as localization could further reduce construction times and costs. He said the industry was targeting FT-SAF production costs below $2,000/mt, rather than claiming that cost had already been achieved. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/093026-denmark-eases-hydrogen-pipeline-rules-to-derisk-producer-commitment</link><description>Denmark has overhauled key terms governing capacity bookings for its planned hydrogen pipeline backbone, easing financial commitments on producers and sharply increasing state operating support, in a move designed to unblock a project critical to connecting Danish green hydrogen output with German and broader European demand. The Danish Ministry of Climate, Energy and Utilities revised the</description><title>Denmark eases hydrogen pipeline rules to derisk producer commitment</title><pubDate>30 September 2026 13:30:47 GMT</pubDate><author><name>James Burgess</name></author><content><![CDATA[ Energy Transition, Electric Power, Hydrogen, Renewables September 30, 2026 Denmark eases hydrogen pipeline rules to derisk producer commitment By James Burgess Editor: Anoop Menon Getting your Trinity Audio player ready... HIGHLIGHTS State support raised to 16.5B Danish kroner Energinet extends capacity booking window Booking threshold cut to 100 MW from 500 MW Denmark has overhauled key terms governing capacity bookings for its planned hydrogen pipeline backbone, easing financial commitments on producers and sharply increasing state operating support, in a move designed to unblock a project critical to connecting Danish green hydrogen output with German and broader European demand. The Danish Ministry of Climate, Energy and Utilities revised the original deal on the country's hydrogen infrastructure after producers flagged heavy financial obligations ahead of a final investment decision on the pipeline. Under the revised terms, the initial 500 megawatt booking requirement as of Dec. 1, 2026, is retained, but bookings will no longer be binding at that stage. Producers now have until Nov. 1, 2027 â nearly a year longer than under the original schedule â to formally book capacity in the hydrogen pipeline. A binding guarantee of at least 100 MW must be in place by Dec. 31, 2027, for the project to proceed. The state's operating support for the hydrogen pipeline has been increased by 5.6 billion Danish kroner ($851 million), bringing the total to 16.5 billion kroner, Energinet said. State coverage of Energinet's potential stranded costs has also been raised from 417.4 million kroner to 2.1 billion kroner through Jan. 1, 2028, providing a financial buffer that allows Energinet to continue project development even as final booking certainty is pushed back. The agreement addresses concerns raised by the market, Energinet said in a statement on Sept. 29. Energinet said the project continues to target commissioning by end-2030, though it acknowledged that significant project activities remain outstanding and that financial estimates will be refined as milestones are achieved and tenders for critical components and construction work are completed. Producers will also retain the right to terminate their capacity contracts until Dec. 31, 2027, if project conditions no longer align with their individual circumstances. The postponement of the termination date remains subject to final approval from the Danish Utility Regulator, expected in early October. Denmark's hydrogen backbone is intended to serve as a physical link between domestic renewable hydrogen producers and industrial consumers and importers in Germany, Europe's largest anticipated hydrogen demand center. Delays or uncertainty in capacity commitments risked stalling investment decisions across the hydrogen supply chain, including projects seeking co-financing from the EU's Connecting Europe Facility. Energinet said it was working with Gasunie Deutschland to submit a joint application to the Connecting Europe Facility, which could help finance the project. Platts, part of S&amp;P Global Energy, assessed the cost of RFNBO-compliant hydrogen production via alkaline electrolysis in Germany, backed by renewable power purchase agreements, at â¬12.30/kg on Sept. 29. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/lng/093026-interview-asia-emerging-as-key-early-market-for-distributed-green-ammonia-power-says-amogy-ceo</link><description>Asian countries are emerging as key early markets for distributed green ammonia power, as rising electricity demand from AI, data centers, and industrial users is supporting the deployment of behind-the-meter clean power solutions, Amogy co-founder and CEO Seonghoon Woo told Platts, part of S&amp;amp;P Global Energy, in an interview. Such clean power solutions can serve local demand while reducing the</description><title>INTERVIEW: Asia emerging as key early market for distributed green ammonia power, says Amogy CEO</title><pubDate>30 September 2026 11:13:27 GMT</pubDate><author><name>Surabhi Sahu</name></author><content><![CDATA[ Energy Transition, Electric Power, LNG, Renewables, Hydrogen September 30, 2026 INTERVIEW: Asia emerging as key early market for distributed green ammonia power, says Amogy CEO By Surabhi Sahu Editor: Debiprasad Nayak Getting your Trinity Audio player ready... HIGHLIGHTS AI demand drives behind-the-meter solutions Likely transition from LNG to ammonia usage over time Geen ammonia to be more cost-competitive as demand ramps up Asian countries are emerging as key early markets for distributed green ammonia power, as rising electricity demand from AI, data centers, and industrial users is supporting the deployment of behind-the-meter clean power solutions, Amogy co-founder and CEO Seonghoon Woo told Platts, part of S&amp;P Global Energy, in an interview. Such clean power solutions can serve local demand while reducing the need for large-scale grid infrastructure such as transmission cables, Woo said. "We still have very limited hydrogen or ammonia-powered pilots running today...So, this is a very early market. But the direction towards these fuels is clear as decarbonization gains momentum," Woo said. According to a company presentation, the global clean ammonia market is projected to grow from less than 10 million metric tons per year in 2025 to about 100 million mt per year by 2040. Ammonia is supported by a robust global infrastructure, with nearly 200 ports currently handling and storing the commodity. Announced projects could boost the number of ammonia ports by roughly 50% by 2030, facilitating a clean-ammonia trade market expected to reach about 30 million mt/year, according to the report. "Right now, within APAC, we are concentrating our efforts on markets such as Singapore, South Korea, Japan, and Taiwan. However, we are also in discussions with many Thai players who want to follow," Woo said. In July, Amogy began construction in South Korea on a project targeting up to 40 MW of ammonia-based power over roughly the next three years, starting with a 1 MW phase and scaling up through 10 MW and 30 MW stages. The project is scheduled to enter the first phase of commercial operations in the second quarter next year, Woo shared. South Korea's industrial demand, including semiconductor-related power and emerging data center requirements, is creating opportunities for distributed power systems that use ammonia as a fuel source, Woo said. Amogy's partnership with Lotte Fine Chemical, announced in September, is another route to scale ammonia-based power and hydrogen supply in South Korea, Woo said. Lotte has an extensive position in ammonia imports and infrastructure in the country, including access to existing ammonia molecules that could be used to generate power or produce hydrogen for industrial applications, he said. Ulsan, where Lotte is based, is also becoming a focus area because of planned data center development and demand for decarbonized hydrogen in petrochemical and chemical manufacturing, he added. Woo said ammonia does not directly compete with LNG due to LNG's current cost advantage, but instead marks the next phase of fuel transition as Asian economies shift from coal- or gas-fired power to hydrogen-based generation. "LNG will transition to ammonia over time. I think that is the right way to put it because LNG still is a carbon-dense fuel," Woo said. In addition to South Korea, markets such as Singapore and Japan, which are also major LNG importers, are looking to use ammonia as a hydrogen carrier as they decarbonize power supply over the next 10â20 years, according to Woo. Singapore relies on LNG for about 95% of its power generation today, the country's Energy Market Authority said recently. According to an EMA statement in 2024, hydrogen has the potential to meet up to 50% of Singapore's projected electricity demand by 2050. Similar trends may be emerging in Japan, where gas-fired power infrastructure could gradually transition toward hydrogen firing supported by ammonia cracking technology, Woo added. In June, Amogy and KOWA Company, Ltd. announced a partnership to bring ammonia cracking-based hydrogen supply solutions in Japan's Chubu region, following the signing of an agreement in April. Earlier this year, Amogy and Hoku Infrastructure Partner announced an agreement to advance ammonia to power projects for data centers in Japan. Amogy is also extending the application of its technology to maritime shipping. However, the power generation market is more advanced for Amogy, Woo noted. Looking ahead Recent geopolitical tensions around the Middle East and the Strait of Hormuz have also sharpened energy security concerns among Asian LNG importers, reinforcing the case for more diversified fuel supply chains, Woo said. Green ammonia could be sourced from a broader range of suppliers, including India, China, Middle East and Australia, and blue ammonia could come from the US, he said. According to Woo, green ammonia is also becoming more cost-competitive with gray ammonia as production scales up and deployment accelerates across industries. Woo also highlighted that the emergence of competing developers of ammonia-cracking technology is a positive signal for the market. "This means that the market is growing bigger and bigger," he said. According to Woo, Amogy's advantage lies in the commercial maturity of its integrated ammonia cracking and power system, with its first Houston-built unit manufactured this year and operating continuously for several months, logging thousands of hours. Amogy's ability to integrate ammonia cracking with power generation at a commercial scale has helped it raise funding and secure strategic partnerships, even as other technology developers enter the market, Woo shared. "Meanwhile, we also want to see the geopolitical environment resolve and become more favorable for the development of the clean fuel," Woo said. "There are a few important events, including the IMO discussion...So, we are keen to see what happens there as well," he added. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/metals/093026-europes-scrap-demand-set-to-surge-as-new-eafs-loom-eurofer</link><description>Europe&amp;apos;s transition toward more electric steelmaking, with up to 20 electric arc furnaces expected to be commissioned in 2026-2030, adding 34 million-44 million metric tons of steel capacity, will increase the need for ferrous scrap, especially for high-quality material, the European Steel Association told Platts, part of S&amp;amp;P Global Energy. In 2025, the EU steel industry consumed 74.4 million mt</description><title>Europe&amp;apos;s scrap demand set to surge as new EAFs loom: Eurofer</title><pubDate>30 September 2026 12:39:46 GMT</pubDate><author><name>Katya Bouckley</name></author><content><![CDATA[ Metals &amp; Mining, Energy Transition, Ferrous, Renewables September 30, 2026 Europe's scrap demand set to surge as new EAFs loom: Eurofer By Katya Bouckley Editor: Jonathan Loades-Carter Getting your Trinity Audio player ready... HIGHLIGHTS 20 EAFs to add up to 44 mil mt of steel capacity EU scrap consumption reached 74.4 mil mt DRI projects total 26.9 mil mt/year of capacity Europe's transition toward more electric steelmaking, with up to 20 electric arc furnaces expected to be commissioned in 2026-2030, adding 34 million-44 million metric tons of steel capacity, will increase the need for ferrous scrap, especially for high-quality material, the European Steel Association told Platts, part of S&amp;P Global Energy. In 2025, the EU steel industry consumed 74.4 million mt of ferrous scrap. Its H1 2026 intake of 38.1 million mt has kept EU steel production and ferrous scrap utilization broadly in line with the first half of 2025, but Europe's accelerating transition toward more electric steelmaking will trigger a surge in the EU's steel scrap demand, according to Eurofer. Based on announcements by EU steel companies, 20 new EAF projects are expected to be commissioned between 2026 and 2030, representing 44.1 million mt/year of capacity. Of this, 33.8 million mt/year capacity is progressing; the remaining 10.3 million mt/year is delayed or suspended, said the steel body's head of communications, David French. The projects illustrate the scale of the potential transformation of European steelmaking, but their actual output will depend on market conditions and on whether individual investments proceed, French said. Also, these figures should not be interpreted as 44.1 million mt of additional annual scrap demand, he added â they represent steelmaking capacity, not actual production or scrap consumption. The transition will not depend on scrap alone. Eurofer is tracking 13 direct reduced iron projects planned for 2026-2030, representing 26.9 million mt/year of DRI capacity, of which 17.2 million mt/year is progressing and 9.7 million mt/year is stalled. There is also one electric smelting furnace project, representing 2.3 million mt/year of hot-metal capacity. This means Europe's future steelmaking system will use a combination of scrap and primary iron units, rather than simply replacing today's production with 100% scrap-based EAF output. But there won't be a uniform European scrap-to-DRI ratio: mixes will be plant-specific with EAFs operating on a spectrum ranging from near-100% scrap to 50:50, or even DRI/hot briquetted iron-dominant blends, French said. The ratio will be driven less by the EAF itself and more by scrap and DRI/HBI dynamics â such as quality, availability, and price â alongside product mix, utility and hydrogen costs, and carbon economics. Ultimately, the ratio will represent a balance between securing product quality and project profitability, according to Eurofer. Based on a 50:50 scrap-to-other-metallics ratio and the and an 80% utilization of the 33.8 million mt/year of EAF capacity that is being built, 27 million mt actual steel production will require 14.2 million-14.8 million mt of steel scrap and 14.2 million-15 million mt of DRI/HBI, with the results adjusted for the amount of feedstock lost during the melting process, given EAF operations' typical metallic yield of 90%-95%, according to Platts, part of S&amp;P Global Energy. Stanislav Zinchenko, CEO of Kyiv-based think tank GMK Center, said the EU's need to grow crude steel production by 12%-13% to counter falling imports triggered by steel safeguards and the Carbon Border Adjustment Mechanism, alongside the rollout of new EAFs, will require an additional 8 million-11 million mt of steel scrap. The European Commission is looking to reduce EU annual exports of steel scrap by 4 million-4.1 million mt, or 25%-26%, from 2025 levels. In its draft delegated act under the Waste Shipment Regulation, released Sept. 18, the commission proposes cutting off the majority of non-OECD countries from EU scrap metal supplies as of May 21, 2027. "We don't yet have an agreed position, but it is worth noting the following: 32 non-OECD countries applied [to the commission] to continue receiving EU waste; 24 applications covered metals, but only five were accepted," Eurofer's French said. "However, the majority of EU [ferrous metal] waste exports, around 72%, currently go to OECD destinations, and 64.4% of that OECD flow goes to Turkey. This wider picture matters when assessing how much scrap the European Commission's measure could actually retain within the EU and what effect it could have on the European scrap market." Platts assessed shredded scrap prices in Southern Europe at Platts at â¬325/mt ($369/mt) at the beginning of September; the monthly assessment increased by â¬10/mt, or 3%, since early January and is â¬15/mt, or 5%, higher year over year. On Sept. 29, Platts assessed the HBI price, including freight cost of delivery to a port in the Mediterranean region, at $396.50/mt CFR Mediterranean; the daily assessment gained 13% from the year-start point of $350/mt and is 25% higher than its $318/mt year-ago level. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/agriculture/093026-india-adds-biofuels-to-vehicle-efficiency-compliance-rules</link><description>India has formally incorporated ethanol, compressed biogas and other biofuels into its vehicle-efficiency compliance system, strengthening incentives for automakers to introduce flex-fuel and biofuel-compatible vehicles, according to a Sept. 29 government notice. The Ministry of Power has notified the Corporate Average Fuel Economy norms for fiscal years 2027-28 (April-March) through 2031-32,</description><title>India adds biofuels to vehicle efficiency compliance rules</title><pubDate>30 September 2026 08:31:36 GMT</pubDate><author><name>Samyak Pandey</name></author><content><![CDATA[ Agriculture, Refined Products, Natural Gas, Energy Transition, Biofuels, Gasoline, Diesel-Gasoil, Grains, Rice, Carbon September 30, 2026 India adds biofuels to vehicle efficiency compliance rules By Samyak Pandey Editor: Shashwat Pradhan Getting your Trinity Audio player ready... HIGHLIGHTS Biofuels gain CO2 compliance discounts Ethanol capacity exceeds E20 blending volume Automakers can trade efficiency credits India has formally incorporated ethanol, compressed biogas and other biofuels into its vehicle-efficiency compliance system, strengthening incentives for automakers to introduce flex-fuel and biofuel-compatible vehicles, according to a Sept. 29 government notice. The Ministry of Power has notified the Corporate Average Fuel Economy norms for fiscal years 2027-28 (April-March) through 2031-32, effective April 1, 2027, establishing carbon neutrality factors that reduce the emissions value assigned to vehicles operating on eligible biofuel blends, according to the notice. Vehicles using gasoline blended with 20% ethanol, or higher blends subsequently specified by the government, will receive an 8% carbon neutrality factor on declared tailpipe carbon dioxide emissions. The provision also covers strong hybrids and plug-in hybrids using ethanol-blended gasoline. The discount increases to 22.3% for flex-fuel ethanol vehicles, defined under the notification as vehicles capable of operating on gasoline-ethanol blends containing 85% ethanol (E85), and on 100% ethanol (E100). Flex-fuel vehicles also receive a 1.1 volume multiplier, or super-credit, when manufacturers calculate fleet-average compliance. Plug-in and strong-hybrid flex-fuel vehicles will receive a higher 2.5 multiplier, compared with 1.6 for conventional strong hybrids and 3 for battery-electric and range-extended electric vehicles, the power ministry said. CBG blending gains regulatory value For vehicles running on compressed natural gas, the carbon-neutrality factor will be either 5% or the compressed biogas blending percentage notified by the Ministry of Petroleum and Natural Gas, whichever is higher, according to the notice. The mechanism means that a future increase in the notified CBG blending share would increase the carbon-neutrality factor available to CNG vehicles, provided the notified percentage exceeds 5%. The framework does not, however, establish a new CBG blending mandate or specify a future blending rate. Diesel vehicles will similarly receive a carbon neutrality adjustment based on the actual biofuel blend specified by the petroleum ministry, the notice said. Post-E20 demand outlet The ethanol incentives arrive as India's production capacity has moved ahead of the required E20 blending volumes. According to a US Department of Agriculture report, India's annual ethanol production capacity increased from 6 billion liters in 2021 to 22 billion liters as of April 2026, while capacity utilization was forecast at only 51.5% for calendar year 2026. The report said grain-based sources supplied 73% of ethanol, led by corn at 46%, with damaged grains and government rice stocks contributing another 27%. That growing capacity has shifted the policy discussion from achieving E20 toward creating additional end-use markets. Flex-fuel vehicles are particularly important because they can consume E85 or E100, offering an outlet for significantly more ethanol per vehicle than the nationwide E20 pool. "The recognition of ethanol and flex-fuel vehicles through a 22.3% Carbon Neutrality Factor and 1.1x super-credit provides greater policy visibility to biofuels and gives automakers a clearer framework to plan for flex-fuel technologies. For the ethanol industry, this creates an enabling framework for the next phase of growth, while giving automakers greater clarity to plan and invest in flex-fuel technologies," Vijendra Singh, president, All India Distillers' Association, said. Earlier draft discussions had prompted the Indian Sugar &amp; Bio-Energy Manufacturers Association to seek a restoration of stronger flex-fuel incentives, including an increase in the volume multiplier from 1.1 to 1.5. The final notification retained the 1.1 multiplier, while confirming the 22.3% carbon neutrality factor. Platts, part of S&amp;P Global Energy, assessed Asian fuel ethanol up $8/cubic meter week over week at $681.67/cubic meter CIF Philippines on Sept. 28, amid stronger US ethanol futures. Ethanol futures fluctuated throughout the week, but remained above $2/gal over the September-November period. Ethanol futures for October hit $2.2/gal on Sept. 25, Platts data showed. Tradable compliance value The norms also introduce a credit-and-debit mechanism that gives direct economic value to fleet performance. According to the norms, manufacturers beating their annual average fuel-consumption target will generate credits, while those exceeding the target will record debits in individual compliance passbooks. Credits and debits can be carried forward within a compliance block, with the first block covering three years from 2027-28 and the second covering two years beginning in 2030-31. Unsettled credits expire at the end of each block. Automakers will be permitted to trade credits among themselves on mutually agreed terms. Manufacturers with remaining deficits can purchase credits from the Bureau of Energy Efficiency at prescribed prices rising from 2,500 rupees/gram CO2/km in fiscal 2027-28 to 4,500 rupees/gram CO2/km in fiscal 2031-32, the notice said. The credit framework, therefore, gives automakers a financial reason to consider biofuel-compatible models alongside electric vehicles, hybrids and conventional efficiency improvements when managing their fleet mix. The Ministry of Road Transport and Highways will develop and enforce testing, reporting and calculation methodologies, including those covering biofuel carbon neutrality factors and super-credits, according to the notice. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/agriculture/093026-aether-produces-astm-specification-saf-at-25-bd-integrated-demonstration-line</link><description>Sustainable fuel technology developer Aether Fuels has produced synthetic aviation fuel meeting ASTM D7566 specifications from waste-derived gases at a 2.5 barrel-per-day integrated demonstration line, providing technical validation for its planned 50 b/d Project Beacon facility in Singapore, the company said Sept. 29. The demonstration combined Aether&amp;apos;s Aurora Tri-Converter and Upgrader units</description><title>Aether produces ASTM-specification SAF at 2.5 b/d integrated demonstration line</title><pubDate>30 September 2026 01:37:51 GMT</pubDate><author><name>Samyak Pandey</name></author><content><![CDATA[ Agriculture, Energy Transition, Refined Products, Biofuels, Renewables, Carbon September 30, 2026 Aether produces ASTM-specification SAF at 2.5 b/d integrated demonstration line By Samyak Pandey Editor: Adithya Ram Getting your Trinity Audio player ready... HIGHLIGHTS Demo unit validates fuel specifications Singapore plant targets 2028 startup Sustainable fuel technology developer Aether Fuels has produced synthetic aviation fuel meeting ASTM D7566 specifications from waste-derived gases at a 2.5 barrel-per-day integrated demonstration line, providing technical validation for its planned 50 b/d Project Beacon facility in Singapore, the company said Sept. 29. The demonstration combined Aether's Aurora Tri-Converter and Upgrader units with an existing Fischer-Tropsch reactor operated by RTI International in North Carolina. The line completed the conversion of waste-derived gas feedstocks into fully upgraded synthetic jet fuel, according to Aether. The feedstocks comprised mass-balanced renewable natural gas derived from Kentucky landfill gas and captured industrial CO2. Aether said it believed the demonstration represented the first production in North America of ASTM-specification synthetic aviation fuel from those feedstocks at this scale. The samples from the demonstration met the applicable requirements for Fischer-Tropsch synthesized paraffinic kerosene under Annex A1 of ASTM D7566, the Aether statement said. FT-SPK meeting the specification may be blended with conventional kerosene at up to 50% without modifications to existing aircraft fuel tanks, pipelines, or airport fueling infrastructure. The result should provide operational data for the design of Project Beacon, Aether's planned commercial demonstration plant at Aster's integrated refining and chemical complex on Pulau Bukom, Singapore, the company said. Singapore scale-up planned Project Beacon is designed to produce up to 50 b/d, or around 2,000 mt/year, using industrial waste gas and biomethane, and construction is expected to start in 2026, with commercial operations targeted for 2028, Platts reported earlier. The project is expected to produce SAF with lifecycle greenhouse-gas emissions reductions of more than 70% compared with conventional fossil jet fuel, according to Aether. Aster is expected to provide renewable power, waste-carbon feedstock, utilities, and site support. Locating the plant within an established industrial complex is intended to support the transition from the smaller demonstration equipment toward continuous commercial operation. Downstream partnerships Aether and Singapore-based blending technology company FlyORO Technologies signed a nonbinding memorandum of understanding in May to explore blending, storage interfaces, certification workflows, logistics, and market delivery for Project Beacon and future facilities. FlyORO is evaluating the use of its modular AlphaLite system to provide flexible blending closer to production sites, terminals, or airports. The arrangement remains subject to further technical, commercial, and regulatory discussions. Aether also has an MOU with Singapore Airlines Group covering the potential procurement of neat SAF for five years after Aether's plants commence commercial production, with an option for a further five years. The agreements indicate prospective demand and downstream cooperation but are not equivalent to binding long-term purchases or confirmation that Project Beacon has reached commercial operation. Platts, part of S&amp;P Global Energy, assessed Sustainable Aviation Fuel HEFA-SPK FOB Straits, reflecting CORSIA-certified cargoes, at $2,420/metric ton Sept. 29, down $20/mt from Sept. 28. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/en/research-insights/special-reports/india-forward/reimagining-growth</link><description>India Forward: Reimagining Growth explores how India can move beyond consumption-led growth through domestic reform, infrastructure investment, capital market development and strategic execution to support its long-term economic ambitions.</description><title>India Forward: Reimagining Growth</title><pubDate>30 September 2026 09:00:00 GMT</pubDate><content><![CDATA[ Volume 5 â 30 September 2026 India Forward: Reimagining Growth In this edition Foreword Introduction Explore the Research Conclusion Sponsors &amp; Contributors About the India Research Chapter In this edition Foreword Introduction Explore the Research Conclusion Sponsors &amp; Contributors About the India Research Chapter India is recalibrating its growth strategy,â¯implementing reforms to strengthen resilience, unlock new opportunities and support long-term prosperity. As global markets contend with persistent inflationary pressures, challenging growth environments and fragmented supply chains, Indiaâs economic trajectory remains strong. In the fifth edition of India Forward, analysts from S&amp;P Global and Crisil examine how India is navigating geopolitical shifts, resource security initiatives and economic policy interventions toâ¯realizeâ¯its economic ambitions. Successful implementation of these initiatives and reforms will be critical forâ¯the countryâ¯as it deepens its integration with global trade, capitalâ¯marketsâ¯and energy flows. India has a significant opportunity to convert macroeconomic resilience into sustained economic momentum.â¯The countryâ¯can build on this momentum by advancing the next phase of physical infrastructure development, supported by competitive federalism, deeper capitalâ¯marketsâ¯and more robust financial intermediation. As Indiaâs physical infrastructure footprint expands, its growing digital infrastructure ecosystem will need toâ¯leverageâ¯the programmable capabilities of digital currencies and capital markets toâ¯optimizeâ¯capital efficiency and lower transaction costs. At the same time, advancing Indiaâs energy transition will require a unified storage strategy and a more integrated approach to building clean energy capacity. India Forward: Reimagining Growth demonstratesâ¯our enduring commitment to the Indian market. At S&amp;P Global and Crisil, our aim is forâ¯India Forwardâ¯to provide an essential roadâ¯map for unpacking India's evolution, and for understanding the critical commercial,â¯regulatoryâ¯and financial forces driving its future. Explore the research S&amp;P Global Ratings Yann Le Pallec President, S&amp;P Global Ratings Yann Le Pallec is President of S&amp;P Global Ratings and a member of S&amp;P Globalâs Executive Leadership Team. He has ultimate responsibility for all aspects of the business, including commercial, analytical, control and operations functions. He is based in Paris and heads the S&amp;P Global Ratings Operating Committee. Mr. Le Pallec chairs the Board of Crisil Ltd, a global provider of benchmarks and analytics for the financial community that also owns Crisil Ratings, a leading credit rating agency in India. Crisil Ltd is listed on BSE (formerly Bombay Stock Exchange). Previously, Mr. Le Pallec was the Executive Managing Director and Head of Global Ratings Services which oversees Analytics, Research, and Operations, encompassing more than 2,200 analysts and support staff across 28 countries who cover more than one million outstanding ratings on entities and securities across a range of sectors, including governments, corporations, financial institutions and structured finance. Since joining S&amp;P Global Ratings in 1999, Mr. Le Pallec has held a diverse array of roles, including Head of Global Corporate Ratings, leading a group of 500 analysts responsible for coverage of more than 4,000 non-financial corporations worldwide. Before that he led S&amp;P Globalâs credit ratings business in EMEA, managing a team of more than 900 ratings analysts and support staff across a dozen offices. Previously, he was Head of EMEA Corporate and Government Ratings, after serving in various managerial and analytical positions in the Insurance and Sovereign &amp; Public Sector groups. Mr. Le Pallec has also served as the Executive Sponsor for S&amp;P Globalâs PRIDE People Resource Group, which is dedicated to maintaining a supportive work environment for LGBTQ+ colleagues. Prior to joining S&amp;P Global, Mr. Le Pallec worked for nine years at Paris-based auditing and financial services firm Salustro Reydel. Mr. Le Pallec holds a master's degree in Business from the Ecole SupÃ©rieure des Sciences Economique et Commerciales (ESSEC) in France. Disclaimer: The views expressed in this journal are those of S&amp;P Global and Crisil and do notâ¯representâ¯the views of S&amp;P Global Ratings or any of its ratingâ¯committees.â¯ Introduction India's economic trajectory in the 2026-27 fiscal year is defined by a paradox: its remarkable domestic macroeconomic resilience, considering the increasingly volatile global environment. Unlike other major economies, India has beaten forecasts while contending with the same inflationary pressures, geopolitical conflicts and slower growth. In fiscal year 2025-26, despite high tariffs, the Indian economy expanded by 7.7% â more than 100 basis points above analysts' consensus. India's standout economic outlook does not imply that it is insulated. Its increasing integration into global trade, capital flows and energy mean that external shocks reverberate across its domestic systems. Whether due to disruptions at maritime chokepoints such as the Strait of Hormuz, the reallocation of global portfolio capital toward AI, or the complex balancing of domestic food security and renewable fuel mandates, the boundaries between geopolitical strategy, resource security and economic management are blurring. In India Forward: Reimagining Growth, analysts and experts from S&amp;P Global and Crisil examine the next phase of India's economic growth, its approach to managing global challenges and its strategies to navigate this environment. The articles underscore India's macroeconomic dynamics, recalibrated geopolitical approach, monetary innovation, capital market efficiency, traditional and alternative energy strategies, and power sector decarbonization. As India charts its path towardâ¯Viksit Bharat by 2047, the analysis in India Forward: Reimagining Growth considers ways to address India's structural, financial and logistical bottlenecks to achieve sustainable growth and development. India's macroeconomic momentum is strong, but there are friction points. According to Crisil and S&amp;P Global Market Intelligence, India entered fiscal year 2026-27 backed by structural buffers: foreign exchange reserves covering over nine months of imports, commercial banks reporting a decade-low gross nonperforming asset ratio of 1.8%, Crisil credit rating upgrade-to-downgrade ratios standing at a healthy 1.50x and central food grain stocks reaching 92.6 million tons. However, the war in the Middle East has inflated crude oil prices for India and, at the time of writing, India's rainfall is reported to be 14% below the long-term average, driven by El NiÃ±o conditions through late August. India also faces a conundrum in securing foreign capital: Net foreign portfolio inflows fell 16.6% in 2025-26, and while gross foreign direct investment hit $94.5 billion, net inflows compressed to $7.8 billion due to corporate outward investment and repatriation. To sustain the roughly 7.8% annual GDP growth required to achieve Viksit Bharat, India must lift total investment from 32% of GDP through revived private capital expenditure. This is most pertinent in emerging industrial sectors such as semiconductors, electric vehicles and defense, which are expected to capture up to 25%-27% of industrial investment over the next five years, from 12% in the previous five years. India's geopolitical strategy is evolving in response. Through cooperation with the US via the Initiative on Critical and Emerging Technology, pragmatic resource engagement with Russia and digital diplomacy exporting the India Stack across Latin America and Africa, India is converting global variation into national advantage. Although "competitive federalism" speaks of domestic reform in India, it is increasingly linked to foreign policy. The focus on data center expansion demonstrates how intranational competition to build digital and physical infrastructure directly fuels India's international bargaining power. According to S&amp;P Global Energy, India's data center expansion is forecast to surge from 1.5 gigawatts to 26.3 GW by 2031-32, with states such as Telangana, Maharashtra, Gujarat and Uttar Pradesh well positioned to support it. These strategies matter even more at a time of energy vulnerability. Indian refiners responded with agility to the effective closure of the Strait of Hormuz, which carried more than half of the country's crude imports, by pivoting to Russian supplies and opportunistic Atlantic Basin and Venezuelan purchases. For enduring resilience, however, India must focus on initiatives such as the $8.8 billionâ¯Samudra Manthanâ¯deepwater exploration. According to S&amp;P Global Energy, India must also consider an integrated electrons-to-molecules storage policy connecting strategic petroleum reserves (including Mangaluru's 1.75 million-ton facility) with grid-scale battery and pumped-hydro storage. This must be done alongside securing India's power transition. Electricity demand is forecast to grow 5.56% annually, compared with 2.47% for total energy, and S&amp;P Global Energy estimates that power will account for nearly 25% of the national energy basket by 2035. Meeting this demand requires adding 300 GW of solar photovoltaic capacity and 95 GW of storage. The primary challenge is not just clean capacity creation, but also its deliverability and grid security. Between April and June 2026, transmission constraints stranded over 6 terawatt-hours of solar generation, while grid inflexibility caused 3,300 gigawatt-hours of renewable curtailment in early 2026. The strategic imperative of supply chain sovereignty should be to transition away from fossil fuel imports while avoiding new dependencies on imported clean-technology components. India's energy transition underpins a fuel transition as well. India's E20 ethanol blending program is evolving from agricultural support into a strategic pillar. It has generated $22 billion in farmer income and saved over $25 billion in foreign exchange since 2014-15, but it faces bottlenecks. With grain-based ethanol surpassing molasses-based output, the diversion of corn is squeezing animal feed supplies, while domestic maize yields lag global averages. Beyond energy, achieving the next phase of growth requires evaluating India's financial levers. Retail adoption of the digital rupee has lagged the ubiquitous Unified Payments Interface (UPI), but evaluating the central bank digital currency by wallet counts misconstrues its purpose. India's digital rupee is a programmable settlement layer, representing the emerging fourth pillar of India's digital public infrastructure alongside Aadhaar, the UPI and account aggregators. A pilot study showed how embedded logic prevents subsidy leakage and credit diversion. In wholesale markets, atomic settlement promises to unlock liquidity across tokenized government securities and remove friction on India's $151 billion annual remittance flows. S&amp;P Dow Jones Indices also presents a decade of evidence from the SPIVA India Scorecard to evaluate Indian equity and bond markets. Despite the belief that emerging markets offer fertile ground for stock pickers, over 70% of actively managed Indian funds underperformed their respective benchmarks across all five tracked categories over the 10 years ended June 30, 2026. Through an analysis of the $2.03 trillion S&amp;P India BMI and the $1.26 trillion iBoxx ALBI India Index, it is evident that elevated market dispersion, such as the 40-percentage-point spread between sectors in early 2026, skews downside risk for fund selectors while survivorship bias masks fund liquidations (only 74.3% of funds survived the decade). In India Forward: Reimagining Growth, S&amp;P Global and Crisil analysts share their perspectives on how India's path to a $30 trillion economy by 2047 needs to expand beyond consumption and headline growth rates. India's next iteration of strategic autonomy calls for creative execution in emerging geographies while accelerating domestic reform. It will need to balance the physical realities of grid transmission, agricultural feedstock allocation and deepwater exploration while underscoring the value of programmable, digital currencies, deep capital markets and competitive state-level policies. To reimagine growth, India must develop a blueprint to convert external volatility into domestic capability. By Deepa Kumar, Gauri Jauhar, and Atul Arya, Ph.D. In this edition Conclusion The disruption to energy supplies through the Strait of Hormuz has been a severe test of energy security for high-growth Asia. India, which relies heavily on the Strait of Hormuz for oil, refined products, gas and adjacent supply chains,â¯has faced reductions in crude and LPG of 20% and 12%, respectively, as well as a drop in LNG of 16%.â¯Economic resilience and energy security are critical as India responds to this continuing supply shock. Indiaâs macroeconomic resilience throughout this disruption has been underpinned by an overall push for economic reforms, supported by public infrastructure investment, rapid digital infrastructure build-outs, and targeted incentives for manufacturing and welfare schemes. First-quarter GDP growth of 7.8% signals Indiaâs macroeconomic resilience and a pattern we have seen for several quarters. To sustain high growth and realize the vision of Viksit Bharat by 2047, India requiresâ¯a significant increase in the investment rate from the current level of about 32% of GDP.â¯ The countryâs focus on domestic energy will be sharpened to ensure all reforms target sturdy, secure supply chains that support the energy transition.â¯Indiaâ¯achievedâ¯its 2030â¯Nationally Determined Contributionâ¯target of 50% cumulative installed capacity from non-fossil sources ahead of schedule. The next stage of the energy transition will depend on the reliability andâ¯flexibility of the power system. A competitive power system will be core to competitive industry, services and agriculture. In transport, higher ethanol blending has helped to reduce the oil import bill.â¯The pursuit of energy diversity has been agile, with new routes and new sources of international supplies being explored.â¯ To secure long-term domestic oil and gas supplies, the Indian government has launched a major effort to de-risk upstream exploration via the Samudra Manthan initiative by 2031.â¯More broadly, storageâ¯across oil, gas, key refined products and battery storage has been elevated in urgency and importance for policymaking.â¯An integrated storage policy will signal Indiaâs move to greater energy security and deeper energy markets.â¯An electrons-to-molecules integrated approach will strengthen resilience across Indiaâs future energy value chain.â¯ Looking ahead, the priority is not only to withstand the current disruption, but also to build an energy system that gives India more choices, more flexibility and more resilience. That means greater domestic supply, diversified imports, reliable power, deeper storage and continued reforms all moving together. In a more disrupted world, this integrated approach will be central to India's growth and its path toward becoming an advanced economy by 2047. S&amp;P Global Energy Dave Ernsberger President, S&amp;P Global Energy Dave Ernsberger is President of S&amp;P Global Energy and a member of S&amp;P Globalâs Executive Leadership Team. Most recently, Mr. Ernsberger was Head of Market Reporting and Trading Solutions at S&amp;P Global Energy. In that role, he was responsible for managing Platts commodity price benchmarks worldwide, including market reporting, news coverage and exchange relationships, from well-established markets like oil and gas through to emerging market environments like new Energy Transition commodities and recycled materials. Prior to that, Mr. Ernsberger served in a variety of roles at Platts, including Head of Oil Content; Editorial Director for Asia (based in Singapore), and Houston Bureau Chief. He joined Platts in 1996 as a metals reporter in London, and launched coverage of Europeâs then-deregulating gas and electricity markets in 1999. A native of Boston, Massachusetts, Mr. Ernsberger holds a bachelor's degree in philosophy and politics from Warwick University, England, and a master's degree in international relations from Southampton University, England. The S&amp;P Global Institute The S&amp;P Global Institute is the center for enterprise-wide thought leadership that brings together expertise from across S&amp;P Global to provide insights on the trends reshaping markets, industries, and the global economy. Explore More Sponsors and Leads of the India Research Chapter S&amp;P Global Market Intelligence Head of India Leadership Council Abhishek Tomar Head of Kensho Data In his role, Abhishek leads S&amp;P Global's enterprise data strategy and transformation agenda, focused on building trusted, standardized and AI-ready data foundations that power innovation, operational excellence and business growth. He plays a critical role in enabling scalable data platforms, intelligent automation and responsible AI adoption across the enterprise, helping teams unlock greater value from data and accelerate decision-making. As a member of the Crisil Board, Abhishek brings deep expertise in enterprise data strategy, financial services, large-scale operations, AI enablement and business transformation. His perspective is particularly valuable as data, analytics and emerging technologies continue to reshape how organizations generate insights, manage risk and make decisions in increasingly dynamic markets. Abhishek brings more than 20 years of leadership experience spanning data, technology, operations and financial services. Prior to his current role, he served as Chief Data Officer for S&amp;P Global Market Intelligence and as Managing Director, India Operations, where he led a workforce of more than 8,000 employees and drove significant operational, talent and business outcomes. He was also a member of the Market Intelligence Operating Committee. Beyond his formal leadership responsibilities, Abhishek serves as a trusted advisor to senior leadership teams across India, Pakistan and the Philippines, helping shape regional strategy, strengthen collaboration and support long-term growth priorities. He is an active member of the National Executive Board of the American Chamber of Commerce in India. Abhishek holds a bachelor's degree in commerce from Delhi University and an MBA from NIILM Centre for Management Studies. S&amp;P Global Amish Mehta Managing Director and CEO, Crisil Amish Mehta is the Managing Director and CEO of CRISIL. In his current profile, Amish leads CRISIL's Indian and global businesses, steering its efforts to deliver high-quality analytics, opinions and solutions to corporations, investors, financial institutions, policy makers and governments. Amish joined CRISIL in October 2014 as President and Chief Financial Officer. In July 2017, he was appointed Chief Operating Officer, responsible for Global Analytical Center, India Research and SME, Global Innovation and Excellence (GIX) Hub and Corporate Strategy. As COO, Amish has led CRISILâs acquisitions and change agenda, and creating a growth path for the businesses managed. Prior to joining CRISIL, Amish was Chief Financial Officer for Indus Towers. He has rich experience of over two decades in telecommunications, oil and gas, FMCG and business advisory services, and has held leadership roles in diverse organisations, including BP/Castrol India, EY, and ExxonMobil India. He is a Chartered Accountant and holds a bachelorâs degree in Commerce. S&amp;P Global Energy Atul Arya, Ph.D. Senior Vice President and Chief Energy Strategist His areas of expertise include business strategy, commercial analysis, oil markets, energy technologies, climate change and renewables. He has previously led Energy Insight, Research and Analysis and Energy Research teams at S&amp;P Global (Now a part of S&amp;P Global). Dr. Atul previously worked for BP for over 20 years in a number of operational, business, technical and strategic positions around the world. His career includes international leadership experience in a diverse array of energy fields spanning strategy development, business planning, field operations and technology commercialization. His experience includes leadership in solar energy development as well as oil and gas. Dr. Atul has previously served on boards of several companies and institutions and is member of the World Economic Forum's Global Future Council on Advanced Energy Technologies and is 25+ year member of the Society of Petroleum Engineers. He is a sought-after speaker and moderator at public conferences, company boards and industry events and a member of the CERAWeek leadership team. He holds B.S., M.S. and Ph. D. degrees in engineering. S&amp;P Global Ratings Farhan Husain Global Group Head of Communications, S&amp;P Global Ratings, LGARC (Legal, Government Affairs, Risk &amp; Compliance), and Audit Farhan Husain is a global communications executive responsible for leading communications strategy for S&amp;P Global Ratings, LGARC (Legal, Government Affairs, Risk &amp; Compliance), and Audit. He serves as a member of the S&amp;P Global Ratings Operating Committee and is President of S&amp;P Globalâs Wellbeing London Chapter People Resource Group. With nearly two decades of experience advising senior executives and leading communications for global financial services organizations, Farhan is recognized for building high-performing teams, driving transformational change, and developing communications strategies that advance business growth, reputation, and stakeholder engagement. Most recently, Farhan led communications for S&amp;P Dow Jones Indices and played a key role in the successful spin-off and IPO of S&amp;P Global Mobility. Previously, he served as Global Group Head of Communications for S&amp;P Global Market Intelligence and the Enterprise Data Organization (EDO), where he established and scaled global communications teams supporting the companyâs data, insights, and software businesses. He also led communications for the acquisition and integration of IHS Markit, one of the largest and most strategically significant transactions in S&amp;P Globalâs history. Since joining S&amp;P Global in 2016, Farhan has held a series of leadership roles of increasing responsibility across the organization. He initially led external communications across the United States, Canada, and Latin America before being promoted to Global Head of External Communications for S&amp;P Global Market Intelligence. Earlier in his tenure, he helped launch S&amp;P Global Ratingsâ ESG Evaluation offering and played a leading role in establishing the communications strategy and global team supporting Sustainable1, S&amp;P Globalâs first ESG-focused commercial business. Prior to S&amp;P Global, Farhan held communications and marketing leadership positions at several leading financial institutions and market infrastructure organizations, including Ernst &amp; Young (EY), the International Securities Exchange (ISE/Nasdaq), and the New York Stock Exchange (NYSE). Throughout his career, Farhan has partnered closely with C-suite and business leaders to navigate complex business transformations, transactions, regulatory matters, and reputation management challenges. His expertise spans corporate affairs, executive communications, media relations, internal communications, change management, M&amp;A communications, thought leadership, and strategic stakeholder engagement. Farhan holds a Bachelorâs degree in Broadcast Journalism from Hofstra University. S&amp;P Global Nilam Patel Managing Director, India Operations S&amp;P Global Market Intelligence Deepa Kumar Director, Head of Asia-Pacific Country Risk and Co-Lead, India Research Chapter Deepa leads analysis on India and routinely spearheads and contributes to corporate-wide initiatives focused on India. Deepa has a background in Indian parliamentary research and was previously an entrepreneur whose organization in New Delhi focused on increasing citizen engagement with political representatives. S&amp;P Global Energy Gauri Jauhar Global Executive Director, Strategic Climate and Clean Energy Initiatives and CERAWeek Gauri is Executive Director, in Energy Transition and Clean Tech Global Consulting team, and a Certified Independent Director by the Institute of Directors (IOD). She has 23 years of experience in the energy, applied economics, finance fields, with wide regional experience in the United States, Kuala Lumpur, Singapore, Mumbai, New Delhi. Focus on ESG In the Energy Transitions and the integration of clean fuels in the energy spectrum and multi-sector mitigation strategies. Her areas of specialization are Integration of New Energy sources to the Energy spectrum for companies and countries, Financial and Operational Competitor Benchmarking, Energy pricing, Market entry strategies and Energy policy development. She represents S&amp;P Global in various industry bodies such as the US India Hydrogen &amp; Gas Task Forces by the US India Strategic Partnership Forum. Prior to joining S&amp;P Global, Gauri was Commercial Advisor - Gas Policy &amp; Regulatory Affairs at BP in India. She was the gas policy lead for a multi-disciplinary team-leading BP's energy reforms advocacy efforts in India. Prior to joining BP, she was a Senior Consultant at PFC Energy (now part of S&amp;P Global), leading PFC Energy's Integrated Energy business in India and Singapore. Gauri started her career as a Research Associate at the National Council of Applied Economic Research in New Delhi, analyzing macro-economic policy issues for the Indian economy and her paper with DK Joshi on "India's Macro-Stabilization Policy in 1990s: A Review and Assessment" was published in the book, "The Indian State in Transition." Contributors S&amp;P Global Energy Sanjai A. Associate Consultant, Strategic Climate and Clean Energy Initiatives Associate Consultant, Strategic Climate and Clean Energy Initiatives S&amp;P Global Energy Pulkit Agarwal Head of India Content Pulkit Agarwal is Hrad of India Content S&amp;P Global Energy Mohd. Sahil Ali Senior Research Principal, South Asia Power and Gas Sahil has over 13 years of experience spanning research, advisory, implementation support, and capacity building roles. At S&amp;P Global Energy, Sahil focusses on regional energy transition priorities, electrification for decarbonization, national-level carbon markets, competitive assessment and outlook for critical net zero-technologies such EVs, Green Hydrogen and CCS, and evaluation of national pledges for India and other South Asian markets. In the past, he has prominently contributed to several national and state policies and initiatives, engaged multilateral platforms such as World Bank, Global Green Growth Institute, and the Integrated Assessment Modelling Consortium; participated in India-US and India-EU joint climate research efforts, and conducted capacity building for energy modelling at the national and state levels with NITI Aayog. Prior to joining S&amp;P Global Energy, Sahil has worked as an associate fellow with the Brookings Institution India Center, where he led the efforts on energy scenarios, carbon pricing, and climate policy for India. He has also worked with the Center for Study of Science, Technology and Policy, Bengaluru, as a research scientist, and Willis Towers Watson, Gurgaon, as a research analyst. S&amp;P Global Energy Mansi Anand Analyst, National Oil Company Research - Upstream Companies and Transactions Mansi Anand in this role, she leverages her extensive expertise to assess and analyse the upstream and low-carbon strategies of national oil companies across Southeast Asia and South Asia. With over six years of experience in the energy sector, Mansi is adept at generating actionable insights that inform strategic decision-making. Mansiâs analytical skills and collaborative approach support her efforts in providing valuable insights that drive informed decision-making within the team and the broader energy sector. She earned her Bachelor of Science in Life Sciences from the University of Delhi, New Delhi, and holds an MBA in Energy Trading from the University of Petroleum and Energy Studies in Dehradun, India. S&amp;P Global Energy Atul Arya, Ph.D. Senior Vice President and Chief Energy Strategist His areas of expertise include business strategy, commercial analysis, oil markets, energy technologies, climate change and renewables. He has previously led Energy Insight, Research and Analysis and Energy Research teams at S&amp;P Global (Now a part of S&amp;P Global). Dr. Atul previously worked for BP for over 20 years in a number of operational, business, technical and strategic positions around the world. His career includes international leadership experience in a diverse array of energy fields spanning strategy development, business planning, field operations and technology commercialization. His experience includes leadership in solar energy development as well as oil and gas. Dr. Atul has previously served on boards of several companies and institutions and is member of the World Economic Forum's Global Future Council on Advanced Energy Technologies and is 25+ year member of the Society of Petroleum Engineers. He is a sought-after speaker and moderator at public conferences, company boards and industry events and a member of the CERAWeek leadership team. He holds B.S., M.S. and Ph. D. degrees in engineering. S&amp;P Global Ratings Geeta Chugh Managing Director, Sector Lead, Financial Institutions Ratings, SSEA S&amp;P Global Energy Swati Gautam Consultant, Strategic Climate and Clean Energy Initiatives Consultant, Strategic Climate and Clean Energy Initiatives S&amp;P Global Ratings Zahabia Gupta Managing Director, Head of Credit Research Emerging Markets S&amp;P Global Energy Gauri Jauhar Global Executive Director, Strategic Climate and Clean Energy Initiatives and CERAWeek Gauri is Executive Director, in Energy Transition and Clean Tech Global Consulting team, and a Certified Independent Director by the Institute of Directors (IOD). She has 23 years of experience in the energy, applied economics, finance fields, with wide regional experience in the United States, Kuala Lumpur, Singapore, Mumbai, New Delhi. Focus on ESG In the Energy Transitions and the integration of clean fuels in the energy spectrum and multi-sector mitigation strategies. Her areas of specialization are Integration of New Energy sources to the Energy spectrum for companies and countries, Financial and Operational Competitor Benchmarking, Energy pricing, Market entry strategies and Energy policy development. She represents S&amp;P Global in various industry bodies such as the US India Hydrogen &amp; Gas Task Forces by the US India Strategic Partnership Forum. Prior to joining S&amp;P Global, Gauri was Commercial Advisor - Gas Policy &amp; Regulatory Affairs at BP in India. She was the gas policy lead for a multi-disciplinary team-leading BP's energy reforms advocacy efforts in India. Prior to joining BP, she was a Senior Consultant at PFC Energy (now part of S&amp;P Global), leading PFC Energy's Integrated Energy business in India and Singapore. Gauri started her career as a Research Associate at the National Council of Applied Economic Research in New Delhi, analyzing macro-economic policy issues for the Indian economy and her paper with DK Joshi on "India's Macro-Stabilization Policy in 1990s: A Review and Assessment" was published in the book, "The Indian State in Transition." S&amp;P Global Energy Jessica Jin Senior Analyst, Solar Jessica is primarily responsible for tracking global production, capacity and shipments throughout the supply chain and providing insight and forecasts around the performance of the industry, as well as and the development of prices and margins. In addition,Ms. Jin continuously contributes to S&amp;P Global Energy's detailed coverage of downstream PV market development in China. She is based in Shanghai. Jessica continuously contributes to S&amp;P Global Energy's subscription services, but also provides regular support to custom research reports and consulting projects. Jessica's 12 years of experience as an analyst in the solar industry, having previously worked for more than three years at a specialist market research firm in China focusing on the solar PV supply chain. Jessica graduated from Anhui Polytechnic University with a Bachelor's degree in English. She is based in the company's Shanghai office. S&amp;P Global Dharmakirti Joshi Chief Economist, Crisil At CRISIL, Joshi's purview includes demand forecasting, assessing macroeconomic scenarios, and analyzing and monitoring the impact of macroeconomic domestic and external shocks on the economy. He has extensive experience in macroeconomic analysis and medium-term assessments of the Indian economy. He was member of the Working Group of Savings for the 12th Five Year Plan. He is also a member of the industry monitoring group of Reserve Bank of India. He was the Chairman of Economic Affairs Committee of Bombay Chamber of Commerce and is currently member of Economic Policy Group of Confederation of Indian Industry and Indian Merchant Chamber. He regularly writes for leading newspapers and expresses his views on the economy in the electronic media. Joshi has spent 26 years in economic research and consultancy. He spent 11 years at the National Council of Applied Economic Research (NCAER) before moving on to the Central Electricity Regulatory Commission (CERC), New Delhi, and then CRISIL. At NCAER, Joshi worked on short and medium term macroeconomic forecasting using Computable General Equilibrium and econometric models, macroeconomic reforms and fiscal policy related issues. At CERC, he worked on regulatory, competition and tariff related issues in the Indian power sector. Joshi holds a bachelors and Masters degree from Honours School in Economics, Punjab University, Chandigarh, India. He has attended program on Macroeconomic Policy and Management at Harvard University and was a visiting scholar to Economic Research Unit of University of Pennsylvania. S&amp;P Global Market Intelligence Deepa Kumar Director, Head of Asia-Pacific Country Risk and Co-Lead, India Research Chapter Deepa leads analysis on India and routinely spearheads and contributes to corporate-wide initiatives focused on India. Deepa has a background in Indian parliamentary research and was previously an entrepreneur whose organization in New Delhi focused on increasing citizen engagement with political representatives. S&amp;P Global Energy Rajeev Lala Director, Upstream Strategies and Transformation Rajeev Lala, Ph.D., serves as the Director of the Companies and Transactions group at S&amp;P Global Energy. With 14 years of experience in the energy sector and 17 years dedicated to studying energy geopolitics, Rajeev specializes in the analysis of National Oil Companies (NOCs) and leads a team focused on researching the upstream and low-carbon strategies of major NOCs worldwide. He earned his doctorate from the School of International Studies at Jawaharlal Nehru University in New Delhi, where he explored the politics of energy in EU-Central Asia relations, culminating in his thesis titled âThe Politics of Energy in European Union-Central Asia Relations, 1999-2010.â Additionally, he holds an MPhil in energy pipeline politics and an MA in International Relations. S&amp;P Dow Jones Indices Sue Lee APAC Head of Index Investment Strategy APAC Head of Index Investment Strategy S&amp;P Global Market Intelligence Hanna Luchnikava-Schorsch Head of Asia-Pacific Economics Ms. Hanna Luchnikava-Schorsch, Head of Asia-Pacific Economics, is the lead India economist with the Global Economics group at S&amp;P Global. Her research focuses on macroeconomic, financial and business developments in Asia, with particular emphasis on India. Among the issues she tracks are monetary and fiscal policies, financial and labor markets, as well as foreign trade and investment. She has prior experience in macroeconomic forecasting and market research gained with leading global institutions and firms, including the World Bank and McKinsey &amp; Company. Her university degrees include a Bachelor of Arts in International Relations from the Belarusian State University, Minsk, Belarus, and a master's degree in International Economics and Finance from the International Business School at Brandeis University, Waltham, Massachusetts, US. S&amp;P Global Energy Swati Mathur Associate Director, Agribusiness Consulting S&amp;P Global Market Intelligence Aiman Othman APAC Country Risk Analyst APAC Country Risk Analyst S&amp;P Global Energy Vedant Patil Principal Consultant, Energy Transitions and Cleantech Consulting Vedant Patil is Principal Consultant, Energy Transitions and Cleantech Consulting at S&amp;P Global Energy S&amp;P Global Energy Abhay Pratap Singh Senior Principal Analyst Senior Principal Analyst S&amp;P Global Energy Ashish Singla Director, South Asia Power and Renewable Research Ashish has more than a decade of experience in power sector covering South Asia, US, Canada, Mexico, Caribbean countries and Kenya. Ashish expertise includes economic and policy assessment, Power market designs, power and fuel market analysis, power market modeling, power trading, regulatory and commercial analysis, and environmental policy analysis. Prior to joining S&amp;P Global Energy , He worked with ICF Consulting India private limited where he led the 'Power and Renewable' practice covering South Asia region. Ashish has worked on numerous consulting assignments with IPPs, investors, private equity funds, Multi-lateral organization, power utilities, energy majors, industrial consumers, and government planning bodies to support their business, commercial and policy strategies. Ashish has led numerous techno-commercial and market due diligence assessments related to asset acquisition / sale / development and has authored papers/articles. Ashish holds Bachelor of Technology degree in 'Production and Industrial Engineering' from Indian Institute of Technology (IIT), Roorkee. Key support and contributions by: Brianne Paschen, Claire Wilson, Ellen White, William Lockwood, Shipra Singh, Pooja Nair, Rajat Juneja, Arnav Sarkar, Kurt Burger, and Camille McManus About the S&amp;P Global India Research Chapter The India Research Chapter brings together experts from across divisions and functions of S&amp;P Global and Crisil (an S&amp;P Global company) to focus on the opportunities, risks and potential that will shape Indiaâs future. It is a strategic initiative aimed at providing in-depth, timely insights and thought leadership into the complexities and dynamism of the Indian economy and its diverse sectors and industries. Explore more 2026 Key Themes India's Economic Landscape Balancing Energy Security &amp; Energy Transition Future of Capital Markets Digital Disruption &amp; Artificial Intelligence Geopolitical Scenarios Trade, Resources &amp; Supply Chains Agriculture Sustainability ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/blog/energy-transition/093026-et-highlights-brazil-irec-issuances-china-emissions-repsol-eu-saf-investment</link><description>Energy transition highlights: Our editors and analysts bring you the biggest stories from the industry this week, from renewables to storage to carbon prices.</description><title>ET Highlights: Brazil I-REC issuances hit record high, China targets emissions gaps, Repsol says EU rules hold back SAF investment</title><pubDate>29 September 2026 20:05:00 GMT</pubDate><author><name>Staff </name></author><content><![CDATA[ Energy Transition, Renewables, Emissions, Carbon September 30, 2026 ET Highlights: Brazil I-REC issuances hit record high, China targets emissions gaps, Repsol says EU rules hold back SAF investment Energy Transition Highlights: Our editors and analysts bring together the biggest stories in the industry this week, from renewables to storage to carbon prices. Top story Brazil I-REC issuances hit record high, up 7.7% in Jan-Aug 2026 Brazilian International Renewable Energy Certificates issuances have reached a record high of 69.7 million megawatt-hour from January through August, already surpassing the total issued in the entire previous year, according to the latest data from the I-TRACK Foundation. The figure indicates that the Brazilian I-REC market continues to grow steadily and is likely to reach a two-digit growth in 2026. In the first eight months of the year, issuances were 7.7% higher than the 64.7 million MWh issued in 2025, and by 23.5% from the corresponding January-August period. âThe market is evolving, from simply stating renewable energy consumption toward proven claims,â Isabel Arantes, strategic consultant at Instituto Totum, the Brazilian I-REC issuing body, told Platts Sept. 22. "Today, it is not enough to simply claim to consume renewable energy; it is necessary to demonstrate it through a structured, evidence-based process.â Issuances of hydroelectric I-RECs reached 35.2 million MWh in the period, compared with 35.7 million MWh for all of 2025. Hydropower represents most of the electricity generated in Brazil, having reached 51.2% of the total electricity supply in 2025, according to figures from the countryâs Ministry of Energy and Mines. But other renewable sources have expanded in recent years, reflected in an increase in I-REC issuances. Benchmark of the Week 16 cents/MWh Platts, part of S&amp;P Global Energy, assessed vintage 2026 hydro I-REC at 0.82 real/MWh (16 cents/MWh) on Sept. 25. Explore Platts Energy Transition Price Assessments Editor's Picks: Free and premium content SPGlobal.com/energy INTERVIEW: Repsol's Cabra sees EU rules holding back SAF investment beyond 2030 Europe's sustainable aviation fuel market is on track to meet its 2030 blending targets, but fragmented regulation across feedstocks, processing technologies and end markets risks choking off the investment needed to hit more ambitious post-2030 goals, a senior Repsol executive said Sept. 24. The EU's ReFuelEU Aviation regulation has provided a workable framework so far, with the 2025 SAF blending obligation of 2% already exceeded at 2.8% Repsol deputy CEO Luis Cabra, who is also of refining industry association FuelsEurope, told Platts. Europe must learn to live with energy system sabotage risk: experts Europe must learn to live with energy infrastructure attacks as the continent faces increasing physical and cyber sabotage threats from state actors and elsewhere, though renewables can aid system resilience, leading energy security experts said. The range of potential threats is now too broad and dispersed to be entirely avoided, so operators must adapt by building resilient infrastructure, Tatiana Mitrova, global fellow at Columbia University's Center on Global Energy Policy, told Platts in an interview. HCEE INDIA 2026 INTERVIEW: Reliance to start renewable hydrogen output in 2027, ramp up by 2028 Reliance Industries Ltd. expects to begin renewable hydrogen production at its Jamnagar hub in 2027, with output ramping up in phases to meet its commercial commitments, Rahul T.R., vice president, strategy and planning, new energy, told Platts, a part of S&amp;P Global Energy. Commissioning will be aligned with its obligations under India's production-linked incentive scheme and a roughly $3 billion offtake deal with Samsung C&amp;T, he added. Reliance aims to have a production capacity of 3 million mt/year of renewable hydrogen capacity by 2035. Indonesia maps grid strategy for hyperscale data center boom Indonesia is accelerating power infrastructure development to support a projected surge in AI and hyperscale data centers, with plans to expand national data center capacity nearly tenfold by 2029. Government officials and state utility PLN said grid readiness will be critical as connected power demand from data centers is expected to rise sharply through 2034. Authorities are developing coordinated policy and infrastructure measures to attract hyperscale investment while managing the impact on the electricity system. S&amp;P Global Energy Core China targets emissions measurement gaps to strengthen carbon market China has launched a review of carbon emissions measurement practices across key industrial sectors to improve the integrity and transparency of its national emissions trading system. The country's top market regulator and environment ministry said the investigation will address shortcomings in carbon measurement, recordkeeping and reporting by major emitters. The review covers sectors already included in the carbon market, including power, steel, cement and aluminum, with chemicals and other industries expected to join over time. New Zealand sets integrity criteria for voluntary nature and carbon markets New Zealand has introduced formal endorsement criteria for voluntary carbon and nature market schemes, aiming to boost private investment in environmental restoration projects. The framework creates pathways for recognizing both international and domestic crediting schemes, covering initiatives such as wetland restoration and native forest protection. Authorities said the criteria are designed to improve market credibility by ensuring credits are issued only after independent verification of measurable environmental outcomes. Industry urges EU to keep binding green hydrogen targets post-2030 A coalition of 170 energy companies has warned the European Commission that scrapping binding renewable hydrogen targets after 2030 would destroy investor confidence and waste more than half a decade of legislative and corporate effort. In a letter sent on Sept. 24 to Commission President Ursula von der Leyen, Executive Vice-President Teresa Ribera, and Energy Commissioner Dan JÃ¸rgensen, the companies called on Brussels to maintain the Renewable Energy Directive III transport and industry targets and mandates for Renewable Fuels of Non-Biological Origin hydrogen beyond 2030. Greece-based EmiCert emerges as world's first accredited CBAM emissions verifier EmiCert has become the first company in the world to receive accreditation to certify embedded carbon emissions under the EU's Carbon Border Adjustment Mechanism, the Athens-based environmental services company said Sept. 23, with its scope now covering all six CBAM-regulated sectors: iron and steel, aluminum, cement, fertilizers, electricity and hydrogen. The accreditation arrives at a critical moment. CBAM entered its definitive phase in January, requiring EU importers of covered goods to purchase and surrender certificates corresponding to the embedded emissions of their imports. ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/natural-gas/092426-interview-omans-oqt-eyes-lng-infrastructure-support-amid-trading-push</link><description>Oman&amp;apos;s OQ Trading (OQT) may invest in infrastructure to support new LNG and gas demand as the state-owned trading company pushes to expand its LNG efforts, OQT&amp;apos;s newly named global head of LNG told Platts in a recent interview. &amp;quot;For the right opportunities, we might be interested to look at co-investing in downstream facilities â&amp;#x80;&amp;#x94; call it FSRUs [floating storage and regasification units] or</description><title>INTERVIEW: Oman&amp;apos;s OQT eyes LNG infrastructure support amid trading push</title><pubDate>24 September 2026 14:23:20 GMT</pubDate><author><name>Matt Hoisch</name><name>Claudia Carpenter</name></author><content><![CDATA[ Energy Transition, Crude Oil, LNG, Natural Gas, Renewables September 24, 2026 INTERVIEW: Omanâs OQT eyes LNG infrastructure support amid trading push By Matt Hoisch and Claudia Carpenter Editor: Meghan Gordon Getting your Trinity Audio player ready... HIGHLIGHTS Newly named LNG head flags interest in FSRU co-investment Says gas has âlost a lot of credibility,â buyers to be discerning Sees portfolio âsweet spotâ of 4 million-5 million mt/ year Oman's OQ Trading (OQT) may invest in infrastructure to support new LNG and gas demand as the state-owned trading company pushes to expand its LNG efforts, OQT's newly named global head of LNG told Platts in a recent interview. "For the right opportunities, we might be interested to look at co-investing in downstream facilities â call it FSRUs [floating storage and regasification units] or potentially assets in the system where we can help support the demand creation and supply the demand from our own portfolio," EmmanuÃ«l Brasseur said Sept. 22. "In the developing countries entering the LNG market, I believe FSRUs will be the most cost-effective way to link up the LNG to the demand centers in a timely manner, so that is an option." Brasseur officially starts his new role in November, he said. The interest in supporting LNG penetration into new markets comes as the transit disruptions through the Strait of Hormuz due to the war in the Middle East prove headwinds to demand growth. The ongoing conflict has kept LNG prices elevated for much of the year. Platts, part of S&amp;P Global Energy, assessed the JKM benchmark for cargoes delivered into Northeast Asia at $26.114/million British thermal unit on Sept. 24. The index is 134% higher than the same time last year. "The gas market has lost a lot of credibility," Brasseur said. "Its abundance is there, but its ability to reach the market when it wants has been jeopardized by the closure of the Strait of Hormuz. I believe it opens a door for renewables to penetrate the market quicker than what was initially anticipated." Moving forward, LNG buyers will grow more discerning, Brasseur said. "There has been a tendency over the last 20 years to contract the cheapest molecule at all costs without thinking too much about the reliability of that supply," he said. "Buyers will [now] probably be more selective as to where they get their gas from and ensure a higher level of diversification." Expanding LNG efforts As he develops OQT's LNG business, Brasseur is eyeing a portfolio that can service an evolving market. Today, oil activities are OQT's core revenue generator, according to Brasseur. But, he explained, the company is keen to expand efforts around LNG. "There is a lot experience that has been acquired on the oil business that is transferable to the LNG market, and also the LNG market is commoditizing more and more," Brasseur said. OQT has been active in LNG for a decade and has built a trading platform, albeit still regionally, as a "relatively modest player," according to Brasseur. "It's a good basis to now think about the next phase of development where volume matters more," he said. While Brasseur declined to name a precise portfolio size he'll target, the incoming head described a "sweet spot" around 4-5 million metric tons/year. Diversity and flexibility are also priorities, he said, with cargoes probably sourced from some 3-4 projects. "We are not going to go for volume," he said. "We will focus on value as opposed to market share or volume." Sourcing in a growing market OQT is separate from Oman's state-backed LNG producer, Oman LNG. Nevertheless, it sources from Oman LNG's facility in Qalhat under a four-year, 750,000 mt/ year contract that Brasseur characterized as the "core" around which it will build its portfolio. "Ideally, OQT will grow its share of Omani offtake in the future, but we are going to be competing with the world for that," Brasseur said. Oman LNG is also eyeing an expansion, which could contribute to that growth, Brasseur added. "When and if [an expansion] happens, I hope that OQT can play a larger role in helping marketing or monetizing the assets," he said, stressing that his team would also look for growth from other suppliers. Last year, OQT inked a 15-year LNG sales and purchase agreement for 600,000 mt/ year from the proposed Amigo LNG project in Sonora, Mexico. Deliveries are expected to begin in 2028, according to a 2025 statement â though the facility, which is a joint venture between Epcilon LNG and Singapore-based LNG Alliance, still awaits a final investment decision. Looking ahead, Brasseur underscored a focus on spot and mid-term exposure. "We remain a trading company," he said. "Our role is where the market can really be hedged out, which is probably up to 5-6 years out." While Brasseur acknowledged near-term supply distress with the fighting in the Middle East, he sees this as temporary. Substantial further LNG volumes from a wave of new projects are set to hit the market in the coming years. Analysts with S&amp;P Global Energy CERA forecast global supply reaching some 635 million mt in 2030, up roughly 44% from 2025 levels. "This is clearly a market that is becoming more and more liquid," Brasseur said. "Accessing supply is not going to be an issue in the coming years," he said. "I think the key to success in this market will be to establish market share in developing markets where we believe we can add value." US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/en/research-insights/special-reports/india-forward/reimagining-growth/scaling-indias-e20-ambition-through-ecosystem-transformation</link><description>Is India&amp;apos;s fuel ecosystem ready for the next phase of the E20 journey? </description><title>Fueling options: Scaling India&amp;apos;s E20 ambition through ecosystem transformation</title><author><name>Swati Mathur</name><name>Abhay Pratap Singh</name></author><content><![CDATA[ 30 September 2026 Fueling options: Scaling India's E20 ambition through ecosystem transformation Is India's fuel ecosystem ready for the next phase of the E20 journey? By Swati Mathur and Abhay Pratap Singh This is a thought leadership report issued by S&amp;P Global. This report does not constitute a rating action, neither was it discussed by a rating committee. Highlights India's ethanol-blending program has emerged as a key energy security initiative, generating foreign exchange savings of more than $25 billion since ethanol supply year 2014-15 while reducing exposure to imported crude and global oil-price volatility. The focus may now shift from mandate-driven expansion toward coordinated development of the transportation fleet and fueling infrastructure. Feedstock sustainability, climate-related supply risks and agricultural productivity constraints must be addressed to ensure reliable and scalable supply growth to meet future ethanol demand. Gasoline demand is expected to continue growing, but ethanol will remain an important transition fuel. Long-term ethanol adoption will depend on consumer confidence, vehicle readiness and overall value proposition, as seen in the US and Brazil. In the wake of the Strait of Hormuz crisis, India's E20 program has advanced from a fuel-blending mandate into a broader energy security option. Its sustainable implementation will be shaped by ecosystem readiness and sustainable feedstock supplies while keeping pace with increasing demand. India imports about 88% of its crude oil needs and significant shares of other energy fuels. More than just a blending component, ethanol has delivered $22 billion in farmer income, reduced COâ emissions by 95.2 million metric tons, decreased crude oil imports and provided foreign exchange savings of more than $25 billion between ethanol supply year 2014-15 and May 2026. Achieving higher ethanol adoption through E20, E85 or E100 will require more than policy intent. Ethanol's evolving role in India's multifuel ecosystem Increasingly viewed as a multipurpose energy molecule, ethanol is expected to serve gasoline blending, sustainable aviation fuel and clean cooking. As demand increases, supply sustainability will require a sharper focus on feedstock supplies, feed and food markets, and the commercial viability of second-generation ethanol from agricultural residues and biomass. More recently, ethanol's use in clean cooking has been explored, but because it has a lower energy density than LPG, it requires larger fuel volumes and a dedicated distribution infrastructure to deliver comparable performance. A multifuel strategy for transportation, including conventional fuel, biofuel and electric vehicles, gives rise to gasoline demand scenarios with slight variations in gasoline consumption growth. S&amp;P Global analyzes gasoline demand scenarios based on the varying rate of EV penetration, economic growth and technology diffusion with improved infrastructure. In the base-case scenario, gasoline demand in India's transport sector continues to rise into the 2040s as economic growth, rising household incomes and continued urbanization drive increased passenger vehicle ownership. Despite increasing adoption of EVs, the expansion of the light-duty vehicle fleet and relatively low car ownership per capita compared with developed economies support ongoing growth in gasoline consumption. As mobility demand rises and more households enter the middle class, gasoline remains a key transport fuel for much of the outlook period. As mobility demand rises and more households enter the middle class, gasoline remains a key transport fuel for much of the outlook period. In the base-case scenario, a consistent increase is expected in gasoline-based cars, even with increasing EV penetration. Securing sustainable ethanol supplies long term: Fuel and food to the fore Although India has diversified its ethanol feedstock mix, feedstock sustainability is still an area of concern. In 2023-24, the government accelerated its ethanol blending but experienced weather-related production shocks. Sugarcane output fell significantly, and ethanol production was supported by corn plus rice allocated by the Food Corporation of India. Grain-based ethanol production surpassed molasses-based output for the first time in ethanol supply year 2024-25. Grain-based ethanol economics, supported by higher corn-based ethanol prices and a higher minimum support price for corn, encouraged expansion in corn acreage. However, the surge in production led to corn sales below the minimum support price, leaving ethanol producers profitable while squeezing farmersâ margins. Diverting more corn to ethanol is tightening availability for the animal feed sector, raising concerns about feedstock allocation and market sustainability. While the shift toward grain has facilitated year-round ethanol production, challenges remain, such as lower farm productivity, weather-related shocks for sugarcane, corn and rice, and logistical and structural challenges for feedstock procurement. Diverting more corn to ethanol is tightening availability for the animal feed sector, raising concerns about feedstock allocation and market sustainability. The vulnerability of feedstock supply highlighted by recent drought conditions underscores the urgent need to enhance farm productivity. Although maize has been increasingly used in ethanol production, its current yields of 3.6 metric tons per hectare are below the global average of 5-6 metric tons per hectare. As India sets higher ethanol blending targets, feedstock sustainability is a greater challenge than production capacity, requiring a balanced approach to agricultural productivity, climate resilience and resource allocation. E20: From policy ambition to consumer adoption India's E20 journey is at a crossroads, divided between a policy-driven objective and a nationwide consumer reality. The next phase of growth will depend on balancing feedstock sustainability and consumer acceptance to ensure that E20 delivers energy security and environmental benefits at scale. Some challenges need to be addressed for consumer adoption of E20 and higher blends of ethanol into gasoline. Vehicle compatibility: This has caused uncertainty, with concerns about reduced mileage and damage to engine parts. Pure ethanol has a higher octane number (~108.5 RON) than pure gasoline (~84.4 RON), providing superior anti-knock characteristics and supporting the operation of higher-compression engines. However, ethanol has a 35% lower calorific value (~29.7 MJ/kg) compared with gasoline (~46.4 MJ/kg), resulting in lower energy content per unit of fuel. While ethanol can enhance combustion quality and engine efficiency, its lower energy density may reduce volumetric fuel economy unless engines are specifically optimized for higher ethanol blends. Per the E20 road map, new vehicles must be materially compliant by 2023 and fully E20 compliant by 2025. According to some auto industry sources, there is no evidence of engine damage in non-E20-certified vehicles. The reported reduction in vehicle mileage associated with the use of E20 blended fuel can be mitigated through E20 calibrated vehicles. Ethanol-blended fuel requires material compatibility and robust infrastructure because it is hygroscopic, which poses a risk of phase separation in the fuel tank. According to the Indian Ministry of Petroleum and Natural Gas, E20 has been rolled out in consultation with the Society of Indian Automobile Manufacturers, the Automotive Research Association of India and key automobile manufacturers after extensive testing. A greater understanding of engine readiness and performance, especially for higher blend rates, will be required if ethanol is adopted by consumers in a sustained way. Clarity in cost benefit to consumer: The Indian government has addressed the fuel economy of using E20 and conventional gasoline by insulating the domestic fuel market from global crude oil price volatility. However, the lack of transparency regarding the cost structure and cost benefit to consumers negatively impacts fuel acceptance. Consumer choice: While ethanol-blended fuel is a strategic lever for enhancing energy security and achieving environmental objectives, the absence of clear pricing signals, ambiguity around vehicle compatibility and limited fuel choice at retail outlets raise concerns among consumers, particularly owners of older vehicles and those wanting to optimize cost and performance. The complexity of India's fuel distribution network means that providing multiple fuel choices at retail pump stations is challenging and requires investment in logistics, storage and supply chain segregation. Brazil and the US: Global benchmarks for ethanol blending A comparison with Brazil and the US reinforces the need for a consumer-aligned energy security solution, rather than a policy-led initiative, for faster implementation of India's E20 program. US and Brazilian government incentives and subsidies were critical in establishing production capacity, infrastructure and consumer adoption during the industry's formative years. Today, ethanol pricing in both countries is primarily market-based, although policy support remains through blending mandates and regulatory frameworks rather than the direct subsidies that characterized the industry's early development. Corresponding infrastructure at pump stations and vehicle fleet compatibility have been aligned with the blending options. The US has largely normalized E10 as a key fuel, with higher blends such as E15 and E85 available mainly for compatible vehicles and supported by a mature corn ethanol supply chain and credit mechanisms. Brazil operates the world's most advanced consumer-driven ethanol fuel market, with extensive flex-fuel adoption and direct competition between ethanol and gasoline at the pump. Use of higher-ethanol blends is widespread, with high flex-fuel vehicle penetration, and Brazil provides consumer choice between gasoline-ethanol blends of E25/E32 and hydrous ethanol, with pricing signals reflecting competitive fuel prices. Based on past years, hydrous ethanol price levels must remain at 70% compared with gasoline C (gasoline blended with 30%-32% anhydrous ethanol) for its consumption to be competitive. Brazil operates the world's most advanced consumer-driven ethanol fuel market, with extensive flex-fuel adoption and direct competition between ethanol and gasoline at the pump. Looking forward: Ethanol as a flex-fuel option in India India has made significant progress toward E20 adoption, but the next phase requires onboarded customers and a robust ethanol ecosystem. While policy support has accelerated blending, for long-term market success, consumers must view ethanol as a compelling choice. Continued collaboration among fuel suppliers, automakers, policymakers and consumers will be essential to address technical considerations related to higher-ethanol blends and build confidence in ethanol-powered mobility. As India moves from policy ambition to large-scale implementation, the initiative must be supported by four key pillars: a transparent pricing mechanism to preserve consumer value; alignment of policy implementation and vehicle fleet transition for using higher ethanol blends and phased flex-fuel vehicle deployment; expansion of multifuel retail infrastructure to accommodate consumer choice and to support higher ethanol blends; and uniform distribution of E20 gas stations across India to ensure nationwide accessibility. Robust fuel quality standards and sustainable feedstock inputs into production units will be important for successful implementation. By balancing energy security objectives with consumer choice, and market readiness with infrastructure preparedness, India can create a self-sustaining ethanol ecosystem that supports decarbonization while transforming the agriculture, mobility and energy sectors. ]]></content></item><item><link>https://www.spglobal.com/en/research-insights/special-reports/india-forward/reimagining-growth/indias-power-transition-renewable-scale-to-system-strength</link><description>By 2035, electricity will have to power a larger share of India&amp;apos;s growth, from factories and cities to cooling systems, mobility, data centers and green hydrogen. </description><title>India&amp;apos;s power transition: From renewable scale to system strength </title><author><name>Ashish Singla</name><name>Mohd. Sahil Ali</name><name>Jessica Jin</name></author><content><![CDATA[ September 30 2026 India's power transition: From renewable scale to system strength By 2035, electricity will have to power a larger share of India's growth, from factories and cities to cooling systems, mobility, data centers and green hydrogen. By Ashish Singla, Mohd. Sahil Ali, and Jessica Jin This is a thought leadership report issued by the S&amp;P Global Institute. This report does not constitute a rating action, neither was it discussed by a rating committee. Highlights India's power transition to 2035 is shifting from capacity addition to resilience. Rising electricity demand will make power central to India's growth and energy security. Renewables will dominate incremental supply, but the real test will be whether clean electricity can be delivered reliably, affordably and at scale. The main bottlenecks will move from generation build-out to system integration. Transmission delays, rising curtailment risk, limited storage, inflexible thermal operations and underdeveloped flexibility markets could prevent India from fully absorbing renewable capacity. Clean-technology supply chain localization will become a strategic investment theme. India has made progress in the downstream ecosystem, but gaps remain upstream and in critical minerals. These vulnerabilities create opportunities. By 2035, India's localization gap across the renewable ecosystem could unlock significant investment potential. The next phase of India's energy transition will be shaped by climate ambition and the need for resilience in an increasingly uncertain world. The Strait of Hormuz is a reminder of how external energy risks can sharpen the case for self-reliance. The key challenge for the power sector is to build a system that can deliver clean, reliable and affordable electricity at scale. By 2035, electricity will have to power a larger share of India's growth, so the generation mix, grid architecture and clean-technology base are central to India's energy transition. Renewable energy will remain the main source of incremental capacity, but its value will depend on the system built around it. Reduced dependence on imported fuels must not create new dependencies on imported components and minerals. India's transition to 2035 should be viewed as both a decarbonization pathway and a power-sector resilience strategy. When growth turns electric India's energy growth story is becoming more electric, with electricity demand expected to grow much faster than energy demand between 2025 and 2035, at 5.56% and 2.47%, respectively. Electricity's share in the total energy basket could rise to nearly 25% by 2035, from about 19% in 2025. This shift is already visible â electric vehicles are reducing fossil fuel use, for example â but the transition is broader. Industrial processes will change through greater use of electricity and green hydrogen-linked production, while industrialization, rising incomes, appliance ownership and cooling will expand conventional electricity consumption. New demand sources will add another layer of complexity. Data centers and green hydrogen production will become increasingly important, with their combined electricity demand potentially rising nearly ninefold to about 240 terawatt-hours by 2035. These loads are important because of their scale and because they demand reliability. Demand will also be served differently. The grid will remain central, but a growing share of electricity demand is expected to be met closer to consumers through distributed generation. This share could increase to about 16% by 2035, from about 13% in 2025. This creates both opportunity and pressure. India's power system must prepare for higher electricity consumption and more unpredictable demand. Meeting this demand reliably will require a diversified supply mix, stronger transmission and distribution networks, storage, and flexible generation and market design that can support a more dynamic electricity system. India's power system must prepare for higher electricity consumption and more unpredictable demand. Renewable scale-up: From capacity addition to system readiness India achieved its 2030 Nationally Determined Contribution target of 50% cumulative installed capacity from non-fossil sources ahead of schedule; the 2035 target is 60%. But early progress on capacity targets also changes the nature of the challenge. It is now moving from clean capacity creation to ensuring supply mix, reliability, flexibility and procurement. Coal will remain central to India's electricity supply, but its dominance is expected to decline. Continued utility-scale solar additions through 2035 are expected to reduce coal's share, potentially toward 60%, from 70% in 2025, S&amp;P Global forecasts. Beyond baseload, coal is likely to evolve into a flexible resource that supports evening peaks and low-renewable periods. Renewable energy will meet the majority of incremental electricity demand through 2035. Utility-scale solar will remain the main engine of supply growth, supported by wind, hydro and storage-backed renewable projects. S&amp;P Global expects India to add about 300 gigawatts of solar photovoltaic capacity between 2026 and 2035, plus roughly 95 GW of storage. The next phase of supply growth must pair renewable capacity with flexibility. S&amp;P Global expects India to add about 300 gigawatts of solar photovoltaic capacity between 2026 and 2035, plus roughly 95 GW of storage. Deep decarbonization technologies such as small module reactors and carbon capture and storage-based coal will gain strategic importance, although their contribution to the generation mix will be minimal over the next five to 10 years. The source of renewables demand will be another important shift. Apart from distribution companies, commercial and industrial (C&amp;I) consumers are expected to become a dominant force behind renewable capacity additions. S&amp;P Global estimates that the share of C&amp;I will increase to about 30% by 2035, from nearly 19% in 2025, making it an important force in shaping India's renewable supply pipeline. India's changing supply mix creates both momentum and risk. The momentum is visible in the growth of renewables, storage-backed projects and C&amp;I procurement. The risk is that supply growth outpaces the systems built to support it. The real measure of the transition will therefore shift from capacity installed to electricity delivered, balanced, economically absorbed and securely supplied. Making clean power deliverable, flexible and secure India's renewable build-out now faces three linked tests. Spatial: Can the grid move power from resource-rich regions to demand centers fast enough? Operational: Can the system balance a rising share of variable solar and wind without rising curtailment? Strategic: Can India build the ecosystem needed to scale clean power without creating new import dependencies? Unblocking India's transmission grid: Turning bottlenecks into build-out India's transmission network has been a quiet enabler of the power transition, but the next phase of renewable growth will test whether the grid can remain ahead of generation. The country has built a relatively strong national transmission backbone, and total transformation capacity was about 1,486 gigavolt-amperes as of July 2026. However, recent delivery trends point to emerging execution risks, and substation capacity additions have slowed. In fiscal year 2024-25, about 77% of targeted additions were achieved, compared with previous rates above 90%. Despite an improvement in fiscal year 2025-26, additions are below the pace required for the next phase of renewable integration. This signals a widening gap between transmission planning and on-the-ground delivery. This matters because renewable projects can be built faster than transmission corridors. As solar and wind capacity grow in resource-rich states such as Rajasthan, Gujarat, Karnataka and Andhra Pradesh, evacuation infrastructure must be ready before projects are commissioned. Transmission lags result in congestion, commissioning delays, stranded capacity and higher curtailment risk. The Indian Ministry of New and Renewable Energy said that more than 6 terawatt-hours of solar generation was not delivered to the grid between April and June 2026 because of delays in transmission development. The issue is less about the absence of planning and more about the speed and adaptability of execution. India has planned transmission around renewable resource zones and solar parks, but project development is increasingly dispersed and market-driven. Grid development must be planned in such a way that interstate corridors, intrastate networks and last-mile evacuation capacity are aligned with where renewable capacity is being built. Curtailment is the warning light: India needs flexibility before solar outruns the system Solar photovoltaic technology has led to an increase in India's renewable capacity in recent years. Significant additions were made in 2024 and 2025, and capacity growth should remain elevated in 2026. But as renewable penetration rises, curtailment risk emerges. During 2025 and the first six months of 2026, India's grid experienced renewable curtailment of about 2,800 gigawatt-hours and 3,300 GWh, respectively, with solar accounting for more than 85%. Transmission bottlenecks explain about 10% of curtailment, according to an S&amp;P Global Energy assessment, with the other 90% attributed to grid-security concerns linked to system inflexibility. The system may have insufficient flexible demand, storage or dispatchable capacity that can ramp down during daylight hours when solar PV generation is high. A comparison of low- and high-curtailment days in April 2026 illustrates how insufficient flexible generation support led to higher curtailment for solar PV (peak curtailment of 22 GW on April 5, versus 1 GW on April 17). The solution is to increase system flexibility. Thermal plants must operate at lower minimum levels and improve ramping capability, with suitable compensation for cycling and flexibility services. Storage additions must accelerate, with battery energy storage systems playing a role in short-duration balancing and evening peak shifting, and pumped storage supporting longer-duration flexibility. Market design must also evolve to reward flexibility. From fuel security to technology security As India's power system becomes more renewable-heavy, energy security will increasingly depend on domestic availability and manufacturing depth. Solar modules, cells, wafers, batteries, inverters, power electronics and critical minerals will become as strategically important to the power system as coal logistics and gas supply were previously. Trade protection, domestic-content rules and manufacturing incentives are reducing this risk. Basic customs duties have raised the cost of imported solar cells and modules, while the approved list of models and manufacturers (ALMM) requirements has created demand for approved domestic supply, and production-linked incentives have supported local manufacturing. As India's power system becomes more renewable-heavy, energy security will increasingly depend on domestic availability and manufacturing depth. Solar PV shows both progress and vulnerability. Module capacity is no longer the main constraint; the deeper vulnerabilities lie upstream in cells, wafers, ingots and polysilicon. The implementation of ALMM List-II for solar cells from June 2026 has exposed the risk of policy mandates moving faster than the certified domestic supply. Cell capacity should improve, but wafers and upstream materials could become the next bottleneck if localization requirements are extended before domestic capacity is ready. Battery storage is a more difficult localization story. India's battery ecosystem is weighted toward downstream pack assembly, battery management systems and project integration, while commercial-scale cell manufacturing and upstream active-material production are at an early stage. The Advanced Chemistry Cell Production-linked Incentive scheme provides an important policy foundation to address this challenge, targeting 50 GWh of domestic advanced chemistry cell manufacturing capacity. Government support and private sector announcements suggest that capacity could scale rapidly. Although execution-dependent, some early estimates indicate that India's cell manufacturing capacity could rise to 140 GWh by 2030. However, most battery manufacturing plans in India are being driven by mobility demand, where scale, cost economics and policy support are stronger. The power sector, by contrast, is more price-sensitive and likely to retain a smaller share of total battery demand. Mobility may underwrite the economics of battery manufacturing, but the resulting scale can become the cost and supply foundation for stationary storage. Looking forward: From clean capacity to strategic power India's next energy security challenge will be to manage the supply chain, infrastructure and markets that make a renewable-heavy power system work, rather than access to fuels or exposure to maritime chokepoints. Solar and wind will scale, but the harder work will be in the layers around them. This also changes the investment story, and generation assets and the upstream ecosystem may offer the most attractive opportunities. A conservative estimate suggests that India's clean-technology supply chain localization could require between $40 billion and $50 billion of investment by 2035. A phased plan to prioritize critical components for indigenization is paramount. A clear supply chain security and diversification road map is needed for items that must be imported. ]]></content></item><item><link>https://www.spglobal.com/en/research-insights/special-reports/india-forward/reimagining-growth/turning-resilience-into-momentum</link><description>Private investments, foreign direct investment and trade agreements will be&amp;#xd;&amp;#xa;among the engines of Indiaâ&amp;#x80;&amp;#x99;s next growth phase.</description><title>Turning resilience into momentum</title><author><name>Dharmakirti Joshi</name><name>Hanna Luchnikava-Schorsch</name></author><content><![CDATA[ 30 September 2026 Turning resilience into momentum Private investments, foreign direct investment and trade agreements will be among the engines of Indiaâs next growth phase. By Dharmakirti Joshi and Hanna Luchnikava-Schorsch This is a thought leadership report issued by the S&amp;P Global Institute. This report does not constitute a rating action, neither was it discussed by a rating committee. Highlights Indiaâs economy grew 7.7% in 2025-26, significantly outperforming expectations despite high US tariffs and global uncertainties. Growth is expected to slow down to 7.0% in 2026-27. The ongoing Middle East conflict, elevated crude oil prices, weak global demand and the specter of below-normal monsoon rains are likely to weigh on growth and increase inflationary pressures. Monetary policy is expected to be cautious due to inflation risks. As global shocks become more frequent and geopolitical realignment tilts toward protectionism, it is time to activate medium-term growth drivers through economic reforms. India needs to realize the full potential of recent efforts to increase engagement with the rest of the world through trade agreements. India's economy has proven resilient post-pandemic, outperforming most major economies despite geopolitical disruptions. A public infrastructure push, rapid digital infrastructure build-out, targeted incentives for manufacturing, welfare schemes and economic reforms have contributed to India's standout performance. The Economic Survey 2025-26 consequently raised the country's growth potential to 7.0% from an earlier estimate of 6.5%. India faced among the highest tariffs imposed by the US in 2025-26, yet the economy grew by 7.7% â more than 100 basis points above policymaker and analyst predictions. India began fiscal year 2026-27 with strong macroeconomic fundamentals: a healthy growth-inflation mix, robust bank and corporate balance sheets, and a comfortable current account position. But as the economy is now more integrated into global trade and capital flows, it is less insulated from global shocks. India's GDP growth of 7.8% in the first quarter exceeded expectations, continuing a pattern seen over the past several quarters. High-frequency indicators such as industrial production, services activity, strong merchandise exports, and goods and services tax collections indicated healthy economic momentum in the first quarter. The growth outperformance underscores the strength of India's domestic drivers and its ability to navigate an increasingly uncertain global environment. Figure 1 details the factors behind India's outperformance in 2025-26, along with the reasons a slowdown is expected in the current fiscal year. Three buffers add to Indiaâs resilience: Foreign exchange reserves cover more than nine months of imports as of July 31. While we expect the current account deficit to rise to 1.5% of GDP in fiscal year 2026 from 0.6% in fiscal year 2025, it will remain within the comfort zone. Balance sheet strength of borrowers and lenders. Crisil's credit rating upgrades outnumber its downgrades, although the upgrade-to-downgrade ratio moderated to 1.50 times in the second half of fiscal year 2026 from 2.17 times in the first half. Banks' gross nonperforming assets are at a decade low of 1.8% at the end of fiscal year 2026. At 92.6 million tons, food grain stocks were at more than twice their buffer norms as of July 2026. Two factors are likely to weigh on growth in the current fiscal year Middle East conflict This ongoing conflict has followed a cycle of escalation and de-escalation. While periods of de-escalation have given many economies breathing room, heightened uncertainty, supply chain disruptions, high and volatile Brent crude oil prices, and elevated freight and insurance costs have become the norm. Crisil expects crude oil prices to range between $82 and $87 per barrel in the current fiscal year, compared with $70 per barrel in the last. Crisil expects crude oil prices to range between $82 and $87 per barrel in the current fiscal year, compared with $70 per barrel in the last. The burden of higher crude prices was initially borne by oil marketing companies. The government then absorbed part of the shock through excise duty relief, before some of the increase was passed to consumers through higher petrol and diesel prices. Higher crude oil prices lead to slower growth, higher inflation and a wider current account deficit (CAD). Subnormal monsoons Although rainfall exceeded the India Meteorological Department's (IMDâs) forecast in July, steadily intensifying El NiÃ±o conditions in the equatorial Pacific persist, leaving the possibility of a dry spell later in the season. As of end of August, cumulative monsoon rainfall was 14% below the long-period average. The IMD has also signaled below-normal rainfall in September, the last month of the four-month southwest monsoon season in India. India has strengthened its irrigation buffer, with net irrigated area increasing by 10 percentage points to 59% over the past decade. The country also has ample rice and wheat stocks to help keep prices in check. Even so, subpar rainfall creates downside risks for agricultural output and upside risks for food inflation. Indiaâs foreign capital flow conundrum Foreign capital inflows dried up amid an otherwise standout economic performance. Even a low CAD of 0.6% of GDP could not be financed through capital inflows in 2025-26, leading to a sharp depreciation of the rupee. Capital outflows amid strong macro fundamentals were a key wrinkle in the India story. Net foreign portfolio inflows declined 16.6% last fiscal year. Between April and July 2026, foreign portfolio investors sold off Indian equities for three consecutive months, returning as net buyers in July. Global cyclical factors played a role, and their impact has been amplified by a structural shift in global capital allocation toward AI and technology. <img src="https://public.flourish.studio/visualisation/30022284/thumbnail" width="100%" alt="chart visualization" /> Gross foreign direct investment (FDI) inflows were healthy at $94.5 billion in 2025-26, but net inflows only reached $7.8 billion due to repatriation by foreign investors in India and outward investments by Indian companies. India is increasingly becoming a capital importer and exporter, reflecting greater corporate maturity but reducing the amount of net foreign capital available for domestic investment. Gross foreign direct investment (FDI) inflows were healthy at $94.5 billion in 2025-26, but net inflows only reached $7.8 billion due to repatriation by foreign investors in India and outward investments by Indian companies. We expect the CAD to increase to 1.5% of GDP in the current fiscal year. Financing is likely to be smoother due to an anticipated improvement in foreign capital flows and FDI. Recent Reserve Bank of India (RBI) measures aimed at attracting foreign capital appear to be yielding results, with cumulative inflows under these schemes exceeding $72.8 billion by Aug. 21. The schemeâs success prompted the RBI to close it one month early, by Aug. 31. On a calendar-year basis, gross FDI inflows increased 22.5% to $42.4 billion between January and May 2026, outpacing the 10% growth recorded over the equivalent period in 2025, itself higher than the global average. Improved capital flows should lend stability to the currency during the current fiscal year. Sustainable growth requires stronger private investment and higher FDI To realize the vision of Viksit Bharat by 2047, India must sustain an even faster growth trajectory, which requires a significant increase in the investment rate from the current level of about 32% of GDP. The World Bank estimates that 7.8% annual growth is required to achieve the objective. Enhanced role of private investments Public and household investment have been the key drivers of overall investment in India, while private corporate investment has grown more slowly, reducing its share of total investment. While public investment in infrastructure must continue, private investment has to take the lead. The private corporate sector's ability to invest, supported by healthy balance sheets and low leverage, does not match its willingness to invest. The nature of investment within the private corporate sector is also changing. Crisil estimates that the share of emerging sectors in overall industrial investment will rise to between 25% and 27% over the next five years, from 12% in the previous five years. These sectors include defense, data centers, solar photovoltaic, batteries, semiconductors and electronics, and electric vehicles. This shift is supported by the production linked incentive (PLI) scheme and growing market demand. Crisil estimates that the share of emerging sectors in overall industrial investment will rise to between 25% and 27% over the next five years, from 12% in the previous five years. Improvements in logistics, a stable business environment and reforms that make doing business easier, such as deregulation and stronger contract enforcement, will play an important role in improving the private investment climate. Why FDI needs a deeper push India has steadily liberalized its FDI regime, including opening the insurance sector to full foreign ownership. Yet, at about 2% of GDP, gross inflows remain modest relative to regional peers and the size of the economy and are below workers' remittance inflows. Global investment is increasingly concentrated in strategic sectors and geographies. UN Trade and Development estimates that AI infrastructure, semiconductors, critical minerals, energy-transition technologies and advanced manufacturing accounted for 44% of global greenfield FDI in 2025, up from 16% in 2020. India is benefiting from this trend, with Google's $14.5 billion AI and data center commitment marking the largest announced greenfield project in developing Asia in 2025. Yet India is in competition for a shrinking pool of global capital against economies with deeper manufacturing and supply chain ecosystems. The key question is whether India is securing a sufficiently large share of the investment that is shaping the next global investment cycle. Role of free trade agreements in supporting exports, manufacturing and FDI India is also rethinking its approach to free trade agreements (FTAs), which are increasingly being used to attract investment, deepen supply chain integration and strengthen Indiaâs position in strategic sectors, rather than as instruments for tariff reduction and market access. Recently signed FTAs and those nearing completion will improve market access and could be vehicles for foreign investment. Agreements such as the India-EFTA Trade and Economic Partnership Agreement and the India-New Zealand FTA place explicit emphasis on investment promotion and commitments. With six trade deals signed over the past four years, including one with the EU to be signed later this year, India will secure FTAs covering more than half of the world's top importing economies. Improved market access can boost exports, encourage domestic private investment in beneficiary sectors and attract additional FDI. Manufacturing exports will benefit from recently signed FTAs in a phased manner, with labor-intensive sectors such as garments, leather, gems and jewelry likely to be the earliest beneficiaries, according to Crisil Intelligence. Looking forward To achieve the Viksit Bharat 2047 vision, India must sustain higher growth through increased investment, with a greater role for the private sector and foreign direct investment. Recent FTAs could enhance exports, attract foreign investment, strengthen supply chain integration and, over time, improve India's position in strategic global industries. FTAs are not an end in themselves, and they must be complemented by efforts to improve India's competitiveness. Ongoing focus on infrastructure build-out, deregulation and increased spending on research and development will be critical to improving competitiveness, durably reviving private capital expenditure, and realizing the export and investment potential of recently signed agreements. ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/092926-uk-carbon-prices-surge-on-burnham-eu-summit-pledge</link><description>UK carbon prices rose about Â£3/metric ton of CO2 equivalent Sept. 29 after Prime Minister Andy Burnham confirmed a long-delayed EU-UK summit would take place before year-end, reviving market expectations that the two jurisdictions could move closer to linking their emissions trading systems. UK Allowances traded at Â£62/mtCO2e at 1643 BST Sept. 29, up 5.2% from the previous settlement, according to</description><title>UK carbon prices surge on Burnham EU summit pledge</title><pubDate>29 September 2026 16:46:19 GMT</pubDate><author><name>Toby Lambert</name><name>Eklavya Gupte</name></author><content><![CDATA[ Energy Transition, Carbon September 29, 2026 UK carbon prices surge on Burnham EU summit pledge By Toby Lambert and Eklavya Gupte Editor: Alisdair Bowles Getting your Trinity Audio player ready... HIGHLIGHTS UKAs climb 5% after UK PM says talks will take place by end-2026 Summit news lifts carbon linkage hopes EUA-UKA spread narrows sharply to about â¬13/mtCO2e UK carbon prices rose about Â£3/metric ton of CO2 equivalent Sept. 29 after Prime Minister Andy Burnham confirmed a long-delayed EU-UK summit would take place before year-end, reviving market expectations that the two jurisdictions could move closer to linking their emissions trading systems. UK Allowances traded at Â£62/mtCO2e at 1643 BST Sept. 29, up 5.2% from the previous settlement, according to the Intercontinental Exchange. Though prices had already been rising throughout the day, they saw a spike following the conclusion of Burnham's speech. "Later this year, there will be a UK-EU summit," said Burnham at the 2026 Labour Party Conference in Liverpool. "I will take the opportunity around the summit, to lay out to you, to lay out to the country, what I believe the different options are for Britain's long-term relationship with our European partners." The topic of linking the EU and the UK ETS was expected to be discussed at the summit, which had seen the spread between EU allowances and UKAs narrow to below â¬11/mtCO2e when the summit was first announced. The second EU-UK summit, originally planned for July 22 of this year, was delayed following the resignation of former UK Prime Minister Keir Starmer, which saw UKA prices tumble below Â£60/mtCO2e. This news follows Burnham meeting European Commission President Ursula von der Leyen at the UN General Assembly on Sept. 23, where the two leaders "discussed the importance of working towards a successful outcome for the next EU-UK summit later in the year," according to a UK government statement Sept. 23. Linkage sentiment improves The rally reflects the high stakes riding on the summit outcome. Following Brexit, the UK left the EU Emissions Trading System and established a separate, smaller and less liquid market, a structure that has made UK carbon prices more volatile, according to industry sources. The divergence also means UK industry faces exposure to the EU Carbon Border Adjustment Mechanism on about Â£7 billion of trade, according to government estimates, a burden that a successful ETS linkage deal would largely neutralize. The two sides have agreed to complete a linkage deal by the time of the summit, though a firm date has yet to be set. Despite the previous delays to the summit, market participants remain optimistic that the linkage between the two carbon compliance markets will proceed. Prior to Burnham's speech, the spread between EUAs and UKAs had been widening, reaching â¬19.27/mtCO2e on Sept. 21, the widest since April 22, according to Platts assessments. Platts is part of S&amp;P Global Energy. As of 1517 BST, the nearest December EUA-UKA spread stood at â¬13.85/mtCO2e, according to ICE data. "A slow grind to Â£65/mtCO2e is likely," said a UK-based trader. As the linkage progresses, the market expects the spread to narrow. Analysts at S&amp;P Global Energy CERA said in a recent note that the spread is likely to remain around â¬14/mtCO2e to â¬18/mtCO2e until there is "concrete progress". "If linkage is formalized and UKAs converge toward EUAs, the implied UKA price would be in the Â£65/mtCO2e to Â£72/mtCO2e range at current EUA levels and Â£/â¬ exchange rates," they added. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/agriculture/092826-india-saf-policy-expected-within-two-weeks-as-industry-eyes-2027-target</link><description>India could announce its sustainable aviation fuel policy in the first or second week of October, establishing a framework to move the country&amp;apos;s SAF industry beyond indicative blending targets and toward commercial implementation, the head of an industry association said Sept. 28. &amp;quot;We have been informed that the SAF policy could come in the first or second week of October,&amp;quot; Rohit Kumar, secretary</description><title>India SAF policy expected within two weeks as industry eyes 2027 target</title><pubDate>28 September 2026 21:53:58 GMT</pubDate><author><name>Samyak Pandey</name></author><content><![CDATA[ Agriculture, Energy Transition, Refined Products, Biofuels, Carbon, Vegetable Oils, Jet Fuel September 28, 2026 India SAF policy expected within two weeks as industry eyes 2027 target By Samyak Pandey Editor: Giselle Rodriguez Getting your Trinity Audio player ready... HIGHLIGHTS Policy announcement slated for early October Panipat refinery to begin co-processing output UCO collection reaches only 6% of potential India could announce its sustainable aviation fuel policy in the first or second week of October, establishing a framework to move the country's SAF industry beyond indicative blending targets and toward commercial implementation, the head of an industry association said Sept. 28. "We have been informed that the SAF policy could come in the first or second week of October," Rohit Kumar, secretary general of the SAF Association and the Carbon Markets Association of India, said at the India SAF Conclave in New Delhi. The announcement would arrive as India prepares to enter the mandatory phase of the International Civil Aviation Organization's Carbon Offsetting and Reduction Scheme for International Aviation, or CORSIA, from Jan. 1, 2027. India has established indicative SAF blending targets for international flights of 1% in 2027, 2% in 2028 and 5% by 2030. The government said in July that the draft policy was in its final stages, with inter-ministerial consultations and stakeholder engagement underway. Panipat could support the initial target Alok Sharma, vice president of the SAF Association and former director of research and development at Indian Oil Corporation, said India was moving from policy design toward practical deployment but must avoid treating SAF as a single fuel or technology. "SAF should not be viewed as a single technology," Alok Sharma said. Instead, India should develop a portfolio of pathways with different feedstock requirements, technology maturity, production economics, lifecycle performance and scalability. India's earlier experience with compressed biogas and second-generation ethanol demonstrated that new biofuel industries can encounter initial problems before technology, supply chains and commercial models stabilize, he said. Alok Sharma identified sustainable feedstock, scalable technology and predictable airline demand as three fundamental requirements for the emerging industry. In a broader framework, he said infrastructure and strong investment signals were also essential. Near-term supply is expected to be supported by refinery co-processing. Alok Sharma said Indian Oil Corporation was preparing to begin co-processing SAF at its Panipat refinery and that the planned output could support India's initial 1% requirement. The Panipat refinery became India's first facility certified to produce SAF through UCO co-processing. India amended its Aviation Turbine Fuel Control Order to include SAF-blended aviation fuel and recognize approved refinery co-processing and blending routes. The change was intended to help operationalize the country's blending targets. Feedstock availability versus accessibility India possesses significant theoretical feedstock potential, but only a fraction is currently available through organized and traceable supply chains. Annual edible-oil consumption of around 29 million-30 million mt could generate an estimated 1.8 million-2.6 million mt of UCO, according to the SAF Association. However, only around 110,000-156,000 mt, or about 6%, enters formal collection channels. Alok Sharma said UCO could support early HEFA and co-processing volumes, but would become increasingly constrained once blending rises beyond the initial stages. India would therefore need to develop alcohol-to-jet and other pathways alongside waste-oil processing. Certification, demand certainty remain unresolved Certification compliance, chain-of-custody documentation, mass-balance systems and lifecycle emissions accounting must be established before Indian SAF can qualify under CORSIA or access premium international markets, Alok Sharma said. Long-term airline offtake would also be needed to give producers sufficient revenue certainty to finance projects. He identified viability-gap funding, production-linked incentives, corporate social responsibility funding, concessional and green finance, and carbon-market revenue as potential means of supporting early projects. These concerns align with the government's earlier identification of high capital and operating costs, expensive feedstock, fragmented collection systems, limited long-term offtake and inadequate fiscal support as obstacles to domestic production. Early SAF markets in the EU and US have relied on combinations of mandates, penalties and production incentives. India would similarly require demand-side obligations and supply-side support if it wants to progress from the 1% requirement to the more demanding 5% target, Alok Sharma said. The SAF Association estimates that India could eventually develop around 40 million mt/year of SAF production potential by 2050, equivalent to roughly 10% of projected global capacity. However, realizing that potential would depend on converting available resources into feedstock that is collectible, certified and commercially deliverable. The immediate challenge, Alok Sharma said, is to ensure that the forthcoming policy connects feedstock, technology and airline demand rather than establishing blending percentages without the commercial mechanisms required to support them. Platts, part of S&amp;P Global Energy, assessed Sustainable Aviation Fuel HEFA-SPK FOB Straits, reflecting CORSIA-certified cargoes, at $2,440/mt on Sept. 28, unchanged from Sept. 25, US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/2026/08/picture-this-mexico-server-boom-ai-data-center-supply-chains</link><description>Mexicoâ&amp;#x80;&amp;#x99;s AI server exports surge as reshoring, Taiwan trade ties and tariff exemptions reshape data center supply chains.</description><title>Picture This: Mexico&amp;apos;s Server Boom Reshapes AI Data Center Supply Chains</title><pubDate>12 August 2026 16:45:00 GMT</pubDate><author><name>Chris Rogers</name><name>Ines Nastali</name><name>Eric Oak</name></author><content><![CDATA[ BLOG â Aug. 12, 2026 Picture This: Mexicoâs Server Boom Reshapes AI Data Center Supply Chains By Vania Alvarez Murakami, Chris Rogers, Ines Nastali, and Eric Oak What we know Mexico has emerged as a significant and growing supplier of computer servers used in AI-driven data centers. Exports reached US$82.9 billion in the first half of 2026, putting the category on pace to surpass autos and auto parts exports for the full year. Computer server exports grew by 172.1% year over year in the 12 months to June 30, 2026, following 210.8% growth in 2025. The US remains the primary destination, absorbing 93.9% of Mexicoâs computer server exports over the 12-month period. The export surge highlights Mexicoâs growing relevance as a reshoring center for advanced electronics, even as trade uncertainty persists around tariffs and USMCA renegotiations. Why it matters The AI investment cycle is not only increasing demand for data centers; it is also reshaping where the physical infrastructure behind those data centers is created. Mexicoâs rise in computer server exports suggests that reshoring is moving beyond traditional manufacturing categories into higher-value electronics supply chains. That shift is also visible in Mexicoâs import patterns. Imports from Taiwan rose 146.4% year over year in the 12 months to June 30, 2026, after growing 169.0% in 2025. Taiwan accounted for 13.4% of Mexicoâs total imports over the period, up from 2.1% in 2019, making it Mexicoâs third-largest supplier after the US and mainland China. The import growth has been led by computer servers. Mexican imports of computer servers from Taiwan reached US$28.4 billion in the first half of 2026, already surpassing the US$15.1 billion imported during all of 2025. What to watch Watch tariff policy and infrastructure. Mexicoâs tariff framework excludes information technology and communications products, which may help sustain server trade amid broader uncertainty. Mexicoâs ability to turn the server boom into a durable role in high-value electronics will depend on sustained AI infrastructure demand, stable US-Mexico trade conditions and improvements in security and connectivity. Learn how our data and insights can empower strategic, operational, and tactical decision-making Click Here This article was published by S&amp;P Global Market Intelligence and not by S&amp;P Global Ratings, which is a separately managed division of S&amp;P Global. Register for Inland26 The must-attend conference for shippers and transportation and logistics providers moving goods from ports to inland destinations Click Here ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/creditweek-will-climate-events-lead-to-more-rating-actions-s101707862</link><description>Another summer of record-breaking temperatures and wildfires in Europe, floods and storms across Asia, and extreme heat and drought in North America has reinforced a stark reality: Climate change is no longer a future risk. For the investors, policymakers, and companies convening at Climate Week NYC 2026, conversations have focused on how resilience is no longer optional, but becoming essential to protecting economies, businesses, and long-term value in a more volatile climate. Attention and act</description><title>CreditWeek: Will Climate Events Lead To More Rating Actions?</title><pubDate>24 September 2026 20:27:51 GMT</pubDate></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/emerging-markets-funding-resilience-could-be-tested-s101707588</link><description>This report does not constitute a rating action. Emerging market (EM) financing conditions are entering a more challenging phase. Higher developed-market borrowing needs and tighter global financing conditions raise questions about whether EMs can continue to fund themselves as easily as in recent years. If external conditions become less supportive, outcomes will vary increasingly across countries and sectors, reflecting differences in refinancing needs, policy settings, and domestic market dep</description><title>Emerging Marketsâ&amp;#x80;&amp;#x99; Funding Resilience Could Be Tested</title><pubDate>28 September 2026 17:08:12 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/metals/092926-indias-ultratech-meets-power-needs-at-chhattisgarh-plant-entirely-from-green-energy</link><description>India&amp;apos;s UltraTech Cement said in a statement Sept. 28 that its integrated Kukurdih cement plant in Chhattisgarh has met its entire electricity demand through renewable energy and waste heat recovery systems each month since April, marking a milestone in the company&amp;apos;s decarbonization efforts. The Kukurdih facility, commissioned in 2024 and equipped with 3.3 million metric tons/year of grey cement</description><title>India&amp;apos;s UltraTech meets power needs at Chhattisgarh plant entirely from green energy</title><pubDate>29 September 2026 04:01:00 GMT</pubDate><author><name>Jia lun Ong</name></author><content><![CDATA[ Metals &amp; Mining, Energy Transition, Electric Power, Renewables September 29, 2026 India's UltraTech meets power needs at Chhattisgarh plant entirely from green energy By Jia lun Ong Editor: Sivassanggari Tamil selvam Getting your Trinity Audio player ready... HIGHLIGHTS Kukurdih plant runs on 100% renewable power One-third of 76 units exceed 50% green energy Company targets 85% green power by 2030 India's UltraTech Cement said in a statement Sept. 28 that its integrated Kukurdih cement plant in Chhattisgarh has met its entire electricity demand through renewable energy and waste heat recovery systems each month since April, marking a milestone in the company's decarbonization efforts. The Kukurdih facility, commissioned in 2024 and equipped with 3.3 million metric tons/year of grey cement capacity, achieved the target through a combination of renewable power procurement and waste heat recovery generation, according to the company. UltraTech said the achievement reflects a broader shift across its manufacturing network. Since April, nearly one-third of the company's 76 production units in India have sourced more than half of their electricity requirements from renewable energy and waste heat recovery, while five sites, including Kukurdih, have recorded green power utilization above 95%. The producer is also expanding the deployment of battery energy storage systems to facilitate higher renewable energy penetration. As of the first quarter of fiscal year 2026-27, UltraTech's captive green power portfolio comprised 1,463 megawatts of renewable energy capacity and 434 MW of waste heat recovery capacity. The company targets an 85% share of green power in its electricity mix by 2030, in line with its RE100 commitment. Several Asia-based market participants said the development reflects a broader push by cement producers to increase the use of renewable energy and waste heat recovery as the sector seeks to lower operating costs and reduce carbon emissions. "Producers are facing growing pressure to improve energy efficiency while advancing their decarbonization targets," an Asia-based trader said. "Investments in renewable power, waste heat recovery and energy storage are becoming increasingly common across the region as companies look to reduce exposure to conventional power costs and tightening environmental requirements." Platts, part of S&amp;P Global Energy, last assessed cement (ASTM type I) FOB Vietnam at $38/mt on Sept. 24, unchanged week over week. Platts assessed cement clinker FOB Vietnam at $32.50/mt, unchanged over the same period. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/sf-credit-brief-us-private-credit-clo-insights-2026-a-tale-of-two-cohorts-s101708956</link><description>This report does not constitute a rating action. S&amp;amp;P Global Ratings is publishing this report to provide key metrics on the credit-estimated companies with loans in U.S. middle market collateralized loan obligations (MM CLOs), as well as CLO performance indicators. Our private credit and middle market CLO slide deck is published in the first month of each quarter (see &amp;quot; Private Credit And Middle-Market CLO Quarterly: What Lies Beneath (Q3 2026) , &amp;quot; July 24, 2026). As of mid-September, we have ra</description><title>SF Credit Brief: U.S. Private Credit CLO Insights 2026: A Tale Of Two Cohorts</title><pubDate>28 September 2026 17:35:41 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/092126-path-to-net-zero-two-thirds-of-top-us-utilities-cancel-or-fall-behind-targets</link><description>This is the first in a multi-part series on net-zero efforts across industries. As atmospheric carbon dioxide levels reached another high in 2025, a majority of the 30 largest US electric utilities relaxed or withdrew their net-zero goals. One power company canceled all its emission reduction targets, while others lost ground on reductions already achieved, according to an annual survey by Platts,</description><title>PATH TO NET-ZERO: Two-thirds of top US utilities cancel or fall behind targets</title><pubDate>21 September 2026 15:01:46 GMT</pubDate><author><name>Karin Rives</name></author><content><![CDATA[ Energy Transition, Electric Power, Agriculture, Coal, Natural Gas, Carbon, Emissions, Food, Renewables September 21, 2026 PATH TO NET-ZERO: Two-thirds of top US utilities cancel or fall behind targets By Karin Rives Editor: Karina Roman Getting your Trinity Audio player ready... HIGHLIGHTS Rising electricity demand complicates goals Emissions increase after years of decline This is the first in a multi-part series on net-zero efforts across industries. As atmospheric carbon dioxide levels reached another high in 2025, a majority of the 30 largest US electric utilities relaxed or withdrew their net-zero goals. One power company canceled all its emission reduction targets, while others lost ground on reductions already achieved, according to an annual survey by Platts, part of S&amp;P Global Energy. The shift in the US power sector marks a major departure from the climate ambitions most companies expressed a few years earlier and comes amid major policy and market changes. "We are shifting our 2030 goal not because we believe we can't achieve it, but because doing so would put an unacceptable cost burden on our customers," Xcel Energy Inc. explained in its 2025 sustainability report after canceling its goal to reduce companywide emissions by 80% by 2030. "The responsible pathway requires more time to get there. Our destination hasn't changed, but the pathway must evolve." American Electric Power Co. Inc. (AEP), the fifth-largest publicly traded US electric utility by market cap, adopted a new strategy in 2025 to serve differing energy policies and customer priorities within its 11-state service territory as demand for electricity soared. The company canceled all its climate goals to instead pursue an "all-of-the-above approach" to balance economic growth, reliability and affordability with state-specific objectives, according to company spokesperson Matthew Thompson. "AEP remains on track to meet clean energy mandates in states [such as] Virginia and Michigan," Thompson said in an email, referencing states with renewables goals mandated by law. A year earlier, AEP said it would reach net-zero for operational Scope 1 and Scope 2 greenhouse gas emissions by 2045 and cut Scope 1 emissions by 80% by 2030. Even so, all but two of the 30 US largest power companies still say they will zero out emissions by 2050 or sooner. Simply switching out paid-for fossil-fueled plants with clean energy is not as easy as it was when electricity demand growth was flat, said Steve Piper, energy research director with S&amp;P Global Energy CERA. "When demand growth starts going to 1.5% and 2%, the math gets much harder," Piper said in an interview. "You have to substitute for your fossil fuel generation while also providing for that incremental load growth. The targets get more difficult to reach in that situation." Add to that equation disappearing tax subsidies for solar and wind investments, tariffs and trade restrictions limiting imports of key technology components, overall inflationary pressures and regulatory delays, and the industry has started reevaluating the timing of new clean energy investments, Piper said. Climate fades from discourse Pressures to keep power costs down permeated this year's survey and newly published sustainability reports. "Many New Jerseyans are trying to make ends meet as costs including food, housing, energy and health care increase," Public Service Enterprise Group Inc. (PSEG) wrote in a 2026 progress update announcing it had delayed until 2050 its previous goal to hit net-zero emissions for all utility operations by 2030. "PSEG stands ready to work with policymakers to take steps to tackle the root cause of New Jersey's supply-and-demand imbalances that have led [to] the recent increases in electric rates." PSEG, which also operates in a state with renewables and net-zero mandates, has delivered 100% clean power since 2023 and has already reduced Scope 1 and 2 carbon emissions by 95% from 2005 levels â results exceeding what most US power companies have achieved. Still, preparing for complete decarbonization by 2030 is proving tough. Ben King, director of the think tank Rhodium Group's energy and climate practice, also pointed to what he said could be "the highest demand growth that we've ever seen." Interim 2030 goals crept up on companies as power needs and the political environment shifted, prompting companies to delay and cancel promises made a few years ago, King said in an interview. "I also think, candidly, that the political environment makes it easier to do that right now," King said. "You've got a White House and Congress saying we need power and we need to get it from our preferred resources. And you've got folks on the other side of the aisle not talking as much about climate right now." The power sector's carbon footprint has been expanding as a result, reversing several years of declining emissions. Evergy Inc., also with an all-of-the-above approach to power production, reported a 24% increase in Scope 1 operational carbon emissions in 2025. Even so, Evergy had cut emissions to 47% below 2005 levels. The total greenhouse gas emissions of AEP, another coal and natural gas-heavy utility, rose 10% in 2025. Emissions from AEP's total owned generation had dropped to 68% below 2005 levels, the company reported. Experts said that without accelerated emission reductions, US electric utilities will fall significantly behind their 2050 climate ambitions. With emissions on the rise and reductions slowing down after years of progress, net-zero by 2050 has become "very much a questionable goal," said Lily Bermel, a visiting fellow at Columbia University's Center on Global Energy Policy. But the trajectory could change, Bermel said. If permitting and transmission barriers are removed, the pace at which clean energy sources are added to the grid will likely rapidly accelerate and get the US energy transition back on its previous track, Bermel said in an interview. "Last year, 93% of what got added to the grid was renewables and storage," Bermel said. "There's no amount of policy that can change that." Bermel recently published a paper arguing that even though Congress rescinded most clean energy incentives and programs under the Inflation Reduction Act and passed the Republican One Big Beautiful Bill Act that favors fossil fuels, 67% of emission reductions the 2022 law would have delivered over 2025-2035 will be preserved. At the same time, fossil fuel generation could be 19% higher, Bermel wrote. Susan Dlin contributed to this article. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/2026/09/risk-now-a-defining-variable-for-breakbulk-and-project-cargo-moves</link><description>Risk is reshaping breakbulk and project cargo as geopolitical threats, congestion and infrastructure constraints disrupt routing and execution.</description><title>Risk now a defining variable for breakbulk and project cargo moves</title><pubDate>28 September 2026 12:00:00 GMT</pubDate><author><name>Carly Fields</name></author><content><![CDATA[ BLOG â Sep 28, 2026 Risk now a defining variable for breakbulk and project cargo moves By Carly Fields Risk has become the defining variable shaping breakbulk and project cargo routing decisions, vessel deployment, port selection and project execution across global supply chains, according to speakers on a Sept. 17 Journal of Commerce webcast. Drawing together perspectives from maritime security, fleet analysis and project logistics, panelists said the sector is increasingly navigating a world in which geopolitical instability, congestion and infrastructure constraints can have a greater impact on freight outcomes than underlying supply and demand. Much of the discussion centered on the Middle East, where shipping operators continue to face elevated risks in both the Strait of Hormuz and the Red Sea. âThe most acute maritime threat point is in the Strait of Hormuz â that's where shipping currently faces an extreme level of risk,â said Jack Kennedy, research and analysis director at S&amp;P Global Market Intelligence Country Risk, citing ongoing concerns over missile attacks, naval activity and uncertainty surrounding the deployment of naval mines. For breakbulk and project cargo operators, however, the challenge extends far beyond the threat of direct attacks. Kennedy argued that risk perception itself has become a powerful market force. âEven if the main shipping lines through the Strait of Hormuz are eventually cleared, the perception of risk and the uncertainty that that generates is probably going to discourage a lot of operators from resuming transit,â he said. Longer-term hesitation has significant consequences for project cargo movements, many of which involve high-value equipment, bespoke supply chains and inflexible delivery schedules. Unlike commodity cargoes, large industrial projects often cannot absorb extended delays or sudden route changes without triggering additional costs throughout the project lifecycle. The Red Sea provides a clear example. According to Kennedy, even periods of reduced conflict do not automatically restore confidence among shipping operators. âThe lag time that comes after a conflict can be just as impactful as the actual conflict time itself,â he said. For shippers, that means rerouting decisions made during a crisis can continue long after active hostilities decline. Ripple effects of routing restrictions The operational consequences are already visible. Susan Oatway, senior research analyst for breakbulk and project cargo at S&amp;P Global Market Intelligence, noted that many breakbulk and project cargo vessels continue to avoid traditional routes through the region, contributing to tighter vessel availability and longer voyage distances. The result is a cascading effect across global project logistics networks. Longer rerouting around the Cape of Good Hope removes effective capacity from the market, while congestion at alternative gateways places additional pressure on already stretched supply chains. Geopolitical conflict is only one dimension of the risk equation, though. For project cargo specialists, climate-related disruptions and infrastructure bottlenecks are increasingly creating similar challenges. The Panama Canal was repeatedly cited as an example of how external events can derail carefully planned operations. Oatway said carriers and shippers are already factoring canal restrictions into routing decisions. âYouâre looking at increased rerouting, or youâre looking at a huge payment additional to your cargo,â she said. Kevin Kwateng, founder and CEO of Project Logistics Engineering Solutions, gave a real-world example involving a move of refinery modules from China to Montreal. Restrictions at the canal generated delays, additional costs and planning complications that rippled through the broader project schedule. What makes such risks particularly acute in the project sector is the interconnected nature of delivery schedules. Heavy-lift transport equipment, specialized labor, permits and receiving-site preparations are typically planned months in advance. âThese delays shift the schedule, which means that you have to start over from the beginning in terms of scheduling,â Kwateng said. Port risk is emerging as another major concern. According to Kwateng, congestion is no longer limited to the largest container gateways. Growing volumes of wind energy equipment, battery projects and large industrial cargoes are placing unprecedented strain on breakbulk and project cargo terminals. âOne of the things that weâre seeing is a lot is ports just simply not being available to meet the demand,â he said. For project cargo shippers, finding an alternative port is often easier said than done. Routes from terminals to final destinations frequently require years of engineering studies, bridge assessments, utility clearances and permitting work. âJust because you can get to a port, it doesnât mean itâs the right one,â Kwateng warned. That reality has forced many project owners to adopt a far more flexible approach to risk management. Rather than relying on a single transportation plan, companies are increasingly developing multiple contingency options before cargo even begins moving. âThe only solution that actually exists is the solution that you have in front of you,â Kwateng said. âPeople are getting more creative.â This article was originally published by the Journal of Commerce on Sept. 18, 2026. Subscribe to JOC.com Learn more about our data and insights Click Here Register for Inland26 The must-attend conference for shippers and transportation and logistics providers moving goods from ports to inland destinations Click Here ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/sustainability-insights-sustainable-finance-volume-in-africa-is-rising-but-remains-insufficient-s101706568</link><description>This report does not constitute a rating action. This research report explores an evolving topic relating to sustainability. It reflects research conducted by and contributions from S&amp;amp;P Global Ratings&amp;apos; sustainability research and sustainable finance teams as well as our credit rating analysts (where listed). Chart 1 This forecast is based on broadly favorable external financing conditions in most African countries, a gradually growing track record of sustainable debt issuance, as well as a need </description><title>Sustainability Insights: Sustainable Finance Volume In Africa Is Rising But Remains Insufficient</title><pubDate>28 September 2026 13:01:27 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/092426-path-to-net-zero-politics-of-mineral-security-to-shape-miners-efforts</link><description>This is the fourth in a multi-part series on net-zero efforts across industries. The previous article can be found here. A major push by Western nations and their trading partners to secure critical mineral supply chains is reshaping the mining sector&amp;apos;s net-zero efforts, experts told Platts, part of S&amp;amp;P Global Energy. Western nations have been working to reduce their reliance on China-dominated</description><title>PATH TO NET ZERO: Politics of mineral security to shape miners&amp;apos; efforts</title><pubDate>24 September 2026 13:30:27 GMT</pubDate><author><name>Anthony Rizkala</name></author><content><![CDATA[ Metals &amp; Mining, Energy Transition, Electric Power, Non-Ferrous, Carbon, Emissions, Ferrous, Renewables September 24, 2026 PATH TO NET ZERO: Politics of mineral security to shape miners' efforts By Anthony Rizkala Editor: Bill Montgomery Getting your Trinity Audio player ready... HIGHLIGHTS Agreements may accelerate sector emissions cuts Miners deploy electric trucks, renewable energy This is the fourth in a multi-part series on net-zero efforts across industries. The previous article can be found here. A major push by Western nations and their trading partners to secure critical mineral supply chains is reshaping the mining sector's net-zero efforts, experts told Platts, part of S&amp;P Global Energy. Western nations have been working to reduce their reliance on China-dominated critical mineral supply chains by signing international investment, trade and supply agreements, marking a shift in international priorities from climate change to security of supply. But experts say the surge in cross-border agreements may still support and even accelerate emissions reduction in the mining sector. Major players such as the EU, Australia and Canada have stringent climate policies, and trade agreements will have to align with these regulations even if other countries like the US are more focused on boosting supply. "At the geopolitical level, security of supply has become the dominant concern," Bryony Clear Hill, director of innovation for the International Council on Mining and Metals (ICMM), told Platts. "Policymakers understand the importance of decarbonization, but they're weighing it against real pressures on critical mineral access and supply chain resilience. That said, the two agendas aren't completely separate." Addressing reliance on China In 2025, China accounted for 85% of global rare earth processing capacity and dominated processing of other key minerals, such as lithium and cobalt, according to the International Energy Agency. The minerals powerhouse exerted its market dominance in 2025 by imposing export controls on critical minerals and rare earths. The subsequent pressure on Western economies drove a series of new mineral deals, and miners may find their decarbonization goals being shaped by these trade agreements. "Cross-border investment is really starting to dictate some of the miners' decarbonization goals sitting alongside supply chain security," Rebecca Seidl-Inglesby, a partner at law firm Baker Botts, told Platts. "An example is the US-Japan strategic memorandum in which we have inbound investment from the government of Japan that needs to align with their abatement goals," said Seidl-Inglesby, who also leads the law firm's critical minerals and metals practice. In March, the US and Japan announced a partnership to support each other's critical mineral supply chain resilience. Japan aims to achieve net-zero emissions by 2050 and has a target to reduce its greenhouse gas emissions by 46% by 2030. "These international trade agreements might actually accelerate some of the decarbonization efforts," Reinhardt Arp, mining and metals lead at global climate consulting firm The Carbon Trust, told Platts. "I think a lot of countries that are racing to secure these agreements understand they need to support responsible mining." Arp emphasized that the extent to which decarbonization advances through trade agreements depends on which countries are involved. "Some countries might be happy to just increase supply without really driving decarbonization," Arp said. "But other countries, particularly those exposed to European trade mechanisms like the [Carbon Border Adjustment Mechanisms], will be impacted. [As] the EU is engaging in these international trade agreements, all these pieces of the puzzle might just slot into place and be a driver for decarbonization." US President Donald Trump has actively opposed efforts to reduce CO2 emissions and withdrew the US from the Paris Agreement and other international climate commitments. The US has also signed or approved 160 mineral deals since January 2025, according to an Aug. 7 White House fact sheet. Although US policy has shifted away from decarbonization, other nations are still working to cut emissions. The EU, Canada, Australia and others have maintained their net-zero targets and climate policies. The EU implemented its CBAM policy to cut carbon emissions entering the bloc, and both Canada and Australia have codified their net zero by 2050 targets into law. Agnico Eagle Mines Ltd., one of the world's largest gold producers, told Platts the constant regulatory changes and shifting geopolitics have caused challenges for miners. "We still have a goal to make our mines carbon resilient and our [emissions reduction] 2030 goal," said Mohammed Ali, the miner's vice president of sustainability and regulatory affairs. "But when Europe, Australia, Canada, etc., are emerging with new standards, it's been quite distracting, and it's been using up our resources. There's been a lot of noise this year that has been a challenge." Miners advance decarbonization amid geopolitical tumult Company Date announced Emissions reduction action Freeport-McMoRan Inc. Feb. 2, 2026 Secured contracts to power Cerro Verde copper site in Peru and El Abra copper site in Chile with "near-100 percent" renewable electricity. Fortescue Ltd. Feb. 12, 2026 Commenced commissioning of two new battery-electric locomotives on its rail network at its Pilbara iron ore operations in Western Australia. Rio Tinto Group April 8, 2026 Commissioned 148-MW solar farm in Richards Bay, South Africa. Vale SA April 9, 2026 Partnered with Shandong Shipping Corp. for two 325,000 mt capacity ethanol-powered shipping vessels. Fortescue Ltd. May 25, 2026 Construction commenced on 690-MW solar farm in the Pilbara region and a 650-MWh battery energy storage system at its Cloudbreak mine. Rio Tinto Group and BHP Group Ltd. June 23, 2026 Collaborated on launch of Caterpillar battery-electric haul truck trials at a mine site in the Pilbara region. mt = metric tons; MW = megawatt; MWh = megawatt-hour The table shows select decarbonization actions by major miners in the first half of 2026. Source: S&amp;P Global Energy Miners cutting emissions Amid the geopolitical tumult and reshaping of supply chains, miners have pressed on with emissions reduction efforts. BHP Group Ltd. and Rio Tinto Group, the world's two largest miners by market capitalization, jointly launched trials of battery-electric haul trucks at iron ore operations in Western Australia. Fortescue Ltd. commenced construction on a 690-megawatt solar farm and a 650-megawatt-hour battery energy storage system, and said it is on track to fully decarbonize mining operations by 2030. "I'd say [2026] is a step forward at this point," Anna Zanetti, strategic communications manager for the Brussels-based trade group Euromines, told Platts. "Companies kept making real operational progress, like Boliden AB (publ) and Epiroc AB (publ)'s battery-electric trolley system at Kristineberg [zinc-gold mine in Sweden] and LKAB's [Luossavaara-Kiirunavaara AB (publ)] move toward fossil-free pellets." Zanetti also highlighted the EU's new Emissions Trading System package proposed in July. "It sets up a â¬100 billion Industrial Decarbonisation Bank starting in 2028, extends free allowances for heavy industry into the 2040s, and pushes the phaseout of free CBAM sector allocation back from 2034 to 2038," Zanetti added. "It looks like an attempt to protect industrial competitiveness through extended free allocation and the new decarbonization bank while still keeping the 2040 climate target intact." Volatility in global energy markets has also pushed miners toward more sustainable methods. "The geopolitical uncertainty around the energy supply chain is definitely sharpening focus on how energy is used and what energy is used," said Mary Stewart, partner at global sustainability consulting firm ERM. "Miners are looking at the efficient use of fossil fuels or other liquid fuel sources, and it changes the business case for electrification." Stockholm-based Sandvik AB (publ), a major producer of electric mining equipment, told Platts it has seen the conversation around mining electrification mature as deployment becomes more widespread. "We see some miners report above 30% improvements in tons per hour, 50% lower maintenance cost and a strongly favorable return on investment, meaning the question is no longer about whether electrification makes sense, but rather, can those substantial benefits be realized in a given mine with its mine design," said Tommi Valkonen, head of battery-electric vehicle strategy at Sandvik Mining. The changing landscape and major shifts in supply chain dynamics come as most of the top miners narrow in on their first set of concrete emissions goals. "2030 is a year where a lot of companies have set their first initial near-term decarbonization targets," The Carbon Trust's Arp said. "That's going to be a pivotal point in not just mining, but the global energy transition. We'll see if these companies achieve their targets. And if not, will there be penalties? I do think it's a pivotal next five years." Susan Dlin contributed to this article. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/japan-auto-brief-us-tariff-uncertainty-weighs-on-japanese-makers-s101705588</link><description>This report does not constitute a rating action. A 50% U.S. tariff on Canadian auto imports could hurt earnings for Japanese automakers. Canadian-made autos exported to the U.S. in 2025 made up 3% of Toyota&amp;apos;s total sales volume, and 10% for Honda. These proportions exceed overseas peers&amp;apos;. Nissan Motor Co. and Mitsubishi Motors Corp. don&amp;apos;t manufacture in Canada. During negotiations on the United States-Mexico-Canada Agreement (USMCA), the U.S. announced plans to raise tariffs on vehicles and auto</description><title>Japan Auto Brief: U.S. Tariff Uncertainty Weighs On Japanese Makers</title><pubDate>14 September 2026 03:23:54 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/blog/crude-oil/092826-insight-conversation-debangsu-ray-reliance-industries</link><description>While India&amp;apos;s transport fuel demand is expected to continue growing into the next decade, Reliance Industries Ltd. views the Jamnagar refinery&amp;apos;s scale, complexity and integration as the foundation of its resilience amid geopolitical volatility, margin pressure and the energy transition. In this interview, Reliance Industries Cluster President Debangsu Ray, who heads the company&amp;apos;s Jamnagar refinery</description><title>INSIGHT CONVERSATION: Debangsu Ray, Reliance Industries</title><pubDate>28 September 2026 06:31:56 GMT</pubDate><author><name>Sambit Mohanty</name></author><content><![CDATA[ Crude Oil, Refined Products, Chemicals, Energy Transition, Electric Power, Agriculture, Renewables, Olefins, Biofuels, Hydrogen, Carbon, Diesel-Gasoil September 28, 2026 INSIGHT CONVERSATION: Debangsu Ray, Reliance Industries By Sambit Mohanty Editor: Barbara Lorenzo-Caluag Getting your Trinity Audio player ready... While India's transport fuel demand is expected to continue growing into the next decade, Reliance Industries Ltd. views the Jamnagar refinery's scale, complexity and integration as the foundation of its resilience amid geopolitical volatility, margin pressure and the energy transition. In this interview, Reliance Industries Cluster President Debangsu Ray, who heads the company's Jamnagar refinery and petrochemical complex, speaks to S&amp;P Global Energy Editorial Lead Sambit Mohanty about India's competitiveness in the refining industry amid a volatile geopolitical landscape. He discusses how Jamnagar's ability to process a highly diverse crude slate, integrate with petrochemicals and progressively decarbonize through renewables will help keep the refinery competitive and ready to meet future challenges. How is Reliance leveraging its complex refining configuration to navigate current geopolitical volatility, and what specific advantages or vulnerabilities do Indian refiners face as global trade routes and crude supply flows become more fragmented? The oil market is global in nature, and supply disruptions have adverse consequences for the world. However, Asia-Pacific, which sources substantial quantities of oil from the Middle East, has seen a larger impact. The configuration, scale and infrastructure of the Jamnagar refinery provide us with the flexibility to process crude oil with a wide range of API gravity, sulfur content and TAN [total acid number]. The crude oil slate of the Jamnagar refinery has always been diverse. This gave us the ability to source feedstock from different regions and tide over the current crisis, and this can also help to serve us in the future. India has firmly established itself as a premier global refining hub, balancing vast domestic demand with aggressive clean product export strategies. As the industry faces volatile and tighter global margins, how do you see the competitiveness of Indian complex refiners evolving against emerging state-of-the-art capacity in the Middle East and China? New refining capacity with higher complexity will increase competition for existing refineries. Our emphasis will continue to be on deep petrochemical integration, optimized logistics, energy self-sufficiency and efficiency, disciplined cost management across the entire value chain, supported by our agility and global footprint in petroleum product marketing. Our unwavering focus on world-class reliability, real-time optimization, digitalization of work processes, circularity and decarbonization is likely to be the key differentiator that will stand us in good stead in the future. With the energy transition threatening long-term transport fuel demand, what is Reliance's targeted crude-to-chemicals conversion plan for the future, and which specific high-value petrochemical building blocks are you prioritizing to protect margins? Several past forecasts of a rapid decline in transport fuel demand have proven to be premature. Technological pathways to reduce transport fuels and increase petrochemical production are already available and are maturing, with a few small-scale units in operation. These include crude-to-chemicals and multizone catalytic cracking with selectivity toward higher olefinic yields. However, these options call for multibillion-dollar investments. We will continue to monitor the supply and demand balances, progress on technological pathways and calibrate our strategy. We have plans for value addition through increased petrochemical production. Being a well-established large player in the petrochemical business, we will be able to move quickly. How is Reliance balancing capital allocation between maintaining its traditional refining edge and scaling up its new energy gigafactories? The next chapter for Jamnagar is about multidimensional integration. We are transforming the site from a premier fuel factory into a hyper-integrated energy and materials complex. The primary capital allocation shall follow two megatrends: deep petrochemical expansion and world-scale green energy manufacturing. By placing solar, bioenergy and advanced energy storage ecosystems in close proximity to our refining footprint, we will create a symbiotic loop where clean energy powers low-carbon refining, which in turn yields the high-tech materials needed for the transition. Given India's push for biofuels and electric vehicles, how do you project the timeline for peak transport fuel demand in India, and how will Reliance shift its product slate between domestic supply and export markets as the peak approaches? India's energy transition is unique because it still has enormous mobility growth ahead and has yet to reach peak transport fuel demand. Given India's robust GDP growth, we expect absolute domestic demand for conventional transport fuels to continue growing well into the next decade before plateauing. We are actively co-processing bio and circular feedstocks and scaling up infrastructure to meet the government's accelerated ethanol and biodiesel blending mandates. Through our planned integration of green hydrogen into our hydro-treating blocks and maximizing chemical conversion, we will supplement revenue growth from long-term fossil fuel demand. Decarbonizing a refining footprint of this scale is a monumental task. Could you highlight the operational milestones Jamnagar is targeting for integrating renewable power, adopting green hydrogen, advancing carbon capture or scaling up co-processing with bio-feedstocks? Decarbonizing an asset of Jamnagar's scale requires an all-of-the-above engineering approach. We are targeting substantial emissions reductions through three distinct pillars. First, we will progressively replace internal fossil-based process heating and captive power with renewable power and green hydrogen. Second, we are scaling up the co-processing of biomass in our gasifiers and retrofitting our hydrotreaters for part processing of renewable bio-oil feed. Finally, we are laying the technical groundwork for carbon capture and utilization â converting captured carbon dioxide into industrial chemical building blocks. At what point do you foresee green hydrogen becoming cost-competitive enough to deeply decarbonize your refining operations? As I mentioned in my previous answer, green hydrogen is one of the green alternatives for our decarbonization efforts. The key to the cost competitiveness of green hydrogen is the convergence of elements like technological breakthroughs, scale of demand and supportive mandates. Currently, conventional hydrogen produced through steam methane reforming costs $1.50-$2/kg, whereas green hydrogen costs range from $2.50-$4/kg. The rapid adoption of green hydrogen [or ammonia] in countries and regions such as Japan and Europe can help reduce costs. Also, increased solar energy generation and integration with large grids could cut the production cost of green hydrogen. We are hopeful that green hydrogen costs will be competitive compared with conventional hydrogen costs sooner rather than later. India's economic growth continues to drive robust diesel and industrial fuel consumption. How does Reliance balance supplying a fast-growing, price-sensitive domestic market against high-premium opportunities in international export markets? Serving India's fast-expanding domestic market is a core operational priority, and our dual-refinery setup provides the perfect structural blueprint to achieve this. Exports are done after meeting domestic demand. As both refineries share a world-class infrastructure base, we are able to shift marginal volumes dynamically as local demand patterns shift seasonally. This interview has been edited for clarity and length. It first appeared in the September 2026 edition of Insights Magazine. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/agriculture/092426-petrobras-saf-plant-delays-deepen-as-brazils-2027-mandate-looms</link><description>Petrobras is set to delay the start-up of all three of its dedicated sustainable aviation fuel plants by one year, pushing back a combined capacity of 45,000 barrels/day as Brazil&amp;apos;s state oil company prepares a revised five-year business plan and with less than four months before the country&amp;apos;s first binding SAF emissions targets take effect. The delays, disclosed by Petrobras Director of</description><title>Petrobras SAF plant delays deepen as Brazil&amp;apos;s 2027 mandate looms</title><pubDate>24 September 2026 19:26:29 GMT</pubDate><author><name>Samyak Pandey</name></author><content><![CDATA[ Agriculture, Energy Transition, Refined Products, Biofuels, Renewables, Emissions, Vegetable Oils, Oilseeds, Jet Fuel September 24, 2026 Petrobras SAF plant delays deepen as Brazil's 2027 mandate looms By Samyak Pandey Editor: Meghan Gordon Getting your Trinity Audio player ready... HIGHLIGHTS Petrobras pushes SAF plants back one year Co-processing at refineries fills supply gap Brazil mandates 1% emissions cut starting 2027 Petrobras is set to delay the start-up of all three of its dedicated sustainable aviation fuel plants by one year, pushing back a combined capacity of 45,000 barrels/day as Brazil's state oil company prepares a revised five-year business plan and with less than four months before the country's first binding SAF emissions targets take effect. The delays, disclosed by Petrobras Director of Industrial Processes and Products William FranÃ§a during the ROG.e oil and gas congress in Rio de Janeiro, shift the timeline for dedicated SAF production from 2029-30 to 2030-31, according to multiple local media reports on Sept. 24. The postponements come as Petrobras enters the final stretch of preparations for its new 2027-2031 business plan, due to be announced at year-end, and could affect the pace at which Brazilian SAF supply enters global aviation fuel trade flows at a moment when both domestic and international compliance clocks are running. Co-processing bridges gap Despite delays to dedicated units, Petrobras said it is making parallel progress on SAF production through co-processing of renewable feedstocks at existing refineries, a route that could partially offset the supply gap created by the postponements. Co-processing is already operational at the Duque de Caxias Refinery, known as Reduc, in Rio de Janeiro state, the first Petrobras unit to receive ICAO ISCC-CORSIA sustainability certification for coprocessed SAF, having delivered its first 3,000 cubic meter batch to Tom Jobim International Airport. FranÃ§a said the co-processing expansion underpins Petrobras' ability to meet near-term international compliance obligations. The three dedicated SAF units facing delays represent the backbone of Petrobras' longer-term SAF ambitions. The first unit, to be built at the Presidente Bernardes Refinery in CubatÃ£o, SÃ£o Paulo, carries a capacity of 16,000 b/d and will now start operations in 2030 rather than 2029. The Boaventura Complex in ItaboraÃ­, Rio de Janeiro the largest of the three at 19,000 b/d and the Replan unit in PaulÃ­nia at 10,000 b/d have both been rescheduled to begin operations in 2031, slipping from an earlier target of 2030. The delays put pressure on Brazil's emerging SAF supply architecture at a critical juncture. Brazil's National Civil Aviation Agency, known as ANAC, opened a public consultation for the National Sustainable Aviation Fuel Program, known as ProBioQAV. The ProBioQAV program, established under the Fuel of the Future Law requires airlines operating domestic flights to reduce aviation greenhouse gas emissions by 1% in 2027 through SAF use, rising progressively in subsequent years. Mandate, market architecture The regulatory timeline is tight as significant market questions remain unresolved with the mandate less than five months away, including how Brazil's domestic certification system will interact with CORSIA, whose mandatory phase also begins in 2027. The decree allows producers to certify SAF either through the national system to be developed by Brazil's National Agency of Petroleum, Natural Gas and Biofuels, known as ANP, or under CORSIA-approved schemes, but does not establish whether Brazilian Sustainable Aviation Fuel Certificates, known as CS-SAF, will support CORSIA Eligible Fuel claims, creating potential uncertainty for airlines with both domestic and international compliance obligations. The decree's inclusion of a book-and-claim structure has introduced a new pricing dynamic that market participants are still assessing. Under the framework, CS-SAF certificates can be traded independently from the physical fuel until retirement, potentially allowing physical SAF to be supplied where logistics are most efficient while airlines acquire certificates separately. Brazil's government has moved to support demand-side uptake. The Management Committee of the National Civil Aviation Fund approved Real 13.56 billion ($2.4 billion) in financing for domestic airlines with a portion specifically earmarked for purchases of SAF produced in Brazil. Petrobras also completed the sale of 3.8 million liters of SAF produced with certified soybean oil supplied by agricultural trader Bunge to distributor Vibra, marking the world's first commercial batch of SAF made from soybeans carrying CORSIA Low ILUC Risk certification. The fuel was produced at Reduc with 1% renewable content and distributed through Vibra's BR Aviation unit at GaleÃ£o International Airport. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/092526-senegal-switzerland-authorize-article-62-carbon-credits-from-ev-project</link><description>Senegal and Switzerland have authorized the first carbon credits under their bilateral Article 6.2 agreement, backing a program to replace Dakar&amp;apos;s aging diesel taxi fleet with electric vehicles in a deal that advances both countries&amp;apos; climate targets while opening a new front in Africa&amp;apos;s quest to scale its carbon markets. The Senegal Mass Car Electrification program, developed by Motion Energy</description><title>Senegal, Switzerland authorize Article 6.2 carbon credits from EV project</title><pubDate>25 September 2026 14:10:57 GMT</pubDate><author><name>Eklavya Gupte</name></author><content><![CDATA[ Energy Transition, Refined Products, Crude Oil, Carbon, Emissions, Diesel-Gasoil, Gasoline September 25, 2026 Senegal, Switzerland authorize Article 6.2 carbon credits from EV project By Eklavya Gupte Editor: Anoop Menon Getting your Trinity Audio player ready... HIGHLIGHTS Dakar EV taxi fleet targets reduction of 175,993 mtCO2e KliK Foundation to buy credits on behalf of Switzerland Switzerland cements position as Article 6.2 pioneer Senegal and Switzerland have authorized the first carbon credits under their bilateral Article 6.2 agreement, backing a program to replace Dakar's aging diesel taxi fleet with electric vehicles in a deal that advances both countries' climate targets while opening a new front in Africa's quest to scale its carbon markets. The Senegal Mass Car Electrification program, developed by Motion Energy Group, implemented by Mbay Mobility and supported by Switzerland's KliK Foundation, will generate Internationally Transferred Mitigation Outcomes that Switzerland will count toward its Nationally Determined Contribution under the Paris Agreement, the companies and countries said in a statement Sept. 25. The authorization marks Senegal's first mitigation activity under Article 6, positioning the West African country alongside Ghana as one of the continent's most active host countries. ITMO volumes The project, which runs from August 2024 to the end of 2030, is expected to yield total emission reductions of 175,993 metric tons of CO2 equivalent, all of which will be converted into tradeable ITMOs, according to official documents. Just eight battery electric vehicles were active in 2024, generating a modest 8 mtCO2e, but the fleet is projected to grow to over 6,000 BEVs by 2030, producing 72,279 mtCO2e in that year alone. "Climate action is of great importance in Senegal, and the international carbon market mechanism is seen as a great opportunity to mobilize investment and accelerate the implementation of transformative and innovative mitigation activities," Papa Lamine Diouf, Head of Mitigation and Carbon Market Division at Senegal's Directorate for Climate Change, Ecological Transition and Green Finance, said. Senegal is almost entirely reliant on oil, namely diesel and gasoline, for its transport fuels, with transport emissions growing by 50% between 2011 and 2021, according to the International Energy Agency. The project targets this high-use, high-emission segment directly, combining EV imports with a fintech-enabled lease-to-own financing model designed to overcome the barriers that have historically made EVs prohibitive in Senegal. "Carbon finance under Article 6 has made this possible, and we see it as the foundation for electrifying transport right across the region," Ben Cavanagh, Director at Motion Energy Group, said. Article 6 trade Article 6 of the Paris Agreement enables countries to transfer carbon credits earned from eligible domestic projects to other countries, helping them meet their climate targets. Under Article 6.2, countries can transfer emission reductions that count toward their domestic climate targets or sell them to other countries for use toward their own Nationally Determined Contributions. The KliK Foundation has emerged as one of the most active buyers of Article 6.2 ITMOs globally. The foundation has previously backed electric bus programmes in Bangkok and clean cooking projects in Ghana, with Switzerland establishing itself as a pioneer in operationalizing bilateral Article 6 agreements. Switzerland has established itself as a pioneer in operationalizing Article 6 globally, having forged a comprehensive network of bilateral agreements, implementation deals, letters of intent, and memorandums of understanding with multiple host countries. More than 110 bilateral deals have been signed under Article 6.2, according to data compiled by S&amp;P Global and the UN Environment Program, though activity has been slow to scale. The first batch of Article 6.2 certified electric vehicle ITMOs traded at around $12-$13/mtCO2e in January 2024, sources told Platts, part of S&amp;P Global Energy. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/092526-interview-eex-calls-for-clear-roadmap-regulatory-stability-on-go-temporal-matching</link><description>A clear roadmap and greater regulatory predictability are needed before the Guarantees of Origin market moves toward tighter temporal matching requirements, according to Aude Filippi, Director of Business Development for Gas and Sustainability Markets at the European Energy Exchange (EEX). Market participants need clarity on when new requirements will be implemented and how the transition will</description><title>INTERVIEW: EEX calls for clear roadmap, regulatory stability on GO temporal matching</title><pubDate>25 September 2026 14:51:26 GMT</pubDate><author><name>Juliet Stevenson Brown</name></author><content><![CDATA[ Natural Gas, Energy Transition, Electric Power, Emissions, Renewables September 25, 2026 INTERVIEW: EEX calls for clear roadmap, regulatory stability on GO temporal matching By Juliet Stevenson Brown Editor: Anoop Menon Getting your Trinity Audio player ready... HIGHLIGHTS Market should not move âtoo quicklyâ toward granular matching Strict annual matching possible, monthly matching feasible Gas GO market fragmented and in need of further standardization A clear roadmap and greater regulatory predictability are needed before the Guarantees of Origin market moves toward tighter temporal matching requirements, according to Aude Filippi, Director of Business Development for Gas and Sustainability Markets at the European Energy Exchange (EEX). Market participants need clarity on when new requirements will be implemented and how the transition will progress. Rules should also be subject to consultation and introduced progressively to avoid price shocks, Filippi told Platts, part of S&amp;P Global Energy, in an interview during the OMC and French GO Symposium on Sept. 17. "A clear roadmap [to granular matching] needs to be given to market participants so they know what is happening and that it won't change," Filippi said. "We need a lot of regulatory predictability â that is the most important thing." Filippi said she supported strict annual and monthly matching requirements but cautioned against moving too quickly toward more granular requirements. "I hope we won't move too quickly toward granular matching, because in the end we might lose some firms," she said. The current liquidity of the power guarantees of origin market would support strict annual matching, while monthly matching is likely feasible, as demonstrated by France. However, market participants would need time to adapt, Filippi said. "Further granularity needs to be assessed on a case-by-case basis because of the implementation efforts required," she said. When asked about the latest developments to the Greenhouse Gas Protocol, Filippi said there had been good progress toward granular matching so far. "It's good to have wider frameworks that aim at standardization. It's good that ISO and the GHG protocol are working together and are making good progress. There has been quite a lot of discussion here today on temporal matching. I support discussing this, as it is a crucial question. What we need is clarity - when will this be implemented and how will it progress? I hope the standards can help there," she said. "I hope we end with a good framework that takes into account everyone's constraints," she added. Any restrictions on the demand side could affect GO prices, making market visibility and a gradual transition particularly important, Filippi said. "If there is a bit more restriction on the demand side, it could impact prices. But this is why we need visibility in the market so there is a smooth transition with no price shocks when rules are changed. Any rules need to be consulted on and implemented progressively." The commoditization of the GO Filippi described the power GO market as well-functioning, standardized, and commoditized, with reliable reference prices available. "The commoditization of the GO is a trend that is happening and is moving in the right direction. More volume is going onto the exchange, which means the prices linked to these volumes are becoming more and more reliable, helping bilateral contracts and indices," she said. French GO prices are closely correlated with the wider AIB market and move in the same direction because the French and wider European markets are completely interconnected, even with French monthly matching, she said. The French GO auction on Sept. 15 sold a total of 4.05 TWh of June 2026 electricity production at an average price of â¬1.76/MWh, about 15% higher than prices at the previous month's auction, according to EEX data published Sept. 16. Platts assessed 2026 AIB wind and solar GOs 4 euro cents/MWh higher session on session at â¬1.78/MWh on Sept. 16. As of Sept. 24, prices were hovering slightly lower at â¬1.70/MWh. Gas GO market needs standardization Looking ahead, the next stage of development for the GO market will be its expansion into other commodities, particularly gas, as the market remains fragmented and is not very standardized. As an exchange, EEX is aiming to ensure more standardization across countries so that everyone working in the industry can work more effectively, Filippi said. "How the biomethane GO evolves will be an interesting topic going forward. How will we make sure that all the systems communicate with each other, given that all these countries have different ways of dealing with this? How can we standardize this better?" she said. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/092526-ec-urges-member-states-to-adopt-delayed-hydrogen-gas-laws-after-most-miss-deadline</link><description>The European Commission has opened infringement procedures against most EU member states after all but Italy missed a deadline to adopt national laws on the hydrogen and decarbonized gas market, it said Sept. 25. Member states had until Aug. 5 to notify the EC of the full transposition of the Hydrogen and Decarbonized Gas Directive, adopted in 2024. The new directive updates the rules on the EU</description><title>EC urges member states to adopt delayed hydrogen, gas laws after most miss deadline</title><pubDate>25 September 2026 14:44:43 GMT</pubDate><author><name>James Burgess</name></author><content><![CDATA[ Energy Transition, Natural Gas, Hydrogen September 25, 2026 EC urges member states to adopt delayed hydrogen, gas laws after most miss deadline By James Burgess Editor: James Leech Getting your Trinity Audio player ready... HIGHLIGHTS Italy alone complies with gas market law deadline Commission launches infringement proceedings Hydrogen infrastructure development faces delays The European Commission has opened infringement procedures against most EU member states after all but Italy missed a deadline to adopt national laws on the hydrogen and decarbonized gas market, it said Sept. 25. Member states had until Aug. 5 to notify the EC of the full transposition of the Hydrogen and Decarbonized Gas Directive, adopted in 2024. The new directive updates the rules on the EU natural gas market, and includes a regulatory framework for dedicated hydrogen infrastructure. "The rules aim to facilitate the uptake of renewable and low-carbon gases, including hydrogen, while ensuring security of supply and affordability of energy for all EU citizens," the EC said. Industry group Hydrogen Europe said the national-level legislation was critical for building the continent's hydrogen infrastructure, and welcomed the EC's move. "Development of the European Hydrogen Backbone depends entirely on the timely transposition of the rules on the hydrogen and decarbonized gas market," Hydrogen Europe Chief Policy Officer Daniel Fraile told Platts by email on Sept. 25. "While some member states have already implemented the core rules regarding the hydrogen market, a complete and timely transposition is crucial as it provides regulatory and financial visibility for hydrogen projects." Fraile said the hydrogen industry needed the market certainty that comes with full EU-wide transposition of the relevant regulations and directives. Planned European hydrogen infrastructure is already facing delays, as a reality check in Europe's energy transition, which has stalled infrastructure projects and pushed back development timelines. First hydrogen flows on the planned European Hydrogen Backbone pipeline grid are expected from 2027 along small sections of local networks, before larger sections are connected from around the end of the decade, infrastructure developers say. EC measures To date, only Italy has notified the full transposition, leaving the EC to issue formal notices to the other 26 member states. They have two months to respond, complete the transposition and notify the commission, the EC said. The EC could issue a stronger warning, known as a "reasoned opinion," in the absence of a satisfactory response, it said. The last step of infringement procedures is a referral to the EU Court of Justice. The commission can propose that the court impose penalties, but the court would decide and establish such penalties. In 2025, the EC took similar measures against all member states apart from Denmark over the transposition of renewable hydrogen consumption laws under the Renewable Energy Directive. Platts, part of S&amp;P Global Energy, last assessed Northwest European long-term renewable hydrogen offtake prices at â¬6.60/kg ($7.53/kg) on Sept. 1. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/091626-global-ai-data-center-air-conditioning-power-demand-stalling-energy-transition-etc</link><description>Surging power demand from AI data centers and air conditioning â&amp;#x80;&amp;#x94; with much of this met by coal and gas-fired generation â&amp;#x80;&amp;#x94; has stalled the global energy transition despite clean energy deploying faster and more cheaply than anyone predicted, Energy Transitions Commission chair Adair Turner told Platts, part of S&amp;amp;P Global Energy, in an interview Sept. 14. The rapid renewables deployment was meeting</description><title>Global AI data center, air conditioning power demand stalling energy transition: ETC</title><pubDate>16 September 2026 08:01:11 GMT</pubDate><author><name>James Burgess</name></author><content><![CDATA[ Energy Transition, Coal, Natural Gas, Electric Power, Maritime &amp; Shipping, Metals &amp; Mining, Emissions, Renewables, Ferrous September 16, 2026 Global AI data center, air conditioning power demand stalling energy transition: ETC By James Burgess Editor: Adithya Ram Getting your Trinity Audio player ready... HIGHLIGHTS New structural demand delays coal phaseout Clean energy deployment fastest, cheapest ever Industrial decarbonization lagging, China leads Surging power demand from AI data centers and air conditioning â with much of this met by coal and gas-fired generation â has stalled the global energy transition despite clean energy deploying faster and more cheaply than anyone predicted, Energy Transitions Commission chair Adair Turner told Platts, part of S&amp;P Global Energy, in an interview Sept. 14. The rapid renewables deployment was meeting the previously unforeseen demand growth rather than cutting into coal burn in any serious way, Turner said. And while solar, battery, and EV costs have fallen sharply, with clean electricity growing 2.3 times faster than the overall energy supply in 2025, global emissions have only plateaued rather than fallen. "If you looked at what has happened to the price of solar photovoltaic, the price of batteries, the rate of increase of electric vehicle sales [...] all of that would make you very optimistic that we can drive a lot of this energy transition to net zero far more rapidly and cheaply than we dared dream just 10 years ago," Turner said. However, "we're not making progress at anything like the pace to meet the well below 2-degree centigrade commitment [in the UN's Paris climate commitment], let alone the 1.5 Â°C [target]," he warned. "That's the big story." The UN Environment Programme warned in a report published at the start of September that the world was set to overshoot 1.5 Â°C of warming, and that urgent action was needed to contain the climate change risk. The world remains on a trajectory of roughly 2.5 Â°C of warming by 2100 under current stated policies, according to the ETC, based on IEA data. Average warming is expected to continue to exceed 1.5 Â°C through 2030, the ETC noted, citing World Meteorological Organization projections. Fossil fuel surge The AI and cooling demand surge has directly delayed the coal and gas phase-out. In the US, data center power consumption is driving up gas burn. Globally, rising temperatures are structurally increasing air conditioning loads, creating a reinforcing cycle in which climate change itself generates new electricity demand. China's coal burn is showing signs of falling, and plants are running fewer hours, but India is lagging, Turner said. Turner noted that electricity is still only around a fifth of total final energy demand and needs to reach a third within 10 years â a target that is being made harder to hit by overall demand growth. Critically, Turner said there had been no serious decarbonization beyond the electricity sector. Heat, heavy industry, aviation, and shipping still run overwhelmingly on fossil fuels, keeping emissions stubbornly high. Turner said that because electricity is more efficient than direct combustion, with fewer conversion losses, final energy demand could still fall in absolute terms even as energy services expand. Power share The key to driving down emissions lies in the dual challenge of decarbonizing power grids and electrifying larger parts of energy demand, Turner said. The electrification of China's road transport fleet, he said, was "absolutely unstoppable," with electric vehicles accounting for large shares of both passenger and road freight fleets. The pathway would vary from country to country, with some regions having deeply decarbonized electricity systems but lagging in electricity's share of final energy demand. But there were no easy wins for the grid upgrades needed to meet growing deployment of renewables, Turner said, noting the picture would be different depending on the power mix and demand in each country or region. Turner said governments have an essential role in setting goals and enabling policies â new grid infrastructure, planning reform, and long-term offtake frameworks â citing the UK's power decarbonization program as a model. Interest rate pressure Rising real interest rates since 2019 have compounded the challenge. Green investment was once an easy win in a low-rate environment, Turner said. Now, AI borrowing for investment is driving interest rates higher still, pushing up capital costs for clean energy projects precisely when deployment needs to accelerate. Beyond the power sector, industrial decarbonization is lagging. Only 9% of the 70 near-zero steel plants needed globally by 2030 have reached final investment decision, and the US recorded zero clean industrial investment decisions in 2025, the ETC said. Turner highlighted one significant exception: a joint project between the ETC and China's iron and steel research institute examining the pathway to net zero for Chinese steelmaking. China produces 50% of global steel, Turner noted, making its decarbonization trajectory transformational for global emissions. "It can happen, and it will happen," he said. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/090726-yara-starts-up-europes-largest-co2-capture-plant-at-dutch-ammonia-site</link><description>Yara International has started carbon capture operations at its Sluiskil ammonia site in the Netherlands, it said in a statement Sept. 7, marking the start of the largest such plant in Europe. The facility is designed to capture and liquefy up to 800,000 metric tons/year of CO2 from ammonia production at the site, shielding those volumes from European carbon taxation under the EU Emissions Trading</description><title>Yara starts up Europe&amp;apos;s largest CO2 capture plant at Dutch ammonia site</title><pubDate>07 September 2026 14:55:34 GMT</pubDate><author><name>Mollie Gorman</name><name>James Burgess</name></author><content><![CDATA[ Energy Transition, Carbon, Emissions September 07, 2026 Yara starts up Europeâs largest CO2 capture plant at Dutch ammonia site By Mollie Gorman and James Burgess Editor: Karina Roman Getting your Trinity Audio player ready... HIGHLIGHTS Facility liquefies 800,000 mt CO2 annually Ships transport emissions to Norwegian seabed Northern Lights expands to 5 million mt by 2028 Yara International has started carbon capture operations at its Sluiskil ammonia site in the Netherlands, it said in a statement Sept. 7, marking the start of the largest such plant in Europe. The facility is designed to capture and liquefy up to 800,000 metric tons/year of CO2 from ammonia production at the site, shielding those volumes from European carbon taxation under the EU Emissions Trading System. Platts, part of S&amp;P Global Energy, assessed nearest December EU ETS prices at â¬84.15/mt ($97.83/mt). The project marks the first large-scale cross-border industrial CCS link in Europe, connecting Yara's Dutch production hub directly to Norway's Northern Lights permanent subsea storage infrastructure. Captured CO2 will be liquefied and temporarily stored at Sluiskil before being transported by ship to Ãygarden, Norway, where it will be injected 2,600 meters beneath the North Sea seabed. The project is expected to capture and permanently store approximately 12 million mt of CO2 over a 15-year period, Yara said. "The carbon capture facility in Sluiskil proves that large-scale industrial decarbonization is possible today," Svein Tore Holsether, President and CEO of Yara International, said. "As global competition intensifies, Europe must find ways to cut emissions while keeping industry, jobs and critical value chains in Europe." Yara said the site would enable the company to "further reduce the carbon footprint of its production and support low-carbon value chains across agriculture, industry, energy and shipping." The inauguration ceremony was attended by EU Commissioner for Climate, Net-Zero and Clean Growth, Wopke Hoekstra, Norwegian Prime Minister Jonas Gahr StÃ¸re, Dutch Prime Minister Rob Jetten and Yara's Holsether, underscoring the strategic importance of the cross-border project for European leaders. "Europe needs practical climate solutions that deliver real emissions reductions while strengthening industrial competitiveness," Hoekstra said in a statement Sept. 7. "This is exactly the kind of project Europe needs to combine climate ambition with a strong and resilient industrial base." Northern Lights expansion The 1.5 million mt/year Northern Lights CO2 storage facility in the Norwegian North Sea started commercial operations in 2025, with first supplies from Heidelberg Materials Brevik cement plant. Heidelberg will supply 400,000 mt/year of CO2 to Northern Lights. The facility is expected to start receiving further volumes from Ãrsted A/S later in 2026. Ãrsted has an agreement with Northern Lights to supply 430,000 mt/year from its Asnaes and Avedore biomass power stations in Denmark. Northern Lights said it would further expand its transport capacity for the second phase of the project â including the addition of larger CO2 tankers from 2028 â which expands capacity to 5 million mt/year. Stockholm Exergi AB in Sweden and Hafslund Celsio in Norway will supply additional volumes from 2028 and 2029. Northern Lights is a joint venture between Equinor ASA, TotalEnergies SE and Shell PLC. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/crude-oil/092326-diesel-export-ban-would-send-shockwaves-through-us-refining-system</link><description>A potential US ban on diesel exports might initially appear to be a straightforward way to increase domestic supply and lower prices, but the reality is far more complicated, analysts and industry watchers agree. While the concept of a US diesel export ban has been floated over the past few weeks amid record high prices, President Trump&amp;apos;s Sept. 22 statement that &amp;quot;let&amp;apos;s not send out the diesel&amp;quot;</description><title>Diesel export ban would send shockwaves through US refining system</title><pubDate>23 September 2026 12:21:13 GMT</pubDate><author><name>Janet McGurty</name></author><content><![CDATA[ Refined Products, Energy Transition, Agriculture, Crude Oil, LNG, Diesel-Gasoil, Gasoline, Jet Fuel, Renewables, Biofuels September 23, 2026 Diesel export ban would send shockwaves through US refining system By Janet McGurty Editor: Alisdair Bowles Getting your Trinity Audio player ready... HIGHLIGHTS US refiners face 1.9M b/d crude run cuts Export ban strands 1.5M b/d diesel domestically Global prices surge as supply tightens abroad A potential US ban on diesel exports might initially appear to be a straightforward way to increase domestic supply and lower prices, but the reality is far more complicated, analysts and industry watchers agree. While the concept of a US diesel export ban has been floated over the past few weeks amid record high prices, President Trump's Sept. 22 statement that "let's not send out the diesel" brought it closer to reality. The proposal comes as diesel markets are under extraordinary stress, but it would not necessarily be a quick fix for domestic diesel prices ahead of November's upcoming midterm elections. "The US is not short of diesel. The world is. The US is a structural diesel surplus producer. Refineries in the US produce roughly 5.3 million barrels of distillates per day against demand of around 3.6 million barrels per day domestically," said Patrick De Haan, head petroleum economist at GasBuddy, on Sept. 22. Because US refineries operate as part of a globally integrated fuels system, removing diesel exports would trigger a chain reaction across refinery operations, product markets, renewable fuels and international trade flows, S&amp;P Global analysts noted. A proposed ban on US diesel exports could strand up to 1.5 million barrels per day of fuel in the domestic market, triggering refinery run cuts on a scale not seen since the early months of the COVID-19 pandemic and sending global diesel prices sharply higher, they said. The warning comes as diesel crack spreads hover at record or near-record levels, driven by refinery outages in the Middle East and Russia, lower Chinese exports and seasonally tight inventories â conditions that have already boosted profits for Gulf Coast refiners while raising fuel costs for truckers, farmers and industrial users. The unplanned outage at ExxonMobil's Joliet refinery has amplified those pressures in Midwest markets just as the harvest season gets underway, illustrating how little buffer remains in a system running at near-100% utilization. Impact on US Gulf Coast refiners Gulf Coast refiners â including Valero, Marathon Petroleum, Phillips 66, ExxonMobil, Chevron and Motiva â depend on foreign markets to absorb excess diesel output. S&amp;P Global analysts Will O'Neil, Debnil Chowdhury and Brian Stetter estimated in a Sept. 22 note that removing export outlets would strand roughly 1.5 million b/d of diesel domestically, rapidly collapsing margins and crack spreads. Chowdhury compared the potential shock to the demand collapse refiners experienced at the start of the coronavirus pandemic. "You have to think of exports as demand," Chowdhury said, warning that Brazil, Mexico and Europe would all face reduced access to US diesel supplies. S&amp;P Global estimates refiners would ultimately need to cut crude runs by nearly 1.9 million b/d, or roughly 12%, to eliminate the surplus, pushing utilization toward 80%-82%. Because a refinery cannot stop making diesel while maintaining gasoline output, lower crude throughput would also reduce gasoline, jet fuel and petrochemical feedstock production. S&amp;P Global estimates the United States could shift from being a net gasoline exporter to a slight net importer. The Platts USGC ULSD prompt pipeline crack averaged $104.66/b on Sept. 22, just below the record $105.42/b on Sept. 15. While far overshadowed by diesel's strength, USGC CBOB gasoline cracks are also rising, reaching $34.53/b on Sept. 22, and are likely to go higher if USGC run cuts go into effect. Platts is a unit of S&amp;P Global. With crack spreads potentially elevated into 2027, Jefferies analyst Lloyd Byrne on Sept. 22 downgraded Valero and Marathon Petroleum to Hold, citing a potential export ban as one of the two biggest threats to the current refining cycle, alongside demand destruction. Pipeline infrastructure offers only partial relief to at-risk regions like the US Atlantic Coast although the expansion of the Laurel Pipe Line could help increase supplies. "Between Colonial, Plantation and Laurel, you could probably backfill East Coast diesel imports, especially with a Jones Act waiver. The problem is that 100,000 to 200,000 b/d is a drop in the bucket compared with a 1.5 million b/d diesel surplus," O'Neil said Sept. 22. Risky business for renewables The renewable fuels sector also sees risks. Renewable Fuels Association CEO Geoff Cooper said waiving the Renewable Volume Obligation would reduce supply in an already tight market. "Waiving the RVO would most definitely not result in lower fuel prices," Cooper said on Sept. 22, noting that biomass-based diesel contributes roughly 400,000 b/d and ethanol more than 1 million b/d to overall supply. S&amp;P Global's O'Neil said a ban would create sharply divergent outcomes within renewables. "If you're a Gulf Coast renewable diesel producer with access to export markets, your margins are going to be great because the rest of the world loses 1.5 million barrels a day of diesel and prices skyrocket," O'Neil said. Biodiesel producers without export access would face deteriorating margins competing against discounted stranded petroleum diesel. O'Neil also warned the disruption could trigger "massive noncompliance" with the Renewable Fuel Standard, sending RIN prices and gasoline costs higher. Politics ahead of midterms Not all analysts foresee deep run cuts. Economist Philip Verleger argues refiners could adapt by switching from heavier Canadian and Venezuelan crudes toward lighter grades such as WTI, reducing diesel yields without large throughput reductions. Verleger nonetheless opposes a ban, warning it would damage US credibility as a reliable supplier of crude, refined products and LNG as well as do little to lower the price of gasoline â a key and more direct metric felt among voting consumers. "While diesel is the headliner today, it has been my experience that when it comes to elections, the price of gasoline impacts the consumer much more directly than the price of diesel," Verleger said in a Sept. 22 email to Platts. He noted that although diesel costs are embedded throughout the economy, their impact on consumers is largely indirect, a sentiment echoed by GasBuddy's De Haan. "Diesel may be driving today's energy debate, but gasoline remains the fuel that most directly influences voter sentiment. Consumers don't closely track diesel futures or wholesale markets, but they notice every penny change at the gas pump, which is why gasoline prices often become a bigger political issue than diesel prices during election years," said De Haan. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/refined-products/092426-interview-dhl-sees-sharp-saf-price-gap-between-voluntary-and-compliance-markets</link><description>Europe&amp;apos;s sustainable aviation fuel mandate has resulted in a two-tier market, with compliance markets commanding a significant premium, an official at DHL told Platts Sept. 24. The compliance cost passed through by fuel suppliers under the EU&amp;apos;s SAF mandate is running at two to three times the price achievable in the voluntary market â&amp;#x80;&amp;#x94; sometimes at the same airport and from the same supplier, Tim</description><title>INTERVIEW: DHL sees sharp SAF price gap between voluntary and compliance markets</title><pubDate>24 September 2026 16:57:16 GMT</pubDate><author><name>Thomas Washington</name></author><content><![CDATA[ Agriculture, Refined Products, Energy Transition, Biofuels, Jet Fuel, Renewables September 24, 2026 INTERVIEW: DHL sees sharp SAF price gap between voluntary and compliance markets By Thomas Washington Editor: Juan Tolentino Getting your Trinity Audio player ready... HIGHLIGHTS Compliance SAF costs 2-3x voluntary market prices: DHL California leads on incentives, Asia lacks policy support Book-and-claim credibility key to scaling SAF demand Europe's sustainable aviation fuel mandate has resulted in a two-tier market, with compliance markets commanding a significant premium, an official at DHL told Platts Sept. 24. The compliance cost passed through by fuel suppliers under the EU's SAF mandate is running at two to three times the price achievable in the voluntary market â sometimes at the same airport and from the same supplier, Tim Lederer, vice president of global aviation regulatory affairs and fuel at DHL, said in an interview. "It's not a market, you're just being hit with the price," Lederer said. "And you don't even have an option not to pay." Europe's RefuelEU Aviation regulation requires a 2% SAF blend from 2025, rising to 6% by 2030, with the compliance obligation on fuel producers rather than end users. The voluntary markets cover optional mechanisms driven by corporate sustainability commitments. Platts, part of S&amp;P Global Energy, assessed SAF, produced via the hydroprocessed esters and fatty acids pathway, on a CIF basis in Northwest Europe, at $2,922.75/metric ton Sept. 23, 85% costlier than $1,576/mt for jet fuel cargoes on an equivalent basis. Regional divergence Pricing also varies across regions. The US â and California in particular â is the most competitively priced SAF market globally, driven by state and federal incentive frameworks, Lederer said. Europe sits in the middle of the global price range, partly cushioned by emissions trading system allowances that reduce net SAF costs. Asia is currently the most expensive region, despite rising production, due to an almost complete absence of policy incentives, Lederer said. Platts assessed HEFA SAF on a FOB basis at Singapore at $2,465/mt Sept. 23, compared to $2,908/mt for SAF on an equivalent basis at Flushing-Amsterdam-Rotterdam-Antwerp-Ghent and 1,066.137 cents/gal in California, equivalent to $3,706/mt. "European SAF and Asian SAF and US SAF, whilst it's all the same product, at the moment it comes at a very different price point in the market," Lederer said. "And that tells you something about regional scalability." China is rapidly expanding SAF production capacity, but cautioned that volume and competitive pricing are not the same thing without demand-side policy support, Lederer said. Global SAF demand is forecast to reach 66,000 b/d or 2.79 million mt in 2026 and 3.62 million 2027, driven by higher demand in the UK and Asia, analysts at S&amp;P Global Energy Horizons said Sept. 7. Amid this, Europe leads consumption at a forecast 1.518 million mt in 2026, with the US at 844,000 mt and the rest of the world at 427,500 mt, according to data from Energy Horizons. On the production side, European output in 2026 will be 564,000 mt in 2026, US output will be 828,000 mt, with China and Singapore combined at 1.173 million mt, Energy Horizons said. Beyond mandates DHL's own procurement figures illustrate how far the company has moved beyond mandate-driven purchasing. DHL procured 185,000 mt of SAF for its Scope 1 emissions in full-year 2025, with 97% sourced through voluntary agreements, Lederer said. The company achieved a 10% SAF sub-blend rate â a figure Lederer described as industry-leading. Industrywide, SAF production is expected to reach around 2.4 million tonnes in 2026, representing just 0.8% of aviation fuel use, the International Air Transport Association said June 6. DHL holds active SAF supply agreements at 19 airports globally. Fixed-price contract structures have largely insulated the company from the jet fuel price volatility seen elsewhere, while HEFA-pathway SAF prices have trended downward over the past three years as supply availability has grown, Lederer said. On power-to-liquid fuels, which face a dedicated EU sub-mandate from 2030, there is scope for caution, Lederer said. Insufficient projects had reached financial close to give confidence that the target could be met, he said. DHL's customer-facing GoGreen Plus product, which allows shippers to co-fund SAF procurement on a book-and-claim basis, now has approximately 570,000 active subscribers, Lederer said. Every euro generated is reinvested into additional SAF purchases, providing certified Scope 3 emissions reductions to corporate customers, he said. Full recognition of book-and-claim under the Greenhouse Gas Protocol remains outstanding, but registry-based systems â including ISCC, Avelia and RSB â provide sufficient credibility to scale now, Lederer said. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/metals/092426-european-recyclers-to-fight-proposed-eu-metal-waste-export-ban-cma</link><description>The Circular Metal Association â&amp;#x80;&amp;#x94; which represents metal recyclers in Europe and Germany â&amp;#x80;&amp;#x94; said the European Commission was treating recycled metals differently from other waste streams and that it intended to fight proposed export restrictions, according to a statement emailed to Platts Sept. 24. The draft delegated act under the Waste Shipment Regulation, published by the European Commission</description><title>European recyclers to fight proposed EU metal waste export ban: CMA</title><pubDate>24 September 2026 17:45:24 GMT</pubDate><author><name>Katya Bouckley</name></author><content><![CDATA[ Metals &amp; Mining, Energy Transition, Non-Ferrous, Ferrous, Renewables September 24, 2026 European recyclers to fight proposed EU metal waste export ban: CMA By Katya Bouckley Editor: Juan Tolentino Getting your Trinity Audio player ready... HIGHLIGHTS Recyclers challenge EU metal waste export rules Rules put 4 million mt of steel scrap at risk India, Egypt, Pakistan risk losing EU scrap supplies The Circular Metal Association â which represents metal recyclers in Europe and Germany â said the European Commission was treating recycled metals differently from other waste streams and that it intended to fight proposed export restrictions, according to a statement emailed to Platts Sept. 24. The draft delegated act under the Waste Shipment Regulation, published by the European Commission Sept. 18, will cut the majority of non-OECD countries off EU supplies of recycled steel and nonferrous metals from May 21, 2027. The commission is looking to reduce EU annual exports of steel scrap by 4 million-4.1 million metric tons, or 25%-26%, and of aluminum scrap by 76% or 970,600 mt, with the volumes equivalent to shipments in 2025 to non-OECD countries that it does not want to authorize to receive European metal waste. India, Egypt, Pakistan, China, Thailand and Morocco would be among the countries most affected by the respective restrictions. The Waste Shipment Regulation states that non-hazardous waste may be exported for recovery to non-OECD countries that have demonstrated they treat such waste in an environmentally sound manner. But "the Commission applies a significantly stricter standard to recycled metals than to other types of waste," says CMA President Murat Bayram. It assumes from the outset that recycled metals pose higher environmental and health risks than many other waste streams on the grounds that they may contain toxic heavy metals and are not biodegradable. "Here, a single group of materials is being prejudged across the board, without any factual basis. The result is an export ban on the most important sales markets," Bayram said. The association is calling on the commission to abandon the special criteria for metals and instead to apply the procedure set out in the Waste Shipment Regulation, under which treatment processes in the recipient country are assessed to determine whether exports there should continue. "Closing off international markets creates neither additional demand nor greater competitiveness in Europe," Bayram said. "If European metal producers do not take up the available volumes, sales markets will disappear, material values will come under pressure and surpluses will grow." Raw-material export restrictions reach record high The association's view echoes that of broader German industries. In its September recommendations to the EU and German governments, the German Chamber of Commerce and Industry, or DIHK, said that export restrictions on critical raw materials globally have reached a historic high, increasing fivefold since 2009. Governments increasingly use them as industrial policy tools, while shifting from duties and quotas toward more aggressive measures; as a result, bans accounted for 25% of all new export restrictions in 2024. Waste and scrap have become the most restricted categories of critical raw materials, driven by environmental and circular economy goals, the DIHK notes. However, the organization representing three million companies in Germany argues that export restrictions are not sustainable tools for securing raw materials: they distort business relationships, reduce sales opportunities for European scrap suppliers, and routinely trigger retaliatory trade measures. "If the EU begins to withhold secondary raw materials, other states might restrict their exports ... even more heavily. This would further fragment global raw material markets and exacerbate trade conflicts," the DIHK says. It adds that mandatory recycled-content quotas, for example, in batteries, can only be achieved through free and global trade in secondary raw materials. The majority of the German business community believes export barriers on waste and scrap should only ever be used as an absolute last resort, if strategic material streams are flowing out in significant volumes, posing a severe risk to domestic supply. If the EU implements restrictions for economic security, they must be highly targeted, time-limited and regularly evaluated, the DIHK said and recommended alternatives. The EU should negotiate binding provisions against export barriers in its bilateral trade deals, dismantle discriminatory dual-pricing mechanisms used by some countries, including Chile and Mercosur, and proactively initiate WTO dispute proceedings against unfair trade barriers, mirroring successful cases against China and Indonesia. Instead of turning protectionist, the EU government should focus on making Europe an attractive location for recycling and reprocessing, in which secondary raw materials are highly competitive with primary raw materials. To achieve that, the EU needs to slash bureaucracy, fast-track permits for processing plants, clarify confusing legal definitions regarding waste versus product and by-product status, and invest in research to boost resource efficiency, the DIHK says. The potential of industrial symbioses should also be given greater consideration, as inter-company utilization of by-products and residual materials can unlock additional sources of raw materials, according to the DIHK. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/092426-carbon-market-volatility-surges-as-ai-policy-shifts-reshape-us-canada-pricing</link><description>Compliance carbon markets across the US and Canada are facing a wave of volatility and structural change, as panelists at the International Emissions Trading Association&amp;apos;s North America Climate Summit pointed to the disruptive impacts of AI-driven electricity demand, regulatory reforms, and the uncertain pace of industrial decarbonization. The Regional Greenhouse Gas Initiative, the oldest</description><title>Carbon market volatility surges as AI, policy shifts reshape US, Canada pricing</title><pubDate>24 September 2026 21:32:11 GMT</pubDate><author><name>Lassana Fisiru</name></author><content><![CDATA[ Electric Power, Natural Gas, Energy Transition, Carbon, Emissions September 24, 2026 Carbon market volatility surges as AI, policy shifts reshape US, Canada pricing By Lassana Fisiru Editor: Kassia Micek Getting your Trinity Audio player ready... HIGHLIGHTS AI demand spikes electricity use, drives up RGGI prices Washington state market awaits California decision Alberta faces credit oversupply, regulatory uncertainty Compliance carbon markets across the US and Canada are facing a wave of volatility and structural change, as panelists at the International Emissions Trading Association's North America Climate Summit pointed to the disruptive impacts of AI-driven electricity demand, regulatory reforms, and the uncertain pace of industrial decarbonization. The Regional Greenhouse Gas Initiative, the oldest multi-state US carbon market, is seeing unprecedented price action. "RGGI prices are now higher than ever, with the most recent auction clearing at $38 per short ton, four times the price five years ago," Bo Qin, head of environmental markets at BloombergNEF said during the Sept. 22 panel discussion. Qin attributed much of the recent volatility to a surge in electricity demand driven by AI and data centers, as well as broader electrification trends. BloombergNEF revised its demand outlook upward, and is now projecting a 12% increase in demand by 2035, compared to prior expectations of a 40% decline. "This is a big adjustment, hugely contributed to revised demand forecasts for AI and data centers," Qin said. Price forecasts now point to an average of $39/st this year, rising to $121/st by 2035 if current trends persist. Platts assessed the RGGI current-month strip at $38.31/allowance on Sept. 24, the next-month strip at $38.45/alw, and the next-December strip at $38.73/alw, climbing $1.05/alw over the day. Platts is part of S&amp;P Global Energy. Washington's eyes convergence with California The Washington state carbon market, modeled closely on California's cap-and-trade system, has experienced price swings since its launch, with allowances trading at the highest levels globally through 2025. "Linkage with California is now the main dynamic," Alex Rau of Environmental Commodity Partners said. "If linkage happens, Washington prices should converge to California's, given the larger surplus and longer history in the latter market. If not, we're headed back to ceiling levels." The market remains illiquid due to persistent binary risk, uncertainty over linkage timing and potential program repeal. "You don't see a lot of trading in Washington. It's a struggle because liquidity is just not there, and options don't trade with any material size," Rau said. California-Quebec system remains 'gold standard' California and Quebec's linked market, often cited as the "gold standard" for subnational carbon trading, is at a turning point. "California has achieved the rare feat of delinking emissions from GDP growth," Mitul Kaushal, engagement manager at cCarbon, said. However, panelists noted that current allowance prices remain subdued, with emissions persistently below the cap due to a combination of weather-driven abatement, refinery shutdowns and natural gas sector reductions. "We are at the cusp of a significant uptick in prices," Kaushal said, pointing to expectations of a major drawdown in the compliance bank by 2027 as easy abatement options are exhausted. "Long-term signals remain bullish, with our models showing potential for prices to reach $120/ton by 2030." Platts assessed the CCA current-month strip at $31.38/alw on Sept. 24, the next-month strip at $31.53/alw, and the next-December strip at $31.83/alw, rising 42 cents/alw on the day. Alberta TIER faces oversupply, regulatory uncertainty Unlike its US counterparts, Alberta's carbon market operates on an intensity-based benchmark rather than a cap-and-trade framework. Despite a nominal compliance price of $C95/ton, credits in the over-the-counter market trade much lower due to surplus supply and regulatory ambiguity. "Alberta is oversupplied, and there's still a lot of uncertainty about how the new price floor and harmonization with federal standards will play out," Jennifer McIsaac, chief market intelligence officer at ClearBlue Markets, said. The market's trajectory will depend heavily on the fate of major CCS projects and the enforcement of new credit price floors under an evolving Canada-Alberta memorandum of understanding. Platts assessed EPCs and AEOs at C$27/metric ton of CO2 equivalent on Sept. 24, holding firm over the day. Panelists discussed the impact of new mechanisms like California's Manufacturing Decarbonization Initiative, and Alberta's direct investment pathways, which allow compliance entities to fund in-house emissions reductions as an alternative to market purchases. While some expressed concern that such measures could undermine cap integrity by introducing new free allocation pots, others argued that uptake will be gradual and back-loaded, limiting immediate market impacts. "There's a long way to go before a lot of allowances come into the market," Kaushal said, citing polling data that suggests most entities will wait for regulatory clarity before participating. Implementation details and transparency requirements remain unresolved, with legislative proposals to pause or amend the MDI still under discussion, McIsaac added. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/092126-hcee-india-2026-renewable-hydrogen-industry-shifts-focus-to-final-investment-construction</link><description>As India enters the next phase of its clean energy transition, the industry will look for evidence that policy support, production incentives and investment commitments are translating into projects reaching final investment decisions and moving into construction. Policymakers and industry leaders will deliberate on the next steps for India&amp;apos;s clean energy development, targeting a commercial stage</description><title>HCEE India 2026: Renewable hydrogen industry shifts focus to final investment, construction</title><pubDate>21 September 2026 18:53:33 GMT</pubDate><author><name>Ruchira Singh</name></author><content><![CDATA[ Energy Transition, Chemicals, Metals &amp; Mining, Hydrogen, Renewables, Carbon, Ferrous September 21, 2026 HCEE India 2026: Renewable hydrogen industry shifts focus to final investment, construction By Ruchira Singh Editor: Benjamin Morse Getting your Trinity Audio player ready... HIGHLIGHTS Most India renewable hydrogen projects in early stage Industries want renewable hydrogen at $1.5-1.75/kg Methanol bunkering tested; hubs, ports in focus As India enters the next phase of its clean energy transition, the industry will look for evidence that policy support, production incentives and investment commitments are translating into projects reaching final investment decisions and moving into construction. Policymakers and industry leaders will deliberate on the next steps for India's clean energy development, targeting a commercial stage by 2028-2030, at S&amp;P Global Energy's Horizons Clean Energy Expansion India Conference 2026, to be held Sept. 24-25 in New Delhi. India launched a 174.90 billion rupees ($2.10 billion) Strategic Interventions for Green Hydrogen Transition (SIGHT) scheme in 2023 and has since conducted multiple auctions to support the production of renewable hydrogen, electrolyzers and renewable ammonia. "The support on offer under the SIGHT hydrogen auctions offered some of the lowest subsidy levels of any global hydrogen revenue support scheme," said Matthew Hodgkinson, senior principal analyst for hydrogen at S&amp;P Global Energy. The industry will be interested in "seeing how long it takes these projects to reach FID and how much state support they require, if any." The National Green Hydrogen Mission targets producing 5 million metric tons of renewable hydrogen by 2030 and aims to position India as a major participant in global renewable hydrogen trade. Industry and government sources say the global slowdown and geopolitical issues may delay it. Trade participants are also expected to discuss the challenges facing project implementation and call for stronger policy support and faster infrastructure development, industry members said. Renewable ammonia advances Despite the challenging global environment for clean fuels, Indian developers are eyeing fresh rounds of tenders from Solar Energy Corp. of India amid a push to produce hydrogen derivatives. "The first round of tenders under the production incentive scheme was more of a price discovery," Sanjay Nagrare, president, Ocior Energy Holding Ltd., a renewable hydrogen developer in India, told Platts, a part of S&amp;P Global Energy. Following disruptions to conventional fuel supplies, the drive for energy security has prompted traditional sectors to view renewable fuels "in a slightly more serious manner." According to Nagrare, the market can expand through additional renewable ammonia tenders, the introduction of green urea, and greater use of renewable hydrogen in refineries. The drive toward energy security has improved India's prospects for adopting renewable ammonia as an import substitution to save foreign exchange. "India is highly competitive on the international market for exporting renewable ammonia," Hodgkinson said. "However, geopolitical issues in 2026 have pushed energy and supply security to the top of the agenda, increasing the likelihood of domestically produced renewable ammonia being used to displace incumbent gray ammonia imports." Hard-to-abate sector eyes low-cost H2 India's hard-to-abate industries will be in the spotlight as companies assess the deployment of emissions-reduction technologies and prepare to participate in the country's emerging compliance carbon market. Industry participants will be closely watching how sectors such as steel, fertilizers and refining are adapting their operations to align with the emerging Carbon Credit Trading Scheme (CCTS), which is expected to lead to carbon credits trading in the compliance market by 2026/2027. The deliberations are expected to delve into the pricing of renewable hydrogen, which is the key to its adoption in the hard-to-abate sector, they said. "For green hydrogen to be viable, especially now, the delivered cost of green hydrogen has to fall between $1.5-$1.75/kg," Naveen Ahlawat, president &amp; head â sustainability &amp; decarbonization at Jindal Steel Ltd. told Platts. "At that cost level, coupled with carbon prices of around $10-$15/mt of CO2 in India and about Eur100/mt in Europe, hard-to-abate sectors would have a strong commercial case to begin transitioning to low-carbon alternatives." According to Ahlawat, renewable hydrogen could be deployed in India's blast furnaces and DRI units by retrofitting existing technology, with gas-based steel plants potentially blending up to 30% renewable hydrogen. Platts assessed the India renewable hydrogen term contract at $3.22/kg on Sept. 10, down 0.6% month over month. Ports, hubs development crucial Some of the earliest commercial opportunities for renewable fuels are emerging at ports on India's east and west coasts, which are aiming to offer renewable methanol bunkering services and facilitate renewable ammonia exports. Also, some major binding agreements, including the ACME-IHI, ACME-Mitsubishi Gas Chemical and Reliance-Samsung C&amp;T deals, now require tangible progress on infrastructure and logistics. Deendayal Port in Gujarat has tested methanol bunkering and V.O. Chidambaranar Port in Tuticorin is pursuing a similar strategy and is now exploring fuel sourcing options. "The next round is going to be more about building the market," Nagrare said. Data from S&amp;P Global Energy shows that India has a renewable hydrogen production pipeline capacity of over 6 million mt/year, of which about 112,752 mt has been financed and 11,329 mt is operational. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/092226-path-to-net-zero-sustainability-now-support-actor-in-eu-energy-security-play</link><description>This is the second in a multi-part series on net-zero efforts across industries. The first part can be found here. European utilities are now navigating a policy paradigm shift as energy security takes center stage, with market observers pointing to stronger government support to unlock further investment in renewables. Most European utilities in Platts&amp;apos; annual survey of net-zero targets held on</description><title>PATH TO NET ZERO: Sustainability now support actor in EU energy security play</title><pubDate>22 September 2026 13:45:25 GMT</pubDate><author><name>Camilla Naschert</name><name>Alex Blackburne</name></author><content><![CDATA[ Energy Transition, Emissions, Carbon, Renewables September 22, 2026 PATH TO NET ZERO: Sustainability now support actor in EU energy security play By Camilla Naschert and Alex Blackburne Editor: Bill Montgomery Getting your Trinity Audio player ready... HIGHLIGHTS Utilities seek government investment support Power demand to surge 65% by 2050 This is the second in a multi-part series on net-zero efforts across industries. The first part can be found here. European utilities are now navigating a policy paradigm shift as energy security takes center stage, with market observers pointing to stronger government support to unlock further investment in renewables. Most European utilities in Platts' annual survey of net-zero targets held on to their commitments this year. But with the European Union facing financial constraints and security imperatives, security of supply and affordability are taking priority over strict 2040 climate targets, analysts at S&amp;P Global Energy said. "My view is that Europe's trajectory is unaltered, but the packaging has moved away from sustainability to resilience and security of supply," said Coralie Laurencin, director of European gas, power and carbon policy at S&amp;P Global Energy CERA. "Since Europe has very limited oil and gas resources, the plan is to boost renewables and electrification, which will conveniently achieve sustainability as well as resilience." That said, analysts at S&amp;P Global Energy expect that Europe will not meet its emissions targets for 2030, 2040 or 2050. Still, emissions will continue to fall quickly given a profound transformation of the energy system, and by 2050 will have fallen 70% compared with 1990, Laurencin said. "It's likely the EU will be the leader or one of the leaders in emissions reduction." In July, the European Commission proposed a substantial redesign of the EU Emissions Trading System (ETS), slowing the pace of emissions reductions beyond 2030, delivering â¬6 billion in additional free permits to manufacturers, and introducing controlled access to carbon removals and international credits while deploying more than â¬100 billion toward industrial decarbonization through a new financing instrument. Electrification helps net-zero Utility executives have reflected on the political messaging in recent conversations with investors and journalists. "The energy security and affordability backdrop in Europe is stronger than I have seen at any point in time," Rasmus Errboe, CEO of Danish wind developer Ãrsted A/S, said Aug. 14. Ãrsted is set to bid in offshore wind auctions across various markets, including Germany, the Netherlands and the UK, in the coming year, the executive said. "Renewables will always be the foundation," Markus Krebber, CEO of Germany's RWE AG, told reporters at a press conference Aug. 13, when asked whether the EU policy emphasis on security of supply could delay net-zero progress. "The trend of the general electrification will actually help us" with net zero, the executive said. While electrification has been a political buzzword, tangible support from governments across Europe has been limited due to stretched fiscal resources, said Sylvain Cognet-Dauphin, executive director in the European power market analysis team at S&amp;P Global Energy. "Utilities are caught in the middle" when it comes to investments in new generation, Cognet-Dauphin said, noting that investments require higher power prices or government support. "Utilities have to navigate a very complicated policy environment â what they can do is build up their lobbying teams and tell governments, 'This is what you should be doing,'" the analyst said. "Right now, 99% of investments rely on government support." The recent hike in gas prices due to tensions in the Middle East has benefited utilities and raised most European utilities' second-quarter results, beating analyst expectations. "More money is coming in, but that doesn't mean people will invest without government support," Cognet-Dauphin added. It is also against that backdrop that many utilities are seeking further exposure to regulated markets via grid investments, a trend that is intensifying M&amp;A appetite for network assets. Still, by 2050, European renewables capacity will double from 2025 levels, analysts wrote in their European Long-Term Power Outlook report Aug. 14. Storage will play a greater role in providing grid flexibility, and wind will become the largest power source by midcentury, reflecting higher capacity factors than solar PV. Power demand outlook Analysts at S&amp;P Global Energy estimate European power demand to grow 65% by 2050. This is a correction from the researchers' December 2025 forecast, reflecting reduced expectations for industrial power demand and slower deployment of green hydrogen. Increased electrification will support growth, and data center power demand will also grow in Europe, they noted. Further upside could come from higher cooling demand in summers, should extreme heat become the norm. Power demand from data centers will grow fivefold in Europe to 2050, the analysts expect, accounting for 11% of total demand growth. The largest markets are Germany, the UK and France. Utilities like Germany's RWE are positioning themselves to capitalize on the rapid growth of AI data centers. While data center power demand, especially in the US, is outpacing renewables deployment, tech companies are holding on to their net-zero targets, RWE's Krebber said. "I need power quickly now, and then I will decarbonize later," he characterized their thinking. For tech companies looking to build data centers in Europe, there will likely be more pressure to use decarbonized electricity, Cognet-Dauphin said, adding that electricity is already about 70% decarbonized. &amp;amp;nbsp; Susan Dlin contributed to this article. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/092326-path-to-net-zero-ai-build-out-tests-tech-sectors-emissions-trajectory</link><description>This is the third in a multi-part series on net-zero efforts across industries. The previous article can be found here. The world&amp;apos;s largest technology companies continue to reach milestones in renewable energy, even as the rapid expansion of AI infrastructure drives absolute emissions higher. The race to build out AI infrastructure is in full swing, with the five major hyperscalers â&amp;#x80;&amp;#x94; Amazon.com</description><title>PATH TO NET ZERO: AI build-out tests tech sector&amp;apos;s emissions trajectory</title><pubDate>23 September 2026 13:45:02 GMT</pubDate><author><name>STEFAN MODRICH</name></author><content><![CDATA[ Energy Transition, Electric Power, Renewables, Emissions, Carbon September 23, 2026 PATH TO NET ZERO: AI build-out tests tech sector's emissions trajectory By STEFAN MODRICH Editor: Karina Roman Getting your Trinity Audio player ready... HIGHLIGHTS Tech firms boost renewables amid AI emissions surge Scope 3 supply chain emissions challenge chip makers This is the third in a multi-part series on net-zero efforts across industries. The previous article can be found here. The world's largest technology companies continue to reach milestones in renewable energy, even as the rapid expansion of AI infrastructure drives absolute emissions higher. The race to build out AI infrastructure is in full swing, with the five major hyperscalers â Amazon.com Inc., Alphabet Inc., Microsoft Corp., Meta Platforms Inc. and Oracle Corp. â having spent $1.1 trillion in capital expenditure over the past five years, according to Visible Alpha. This capex has fueled the rapid expansion of energy-intensive AI data centers, prompting hyperscalers to invest heavily in clean energy capacity â securing everything from solar and wind to geothermal, hydro and nuclear capacity â to power these facilities. However, overall electricity consumption has continued to climb, resulting in some hyperscalers reporting significant increases in their greenhouse gas emissions this year. "The key question for investors and policymakers is whether a clean energy purchase changes emissions in the real world, not simply whether it changes how emissions are allocated on a company's carbon inventory," Mark Dyson, managing director at RMI, said in an email. Big Tech emissions Among the hyperscalers that published sustainability reports in 2026, both Microsoft and Amazon reported increases in total emissions. In particular, Microsoft's total Scope 1, 2 and 3 greenhouse gas emissions increased by 25% year over year in fiscal 2025 as the company expanded its infrastructure. At the same time, the company said it reached a milestone by matching 100% of its annual global electricity consumption with renewable electricity. That calculation includes renewable electricity already present in local power grids. Separately matched renewable electricity totaled about 34.5 million megawatt-hours, representing roughly 93% of Microsoft's 37 million MWh of electricity consumption. Microsoft has maintained its goal of becoming carbon negative by 2030. A company spokesperson reaffirmed Microsoft's climate commitments but declined to provide additional comment, directing S&amp;P Global Market Intelligence to the methodology in its environmental data disclosures. Amazon reported a similar trend. Its carbon footprint increased by 16% in 2025 to 80.85 million metric tons of carbon dioxide equivalent, while carbon intensity rose 3% year over year but remained 38% below its 2019 level, according to the company's sustainability report. Amazon matched 100% of its electricity consumption with renewable energy for a third consecutive year. The company has also continued investing in carbon-free generation, including nuclear power and small modular reactor technology, as it pursues a 2040 net-zero target. Amazon has more than doubled its portfolio of utility-scale clean energy capacity over the past three years, according to a report from 451 Research by S&amp;P Global, with agreements for more than 40 gigawatts of existing and planned capacity. Alphabet subsidiary Google LLC stands out as a hyperscaler that reported a 2% annual decline in operational emissions in 2025, including a 3% year-over-year reduction in Scope 2 emissions, or the indirect greenhouse gas emissions from purchased electricity. The reduction came despite the company reporting a 37% annual increase in electricity demand, its largest load growth in history. "Maintaining this decoupling of electricity-related emissions from our rapid growth will require even more clean energy investments and closer partnerships with local stakeholders in the years ahead," according to the 2026 Google Environmental Report. Google has nearly 35 GW of contracted clean energy capacity and has signed agreements for over 12 GW of net-new clean energy in 2025 alone. Investors question real-world impact For investors and policymakers, these results illustrate why clean energy purchases alone may not be reducing emissions overall, said RMI's Dyson. Traditional Scope 2 accounting is largely attributional, Dyson said. It can show whether a company has matched electricity consumption with clean energy attributes, but it does not necessarily demonstrate whether the procurement made the power system cleaner. At Google, for instance, as the company's overall electricity consumption climbed, the average share of carbon-free electricity powering Google's global data centers fell slightly in 2025 to 65%, down from 66% a year earlier. "Two renewable energy purchases that look identical on a corporate inventory can have very different climate impacts depending on where and when the projects operate, what generation they displace, and whether they change investment, retirement, or operating decisions on the grid," Dyson said. Investors and policymakers, Dyson added, should also consider what he described as consequential impacts: whether a project would have happened without the corporate buyer, what generation it displaces, and whether it accelerates new clean capacity, fossil fuel retirements, or other structural changes to the grid. Evolving standards The distinction between attributional accounting and consequential emissions impacts is beginning to shape the standards companies use to set climate targets. The Science Based Targets initiative (SBTi) Corporate Net-Zero Standard Version 2.0 requires companies with rapidly growing electricity demand â above 20% over a target cycle â to set Scope 2 emissions reduction targets, an SBTi spokesperson said in a statement. The provision is intended to prevent companies with fast-growing assets, such as data centers, from increasing the share of low-carbon electricity they use, contract or match while their physical emissions continue to rise. SBTi's implementation hierarchy also calls for companies to prioritize direct decarbonization within their operations and value chains before turning to market instruments once other available levers have been exhausted. "It's absolutely critical that companies act upon their climate goals," the spokesperson said. SBTi's validation arm does not currently review how companies execute their individual sustainability strategies or assess their ongoing progress. Companies with validated science-based targets are required to publicly report progress annually and review and, if necessary, update their targets every five years. Testing commitments Bruce Kahn, lead portfolio manager of the Shelton Sustainable Equity Fund, is skeptical that voluntary corporate climate commitments will constrain technology companies when they conflict with the commercial race to build AI infrastructure. "None of this is binding," Kahn said in an interview. "Their net-zero commitments are not binding. They're voluntary." The AI investment cycle has made Kahn less confident in the durability of those pledges as technology companies compete to bring new computing capacity online. Their immediate energy strategy is likely to be shaped more by cost and speed than by a preference for any particular generation technology, according to Kahn. "Their strategy is, how do we get power fastest and cheapest?" Kahn said. That dynamic can favor wind and solar because those resources can generally be deployed faster than new nuclear generation, Kahn said. He views nuclear as an important long-term energy source but sees more immediate investment opportunities in areas such as nuclear fuel and equipment supporting new power infrastructure. Emissions hurdles The uneven climate picture extends to the semiconductor industry, which supplies much of the AI build-out. NVIDIA Corp. continued to match 100% of electricity consumption at sites under its operational control with clean electricity in fiscal 2026, according to its sustainability report for the fiscal year. Its Scope 3 emissions, however, increased to 10.7 million metric tons of CO2 equivalent from 6.9 million a year earlier. Analog Devices Inc. reported a 42% reduction in combined Scope 1 and 2 emissions from its 2019 baseline and achieved its goal of 100% renewable energy use across its manufacturing operations by the end of 2025. The company also established its first interim upstream Scope 3 target, seeking a 30% to 35% reduction in emissions intensity by 2030 from a 2022 baseline. Mary Ferris, ADI's head of ESG, said the company considered both absolute and intensity-based approaches before deciding how to structure the Scope 3 target. "We know that our investors want to see us grow," Ferris said in an interview. "That intensity target gave us the comfort that we were going to be able to grow at the pace that we needed to, while still showing the substantive reduction that we're targeting." ADI is expanding fabrication capacity in the US and Europe by adopting more energy-efficient manufacturing equipment and investing in clean energy procurement. Specifically, ADI invested in two US solar developers through arrangements that include renewable energy credits over 10 years, expected to more than cover the company's US electricity requirements, including those for nonmanufacturing operations. "That additionality was really important to us," Ferris said. ADI faces a different set of constraints in its supply chain, where external foundries and other suppliers operate in regions with widely varying access to renewable electricity and use various emissions-intensive processes. "It isn't one size fits all," Ferris said. "It's an engaged, collaborative conversation that allows us to get to scale." Varied progress Other technology companies are further ahead on some near-term operational targets. Marvell Technology Inc. reported an 86% reduction in Scope 1 and 2 emissions in fiscal 2025 compared to its fiscal 2022 baseline, surpassing its 50% fiscal 2030 target years ahead of schedule. Cisco Systems Inc. reduced Scope 1 and 2 emissions by approximately 90% from its fiscal 2019 baseline, meeting its fiscal 2025 goal and exceeding its fiscal 2030 reduction target for selected Scope 3 emissions. Apple Inc. illustrates why the next phase of corporate decarbonization increasingly lies beyond companies' directly controlled operations. Apple has powered its corporate operations with renewable electricity since 2018, but manufacturing accounts for more than half of its gross carbon footprint, according to its Environmental Progress Report covering fiscal 2024. Its supplier code requires direct manufacturing suppliers to transition to 100% renewable electricity for Apple production by 2030. The company's directly controlled operations represent a comparatively small share of its environmental footprint, making manufacturing and the supply chain the larger challenge as Apple pursues carbon neutrality across its entire footprint by 2030. For investors, Kahn of Shelton Sustainable Equity Fund said opportunities lie within the "picks and shovels" supporting the build-out â cooling systems, water-efficiency equipment, electrical components and power infrastructure that could retain value regardless of which AI business models ultimately prevail. Kahn also noted that the strength of a company's climate strategy is unlikely to determine which technology companies ultimately lead the AI market. "Let's just say one company has a much better climate strategy and is executing really great on that, and they're net-zero, and all the other ones are not," Kahn said. "Are they going to be the leader in the AI tech world? It won't have a bearing on it at all." Susan Dlin contributed to this article. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/podcasts/private-markets-360/private-markets-360-episode-52-how-public-private-convergence-is-reshaping-asset-management</link><description>In this episode of Private Markets 360Â°, we welcome Laura Kirk, Head of Private Investments Capital Formation and Investor Relations at Wellington Management. Laura discusses her career journey from Goldman Sachs to Wellington; the firmâ&amp;#x80;&amp;#x99;s organically built private markets platform; and its approach to capital formation, fundraising, and client relationships. She also explores the evolving landscape for private markets, including public-private convergence, wealth-channel access, evergreen veh</description><title>Private Markets 360Â° | Episode 52: How Public-Private Convergence Is Reshaping Asset Management</title><pubDate>24 September 2026 04:00:00 GMT</pubDate><author><name>Jocelyn Lewis</name><name>Chris Sparenberg</name></author><content><![CDATA[ Podcast â24 September, 2026 Private Markets 360Â° | Episode 52: How Public-Private Convergence Is Reshaping Asset Management By Jocelyn Lewis and Chris Sparenberg In this episode of Private Markets 360Â°, we welcome Laura Kirk, Head of Private Investments Capital Formation and Investor Relations at Wellington Management. Laura discusses her career journey from Goldman Sachs to Wellington; the firmâs organically built private markets platform; and its approach to capital formation, fundraising, and client relationships. She also explores the evolving landscape for private markets, including public-private convergence, wealth-channel access, evergreen vehicles, private credit, secondaries, and the role of technology in broadening investor access. Credits: Host/Author: Chris Sparenberg and Jocelyn Lewis Guests: Laura Kirk Producer: Georgina Lee Published With Assistance From: Feranmi Adeoshun, Kimberly Olvany View Full Transcript Jocelyn Lewis [00:00:00]: Welcome to Private Markets 360, your insider's guide to the world of private investments. Today, we're thrilled to have Laura Kirk, Head of Private Investments Capital Formation and Investor Relations at Wellington Management, one of the world's largest independent asset management firms with over $1.4 trillion in assets under management. Laura joined Wellington in 2024 from Goldman Sachs, where she served in various leadership roles across asset and wealth management, and most recently as chief of staff to the firm's president and COO. Wellington's private investments platform spans venture capital, late-stage growth equity, and private credit, with over $12 billion in committed capital across over 300 investments. We're so excited to have Laura join us today to discuss her experience, the Wellington business, and what lies ahead for the private markets industry. Laura, welcome. How are you today? Laura Kirk [00:01:01]: I'm great. Thanks so much. It's great to be here with you. Chris Sparenberg [00:01:04]: Well, we're thrilled to have you, and we'd love to start off by talking about your career path a little bit. You spent roughly 15 years at Goldman Sachs across the alternatives capital formation, manager selection. Ultimately, you were the chief of staff to the president and COO. Can you talk to us about your experience there and what led you to Wellington? Laura Kirk [00:01:24]: Yeah, absolutely. It was a very difficult decision to leave Goldman after so many years. I consider myself incredibly fortunate to have professionally grown up there, and I continue to think it's a formidable firm with extremely talented people, many of whom are my great friends. I spent the first 10 years there in the external manager selection business, covering all types of firms from large publicly traded asset managers to small boutiques. And I actually started my career on the public side, and Wellington was one of the first firms that I covered. One of the benefits of Goldman's manager selection platform in the way it's structured is that the evaluation of all managers, so everything from indexing solutions to private equity, fits within one group. And not only does this provide a tremendous learning platform, but it also gave me a lot of exposure and appreciation for both the similarities and differences in how allocators evaluate managers across the public and private landscape. So when I moved into a new role at Goldman, which was focused on growing its alternatives platform, I felt that I knew a lot about how allocators think and behave, having been one myself for the prior decade. Laura Kirk [00:02:32]: And so after spending 4 years building out that capital formation effort inside of GS, I recognized that what I really enjoyed most about my time was in fact kind of that building phase. So growing the team, building out new products, challenging existing processes and really trying to encourage new ways of thinking. So when the opportunity to build and lead this team for Wellington came about, I thought that the combination of my background, having spent years as an allocator on the public side and helping to build out the fundraising operation on the private side, made me particularly well suited for this role. And as I mentioned, I was familiar with Wellington already, having been a client of the firm early in my career. I knew the firm was an institution with an incredible history and a reputation for just an outstanding culture, really focused on investment talent, and that was very attractive to me. And yet it was a firm with a very limited brand and product in private markets with an interesting opportunity for growth. So it felt like a rare opportunity to join a platform at an inflection point and kind of help shape the next phase of its journey. So while Wellington's private investing platform today is still relatively young compared to the firm's nearly century-long history, I think it's a really unique combination of entrepreneurial energy and institutional strength. Laura Kirk [00:03:44]: I was also particularly attracted to Wellington's ability to really bring together the perspectives across both public and private markets, allowing our teams to have a full-picture view to help inform investment decision-making. Jocelyn Lewis [00:03:56]: Appreciate that overview. And Laura, it seems like your transition also coincided with a period of significant growth and investment in Wellington's private markets platform, which I'm sure was a great and exciting time to join. And for listeners that might not be familiar with that function, let's unpack your mandate. So we'd love to understand from you what capital formation means in the context of a relatively young program inside an institution with Wellington's history. Laura Kirk [00:04:34]: Yeah, absolutely. It's a great question. Capital formation to me is much broader than just fundraising. So I really view it as encompassing the entire client lifecycle of how a client experiences interacting with our platform. So on the front end, this means what is our brand in the marketplace and how do we engage with the allocator community and tell our story? On the other end of the spectrum, it includes all of the elements of client service and ensuring that we're communicating with our clients in a way that's transparent and clear. And as we broaden the platform kind of beyond our flagship strategies, it also really means thinking about new product development, ensuring that we have the right packaging for the strategies that we're trying to deliver. And so in this capacity, my team works really closely with both the investment team, as well as the relationship managers in our client group to ensure that as we build, we're doing so in a way that is in line with client demand. Ultimately, I view my role as really helping to educate the allocator community about what makes Wellington special and ensuring that we're connecting the right investors with the opportunities and strategies that we offer as a firm. Chris Sparenberg [00:05:38]: Well, let's dig into those strategies a little bit. Wellington's been building its private investing platform for nearly a decade now, and you cover everything from early-stage venture to late-stage growth, and recently you've really leaned into private credit. When it comes to fundraising, what's the sequencing logic and which assets are you leading with today? Laura Kirk [00:05:58]: Yeah, so if you look at the industry and the growth over the last few years in private assets, we're one of the few firms that has chosen to build the platform organically through bringing on dedicated investment talent. And plugging those individuals and teams into Wellington's research engine. We have not pursued M&amp;A like many of our traditional peers, primarily because growth was not our primary objective. So I think core to the firm DNA is really a desire to deliver investment alpha to clients. And if that can be done with a strategy whose capacity is $1 billion versus $5 billion, then that's essentially how we've set our fundraising goals. And in that way, we've been able to build a platform very deliberately across discrete areas within these asset classes that you mentioned in the places where we have long-term conviction and unique perspective as a firm, given our investment expertise and research depth as an organization. So we've really built our capabilities anchored on 3 core tenets. So one, starting with the investment case, we have built in areas where we can identify long-term structural market opportunities. Laura Kirk [00:07:00]: Then we hire dedicated and cycle-tested talent and really plug those people into the investment ecosystem. And 3, we try to listen to our clients and what they're asking for and aim to deliver solutions that meet their needs. Jocelyn Lewis [00:07:12]: That's really helpful context on how you're positioning your platform today. And taking a step back from the fundraising strategy, I'd love to get your perspective on the broader trajectory of the business. With Wellington putting a lot of capital to work, I believe it's around 300 investments that you have, yet the firm, you're still in scale mode. So where is the platform today? And how do you see it growing over the next 3 to 5 years? Laura Kirk [00:07:42]: Yeah, so the next phase is really going to be about just continuing to expand thoughtfully while maintaining investment discipline and staying focused on areas where we believe we can add incremental value to our LPs and companies. Like I said, our approach to growth has been anchored in those core tenets, focusing on our existing strategies, as you mentioned, from early-stage venture to late-stage growth, and selective expansion into new sectors and asset classes like private credit, in particular private real estate credit, and just a continued evolution of how clients access private markets. More broadly, we think it's true we're still in the early stages of public-private convergence. We see a lot of increased client demand for integrated portfolio solutions. I think this is coming to light as we see more of an institutionalization of the wealth markets. RIAs increasingly seek similar structures and have similar needs as institutional investors. So I'd say in short, the growth of the private business is likely to come from accessing new client channels. Expanding our LP base geographically and building new products, kind of leveraging our existing investment capabilities. Chris Sparenberg [00:08:44]: It's interesting. We can follow the thread on expanding into new channels and growing the investor base with this partnership that you've announced with Vanguard and Blackstone in April of 2025. I think it generated significant interest across the industry, and we'd love for you to tell us more about it and the role that Wellington plays in that. Laura Kirk [00:09:04]: Yeah, absolutely. This is a really exciting development for us, and I think for our industry overall. As you mentioned, Wellington formed a strategic alliance with Vanguard and Blackstone to develop innovative products that target the wealth channel. And this alliance brings together what we view as 3 highly complementary organizations with distinct strengths. So Vanguard's scale, its indexing expertise, and investor reach. Obviously Blackstone's leadership in private markets and Wellington's active management capabilities and experience investing across public and private markets. So together, we're focused on developing simplified institutional-quality multi-asset solutions that really integrate public and private assets, as well as active and index strategies. Last week, in fact, we announced the launch of our first 2 funds, the WVB All Markets Fund and WVB Blackstone All Privates Fund. Laura Kirk [00:09:54]: And so for Wellington, this alliance is really a manifestation of how we've been thinking about this public-private convergence. It's one example of us innovating to help clients navigate increasingly complex markets. And we, really believe the industry is moving beyond traditional asset class silos and towards a more integrated portfolio construction framework. Chris Sparenberg [00:10:14]: And what are the dynamics of raising funds for these new vehicles? Laura Kirk [00:10:18]: Yeah, so in this case, Wellington is serving as the investment advisor. We're responsible for the portfolio construction, asset allocation decisions, and right now these funds are available to several of our private banking clients through advisors, and we do anticipate broader adoption within the RIA community. As investor demand for private market assets continues to grow, particularly among individual investors, we certainly think education is a key component of this, and we think that we can contribute to that important dialogue around these types of vehicles. Jocelyn Lewis [00:10:48]: Appreciate that overview. And this partnership is really a great example of the innovation that we're seeing across private markets as managers look to broaden investor access. And better meet the evolving needs of clients. But it's also unfolding against a fundraising backdrop that's been anything but easy over the past couple of years. So, Laura, taking a step back to survey the state of the fundraising market, 2025 was possibly one of the toughest on record, and we're starting to see deal activity recover, and we're still waiting for macro factors to resolve. But from your seat, speaking to LPs day in and day out. What are you hearing about capital commitment plans and perspectives on liquidity? Laura Kirk [00:11:38]: Yeah, certainly it's the case that many LPs have been spending a lot of time looking inward, like focusing on their existing managers, the re-ups, trying to really understand where they can expect liquidity and when. And obviously this creates a huge logjam in the system, and that's certainly not helped the fundraising environment, particularly for new managers and new entrants. At the same time, the investors that we speak with continue to view private market strategies as a strategic allocation. And so I'd say they're more focused on where they want to deploy capital rather than whether they should deploy it at all. And I think LPs are asking really good questions around liquidity, portfolio construction, and really focusing rightfully on manager differentiation. As has been talked about from many of my peers, like dispersion of outcomes is much greater in private markets, and manager selection is really critical. So we expect that in many cases fundraising efforts are just going to take a little bit longer because LPs really want to get to know us and they want to understand what we bring to the table beyond returns. Chris Sparenberg [00:12:38]: Love to dig into that a little bit, and especially the differentiation and how you compete for LP attention in that environment. From the conversations we have on this podcast to everything we're seeing in industry news and even in interactions with our clients. The fundraising stats are telling the story that the benefits are accruing to mega managers. Capital is also flowing into differentiated credit and real assets. And then we're seeing an emerging and really durable secondaries market. Can you talk to us about how you stand out and as you're building those relationships with LPs, what are some of the deeper questions they're asking? Laura Kirk [00:13:15]: Yeah, it is absolutely true that in certain asset classes, Scale does really matter. But I think in the areas of the market where we have chosen to participate to date, we do actually believe that we can differentiate and that differentiation matters even more than scale. So I would say our, advantage has been and will continue to be the ability to bring together perspectives from across the public and private markets and see really a full picture view of a given investment opportunity. I think that our teams really benefit from the expert insights and research depth that they can access across this broad global investment platform that really helps them better understand the market dynamics and opportunities. For us, what we say is that to be successful in the areas of the private markets where we participate, you have to do at least 4 things right. So number one, you have to source good deals. Number 2, you have to have differentiated insights that kind of inform the price you pay and your view of the management teams. You have to be able to size those opportunities right in your portfolio. Laura Kirk [00:14:15]: And lastly, you need to have a view on how to exit and provide liquidity to your LPs. And I think that being inside of Wellington's ecosystem really helps us across all 4 of those dimensions. We think that this kind of integrated public and private market capabilities, again, the extensive company network that we have really helps provide more informed portfolio construction and allocation decisions on behalf of our clients. Chris Sparenberg [00:14:38]: I love how you broke that down into 4 very simple steps, all of which are so important. And Laura, another thing that we're seeing, or a trend, is that fundraising was largely a battle for institutional capital. But today, one of the biggest debates in alternatives is whether the next wave of growth is going to come from the wealth channel as different investment vehicles are being built to serve it specifically. And with the rise of evergreen funds It's fundamentally reshaping how both private credit and other asset classes are being distributed to the wealth channel. And Wellington is clearly leaning into this with your evergreen buildout. So we'd love to hear where you see the real opportunity here and which parts of the market might be too frothy. Laura Kirk [00:15:32]: Yeah, clearly private investments are becoming more broadly accessible through new vehicles. Overall, that's creating a variety of opportunities to improve long-term investment outcomes for individuals, which I think is really exciting. These vehicles, as you mentioned, not only offer kind of increased access, but also provide benefits through lower minimums, greater diversification, and liquidity features. Although it's important to recognize these vehicles are definitely not liquid instruments. For us, we see an opportunity to provide individuals access to parts of the market where more value creation is happening before companies even go public. As has been widely quoted, Today, roughly 3 quarters of US companies generating more than $100 million in revenue are privately held, and that's because companies are just staying private longer than they were in the past, and they're entering the public market later in their development and at higher valuations. So waiting to invest in these companies until they go public really means missing out on a key phase of their growth trajectory. I think there's also really underappreciated diversification benefits to accessing this growth in the private market. Laura Kirk [00:16:37]: So there's been so much talk recently, obviously, about AI and these mega-cap companies, But there are companies in other sectors, so consumer, healthcare, financial services, other parts of technology that are also growing really rapidly. And it's hard to find that type of growth in the public markets that are increasingly being driven by just a handful of very large companies. We've seen a lot of product come to market over the last few years for the wealth channel and private credit and real estate. We think there's an opportunity in asset classes like venture and growth equity, which still represent a significant share of private markets, but are pretty underrepresented in the ever-growing vehicles today. As for your question around the froth, I think it's clear there's concern in certain parts of, or in certain pockets of private markets. We think it's important to distinguish structural concerns from cyclical evolution. And so even if we look at areas of private credit today where we actually do not participate, the corporate direct lending market, we don't see structural problems. In fact, this private credit market we think is only broadening in scope. Laura Kirk [00:17:33]: And we're seeing that intersection of public and private credit, which we think will provide significant tailwinds as more fixed income allocations look to incorporate private assets. Chris Sparenberg [00:17:42]: And thinking about the team that you build, how you go to market, I want to put this against the backdrop of factors that are contributing to the evolution of private capital. One we haven't covered yet is the emergence of new datasets, digital platforms, and networks that provide scaled access to the wealth channel. There's also infrastructure for asset management and investor relations emerging out there. With all these new data and tools coming to market, how do you think about building a team and equipping them to succeed in this environment? Laura Kirk [00:18:15]: Yeah, technology's obviously rapidly changing both what we need to deliver and the infrastructure that we use to deliver it. And as private markets move further into the wealth channel, for us, I think success will depend not only on investment capabilities, but also on education and access, a strong operating model around distribution and the investor experience. So that really means like building a team with a broader mix of skills across product strategy, investor relations, client education, distribution enablement, identifying platform partnerships. We definitely need people who can translate complex private market strategy into very clear narratives for advisors and clients while also building infrastructure required to support these solutions at scale. So from a go-to-market standpoint, it, often really becomes less about selling a standalone strategy and more about helping clients think through total portfolio construction, implementation, how public and private exposures can work together over time. I think the firms that will stand out are those that combine the strong investment expertise with technology, data, and a service model that's really needed to make private markets more accessible and understandable and really operationally practical for a broader set of investors. Jocelyn Lewis [00:19:28]: And that broader set of investors is definitely interested in the private markets and accessing them, I think, is really going to continue to change and evolve the private markets business. And Laura, you've really given us great perspective on how Wellington is navigating the market today, and I'd love to get your predictions for the future and how Wellington hopes to shape it. So if we look out 3 to 5 years into the future, what themes do you think will be prominent across private capital, and what role do you want Wellington to play in that evolution? Laura Kirk [00:20:09]: I think the continued convergence of public and private markets will be one of the defining themes across asset management in the years to come. We talked about the continued growth in the wealth channel and the further institutionalization of that channel, which I think will be the case. We also believe private credit is not a monolith. It will continue to evolve, offering LPs ways to further diversify their exposure. And as you mentioned, I think secondaries will continue to mature as an increasingly important tool, both for investors and for managers. From a thematic perspective, we really believe AI is going to remain a defining theme across private capital, but the opportunity set really extends beyond those mega-cap winners. So I think we expect that significant value creation is also going to come from emerging companies using AI to really transform their industries, improve productivity, and develop new business models. We're really excited about all the innovation that's happening in our industries today, and we think that we can continue to be an important partner to our clients throughout this important inflection point. Laura Kirk [00:21:11]: For us, we really believe Wellington can play a leading role in that evolution, given our expertise across both public and private markets. And our advantage is really the ability to bring together perspectives from across those markets and see a full picture view of a given investment opportunity. We think it makes us better investors and ultimately better partners to our clients. Chris Sparenberg [00:21:30]: Thank you for joining Private Markets 360 featuring Laura Kirk from Wellington Management. If you found this episode insightful, please subscribe to Private Markets 360 For more expert discussions on private investments. Thank you to Laura for her contributions and to our listeners for tuning in. Until next time. ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/sustainability-insights-climate-transition-trends-data-centers-are-scaling-faster-than-their-reported-sustainability-efforts-s101706528</link><description>This report does not constitute a rating action. The sustainability trajectory of data centers is relevant outside the technology sector because these facilities are becoming part of the foundational infrastructure for modern economies. AI, cloud computing, streaming, decentralized finance, and digital business services increasingly rely on a rapidly expanding physical network of servers, cooling systems, and electricity infrastructure. At the same time, some stakeholdersâ&amp;#x80;&amp;#x99; (such as local gover</description><title>Sustainability Insights: Climate Transition Trends: Data Centers Are Scaling Faster Than Their Reported Sustainability Efforts</title><pubDate>21 September 2026 13:49:31 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/blog/crude-oil/092426-why-this-energy-crisis-is-different</link><description>Speaking to the British Parliament in 1913, as First Lord of the Admiralty overseeing the Royal Navy&amp;apos;s controversial shift from Welsh coal to foreign oil, Winston Churchill said: &amp;quot;Safety and certainty in oil lie in variety, and variety alone.&amp;quot; More than 110 years later, global oil supply has expanded dramatically and become far more diverse, with major producers across every region. So why did</description><title>Why this energy crisis is different</title><pubDate>24 September 2026 07:59:09 GMT</pubDate><author><name>Atul Arya</name></author><content><![CDATA[ Crude Oil, Refined Products, Coal, Natural Gas, LNG, Chemicals, Energy Transition, Electric Power, Diesel-Gasoil, Jet Fuel, Naphtha, Renewables, Hydrogen, Carbon, LPG September 24, 2026 Why this energy crisis is different Atul Arya Editor: Rob Westervelt Getting your Trinity Audio player ready... Speaking to the British Parliament in 1913, as First Lord of the Admiralty overseeing the Royal Navy's controversial shift from Welsh coal to foreign oil, Winston Churchill said: "Safety and certainty in oil lie in variety, and variety alone." More than 110 years later, global oil supply has expanded dramatically and become far more diverse, with major producers across every region. So why did this crisis still come as a shock, especially to oil and gas importers in Asia and Europe? The largest energy shock in modern times The early days of COVID-19 showed the fragility of global supply chains when products ranging from masks to microchips and medical equipment and pharmaceuticals were in short supply. Russia's invasion of Ukraine exposed Europe's vulnerability to Russian energy supplies and led to an urgent effort to create new supply chains for LNG, oil and refined products. Even with diversification of sources, the importance of the Middle East crude oil, refined products and LNG supplies has been well known and understood for decades. The Strait of Hormuz crisis has exposed the scale of this dependence and vulnerability of the global economy to this supply chokepoint. Vessel traffic across the Strait of Hormuz came to a halt at the start of the conflict on Feb. 28, 2026. Since then, there have been several starts and stops and vessel traffic started to pick up after a memorandum of understanding between the US and Iran was signed in June. The average number of crossings increased from 14 in May to 30 in June but toppled when fighting resumed in early July. Traffic resumes when talk turns to negotiations and a truce, then tightens again when drones and missiles strike ships, infrastructure and military bases. Restoring confidence will require clearer signs of stability: cleared mines, independent maritime security assessments confirming reduced threats and removal of the area's war-zone designation for insurance purposes. War-risk premiums have not gone away just on announcements alone. The impact of the crisis has not been limited to oil, refined products and LNG. Over the years, the Strait of Hormuz has become a critical artery for commodities essential to the global economy, particularly in Asia. Fertilizers, sulfur, helium, automotive diesel and aviation fuel are all building blocks of global trade, and Middle East supplies of these products have been significantly disrupted. For example, before the crisis, 48% of China's naphtha imports, 37% of European jet fuel imports and 21% of Africa's gasoil imports transited the Strait of Hormuz, according to S&amp;P Global Energy analysis. Hormuz closure is Asia's energy crisis As Tatsuya Terazawa, chairman and CEO of The Institute of Energy Economics, Japan (Tokyo), wrote in early June, the Iran war and Strait of Hormuz closure constitute a global energy crisis, but one felt most acutely in Asia. This has been the largest disruption to energy supplies since World War II, cutting crude oil supplies by 27%, refined products by 21% and LNG by 16%, according to S&amp;P Global Energy estimates. Asian economies have borne the brunt of that impact, especially emerging and developing markets, which hold very low reserves of oil, refined products and gas and have limited capacity to absorb price shocks. The crisis has underscored the need to diversify supply sources, even at higher costs, and to build strategic reserves of crude oil, refined products and, where feasible, gas. Significant share of global commodity exports originated from the Gulf Cooperation Council pre-crisis Material GCC share of global exports 2025 Primary end-use sectors Representative product applications Crude oil ~27% Refining, petrochemicals, power generation Transportation fuels, petrochemical feedstocks for plastics and synthetics, asphalt for road construction, heating oils, lubricants Refined products ~21% Transportation (road, aviation, maritime), residential and commercial heating, power generation, industrial burn Motor gasoline, automotive diesel, aviation fuel, marine bunker fuels, LPG for cooking/heating, fuel oil for power generation/industrial boilers LNG ~16% Power generation, industrial manufacturing, residential and commercial heating, fertilizer feedstock Fuel for gas-fired power plants, industrial heating processes and manufacturing, pipeline gas supply for home heating/cooking, LNG marine bunker fuel Fertilizers ~19% Agriculture, commercial farming, forestry, horticulture Urea and ammonia for crop nitrogen supply, DAP/MAP for root development, NPK blends for soil enrichment, specialized green house nutrients Ethylene glycol (ethanediol) ~49% Packing, textiles, automative, aerospace, HVAC PET bottles and food packaging, polyester fibers for clothing and carpet, engine coolants and antifreeze, aircraft de-icing fluid, industrial heat-transfer fluids Sulfur ~49% Fertilizers and agriculture, chemicals, energy and refining, metals and mining, rubber Sulfuric acid production, phosphate and nitrogen fertilizers, petroleum refining (desulfurization), metal leaching and processing, vulcanization of rubber (tires and industrial rubber goods) Diethylene glycol (2,2Â´Oxydiethanol) ~43% Construction, composites, automotive, printing and coating Unsaturated polyester resins (fiberglass panels, pipes and marine parts), brake fluids, inks, dyes and adhesives Rare gases (NESOI, excluding argon) ~38% Semiconductors and electronics, healthcare aerospace and defense, energy-efficient construction Chip manufacturing (lithography lasers), MRI/NMR/medical imaging, commercial and defense systems, insulated glazing, specialty lighting Note: NESOI = not elsewhere specified or included Source: S&amp;P Global Energy (compiled March 10, 2026) Building resilience Asian economies rely on resilient energy systems that are affordable, reliable and secure in the face of evolving risks. For most Asian economies, particularly those still industrializing and urbanizing, energy security remains the overriding priority. Resilience in these markets is built on diversified energy systems: a pragmatic mix of renewables, gas, coal, hydropower, and emerging technologies like hydrogen and carbon capture, utilization and storage (CCUS). Interconnecting regional grids, such as the Vietnam-Laos-Thailand-Malaysia-Singapore link, could deliver more optimized and resilient systems, but success depends on strong political will, aligned policy frameworks and sustained cross-border infrastructure investment. Policymakers face a balancing act: reducing emissions without compromising affordability, reliability and industrial competitiveness. There are several actions Asian countries can take on their own and with partners. China and Japan have managed the crisis better than other Asian countries because years of planning left them with substantial reserves of crude oil, refined products and natural gas. Although both countries remain highly dependent on Middle East oil, strategic reserves and commercial inventories have helped cushion them from the supply shock. Other major Middle East crude importers, including India, Thailand and Pakistan, hold much smaller strategic stocks. These countries, and others in similar positions, need to build larger reserves of key commodities and diversify supply sources. That will require investment and may raise energy costs, but it is a modest price to pay for stronger energy security. During the Energy Asia Global Leadership Forum (EAGLe) held on the sidelines of Energy Asia in June 2025, the assembled CEOs emphasized the need to collaborate on building interconnected and resilient energy systems across Asia, including cross-border electricity grids, LNG infrastructure, carbon dioxide transport networks and shared resource platforms. Collaboration in Asia's energy transition cannot remain aspirational. It must be specific, operationalized, cross-sectoral and realistic, involving governments, corporates, financiers and technology providers. That means co-creating investment frameworks, sharing infrastructure such as regional grids and carbon dioxide transport networks, and jointly setting standards for emerging industries such as hydrogen, CCUS and sustainable fuels. Effective collaboration requires aligned incentives, shared risk-taking and mechanisms to convert regional initiatives into actionable projects. EAGLe participants emphasized that public-private partnerships and regional cooperation are not optional â they are essential enablers for scaling solutions. The Strait of Hormuz crisis is a timely reminder to act on these initiatives. A path to energy security This crisis gives Asia an opportunity to invest in technologies that make better use of domestic resources to secure long-term supply. The priority is not simply to accelerate the energy transition for climate reasons, but to strengthen long-term supply security. On the demand side, promoting electrification across sectors can shift reliance away from fuel imports. Furthermore, robust energy efficiency programs are also essential for managing demand. On the supply side, markets that have domestic coal resources such as India and China may use more coal than previously anticipated. In all countries, building out domestic resources including wind, solar, battery, nuclear and geothermal will also help reduce import dependency. Countries should also adopt regulatory and fiscal policies that encourage new oil and gas development. The Strait of Hormuz crisis makes clear that energy security must anchor sound policy in every country. Sufficient reserves of crude oil, refined products, LPG and other critical commodities must underpin every resilient energy system. Cooperation with partners and neighbors will further strengthen that security. This article contains data, views and forecasts from S&amp;P Global Energy CERA and does not represent reporting by Platts, part of S&amp;P Global Energy. A version of this article appeared in the September 2026 issue of Insights Magazine. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/economic-outlook-us-q4-2026-solid-growth-this-year-before-a-slip-below-potential-in-2027-s101707891</link><description>This report does not constitute a rating action. S&amp;amp;P Global Ratings forecasts the U.S. economy will grow 2.2% in 2026, up slightly from 2.1% in 2025, followed by below-potential growth in 2027 and 2028. We revised up our 2026 growth forecast (from 2.1% in June) after real GDP expanded 2.1% from a year earlier through the second quarter and with real-time tracking estimates pointing to strong sequential third-quarter growth. Private domestic demand remains solid, with consumer spending holding up</description><title>Economic Outlook U.S. Q4 2026: Solid Growth This Year Before A Slip Below Potential In 2027</title><pubDate>23 September 2026 19:03:11 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/092326-us-business-leaders-eye-new-sustainability-ai-supply-chain-risk-strategies</link><description>Green financing has strengthened since early 2025, and sustainability policies are being implemented in US corporations without much ado, investors said at a prominent climate event. At the five-day Climate Week 2026 conference held across New York City, attendees said corporate policies favoring clean energy and emission reductions are being applied in new ways. &amp;quot;It&amp;apos;s not sustainability off to</description><title>US business leaders eye new sustainability, AI, supply chain risk strategies</title><pubDate>23 September 2026 21:02:16 GMT</pubDate><author><name>Karin Rives</name></author><content><![CDATA[ Energy Transition, Electric Power, Crude Oil, Carbon, Renewables, Emissions September 23, 2026 US business leaders eye new sustainability, AI, supply chain risk strategies By Karin Rives Editor: Benjamin Morse Getting your Trinity Audio player ready... HIGHLIGHTS Corporate policies being applied in new ways Investors shift focus to adaptation projects Green financing has strengthened since early 2025, and sustainability policies are being implemented in US corporations without much ado, investors said at a prominent climate event. At the five-day Climate Week 2026 conference held across New York City, attendees said corporate policies favoring clean energy and emission reductions are being applied in new ways. "It's not sustainability off to the side; it's being integrated across everything," Sarah Kapnick, global head of JPMorgan Chase &amp; Co.'s climate advisory, said during a Sept. 22 panel discussion. As companies look for cost savings and synergies, they find that supply chain resilience and sustainability can go hand in hand, Kapnick said. Likewise, on the investment side, people are looking more holistically at factors that cause volatility in today's market, she said. "They're putting it together â policies with sustainability, with climate, with AI â and building their strategies around all of that now," Kapnick said. Jens Nielsen â founder and CEO of the World Climate Foundation, which has more than $130 billion in mobilized finance â agreed that investor approaches are evolving. "It doesn't matter whether you call it climate or sustainability or just good proper business," Nielsen said at the conference. "You need to frame it in terms of the risk, the returns, and now also the resilience." Over the past 18 months, some investors have faced new restrictions that limit overt environmental and governance sustainability policies. At the same time, investments continue to flow to clean energy projects in the US and abroad, speakers said. "It took us 70 years to build the first terawatt of solar. It took us three years to build the second. It took us 18 months to build the third," said Sage Lenier, founder of an environmental think tank called Project Northstar. "That's a growth curve." Globally, the green economy was the third-largest sector in 2025, surpassing health care if considered a stand-alone industry, the London Stock Exchange Group reported in June. Total market capitalization from investments in renewables, energy efficiency, electric vehicles and other technology surpassed $10 trillion in revenue, the financial market infrastructure provider found. "It is an incredible business case," Jesper Brodin, former CEO of Ingka Holding BV and its subsidiary, furniture maker IKEA AB, said on the Climate Week panel. "So I think the problem if we speak about the energy today is not so much to attract capital, but it's the supply chain of getting it done in an AI boom." Investors are also looking for new growth areas. "Traditionally, it was all in mitigation," Kapnick said. "Now it's expanding rapidly towards also adaptation and resilience, and capital is flowing into those areas as long as they have a return on investment. There are bankable projects for what is needed." What coming months will hold remains an open question. The latest S&amp;P Global Investor Management Index, released Sept. 15, showed that US equity investors are increasingly worried about overseas wars and other geopolitical disturbances. US fiscal policies are also contributing to a drag on investments. The survey of 300 institutional investors showed that energy stocks are again a top investor preference amid surging oil prices. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/092226-brazil-i-rec-issuances-reach-record-on-market-growth</link><description>Brazilian International Renewable Energy Certificates issuances have reached a record high of 69.7 million megawatt-hour January through August, already surpassing the total issued in the entire previous year, according to the latest data from the I-TRACK Foundation. The figure indicates that the Brazilian I-REC market continues to grow steadily and is likely to reach a two-digit growth in 2026.</description><title>Brazil I-REC issuances reach record on market growth</title><pubDate>22 September 2026 17:54:24 GMT</pubDate><author><name>Felipe Peroni</name></author><content><![CDATA[ Electric Power, Agriculture, Energy Transition, Biofuels, Renewables September 22, 2026 Brazil I-REC issuances reach record on market growth By Felipe Peroni Editor: Richard Rubin Getting your Trinity Audio player ready... HIGHLIGHTS Issuances surge 24% in eight months, surpassing 2025 Solar certificates jump 32.3% from previous year Hydro prices trade at a discount to wind/solar Brazilian International Renewable Energy Certificates issuances have reached a record high of 69.7 million megawatt-hour January through August, already surpassing the total issued in the entire previous year, according to the latest data from the I-TRACK Foundation. The figure indicates that the Brazilian I-REC market continues to grow steadily and is likely to reach a two-digit growth in 2026. In the first eight months of the year, issuances were 7.7% higher than the 64.7 million MWh issued in 2025, and by 23.5% from the corresponding January-August period. "The market is evolving, from simply stating renewable energy consumption towards proven claims," Isabel Arantes, strategic consultant at Instituto Totum, the Brazilian I-REC issuing body, told Platts Sept. 22. "Today, it is not enough to simply claim to consume renewable energy; it is necessary to demonstrate it through a structured, evidence-based process," Platts is part of S&amp;P Global Energy. Issuances of hydroelectric I-RECs reached 35.2 million MWh in the period, compared with 35.7 million MWh for all of 2025. Hydropower represents most of the electricity generated in Brazil, having reached 51.2% of the total electricity supply in 2025, according to figures from the country's Ministry of Energy and Mines. But other renewable sources have expanded in recent years, reflected in an increase in I-REC issuances. In January-August, solar I-REC issuances reached 7.2 million certificates, up by 32.3% from 2025's total. Wind issuances reached 26.3 million MWh in the year-to-August, up by 18.6% from 2025. Solar power represented 11.3% of the Brazilian electricity supply in 2025, compared with 9.3% in the previous year, while wind increased to 14.9%, from 14.1%. The higher supply of hydro I-RECs, combined with consumers' preference for newer technologies, has been causing a discount for hydro I-RECs relative to other sources, according to market participants. Platts' assessment of vintage 2026 hydro I-REC was at 0.85 real/MWh (17 cents/MWh) on Sept. 21, compared with 0.95 real/MWh for wind and solar. Brazilian I-REC redemptions showed a similar trajectory, though they remained lower than issuances, potentially indicating oversupply, according to sources. Redemptions totaled 65.8 million MWh in January-August, up 8.6% from the 60.6 million MWh retired in all of 2025, the I-TRACK Foundation data shows. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/091626-interview-accu-developer-expects-no-major-safeguard-review-changes</link><description>Australia&amp;apos;s Safeguard Mechanism review is unlikely to produce material changes to baseline decline rates or introduce caps on carbon credit use, with the program working well in its present form, according to Marc Train, CEO of Corporate Carbon, and Julien Gastaldi, CEO of Maki Planet Systems. Speaking to Platts, part of S&amp;amp;P Global Energy, in an exclusive interview Sept. 10, Train said the scale</description><title>INTERVIEW: ACCU developer expects no major Safeguard review changes</title><pubDate>16 September 2026 13:47:46 GMT</pubDate><author><name>Himanshu Chauhan</name></author><content><![CDATA[ Energy Transition, Emissions, Carbon September 16, 2026 INTERVIEW: ACCU developer expects no major Safeguard review changes By Himanshu Chauhan Editor: Ribhu Ranjan Getting your Trinity Audio player ready... HIGHLIGHTS Expects Generic ACCUs to rise toward EP costs Long-term offtake deals gaining traction Soil supply expected to scale; SMC premium temporary Australia's Safeguard Mechanism review is unlikely to produce material changes to baseline decline rates or introduce caps on carbon credit use, with the program working well in its present form, according to Marc Train, CEO of Corporate Carbon, and Julien Gastaldi, CEO of Maki Planet Systems. Speaking to Platts, part of S&amp;P Global Energy, in an exclusive interview Sept. 10, Train said the scale of industrial decarbonization required and the marginal abatement cost curves mean the ACCU market fills a critical gap that caps on offset use would not address. The government's 2026-27 Safeguard Mechanism review, whose consultation closed for submissions Sept. 18, sought feedback on post-2030 baseline decline rates and potential limits on ACCU access for compliance. Corporate Carbon is an Australian multisector developer involved in more than 100 carbon projects under the ACCU program. Maki Planet Systems is a climate technology company working to scale Savanna Fire Management globally. Platts assessed benchmark Generic Australian Carbon Credit Units at A$38.25/metric ton of CO2 equivalent Sept. 16, while Environmental Plantings ACCUs were assessed at A$54.50/mtCO2e and Savanna Fire Management Indigenous ACCUs at A$50.50/mtCO2e. Safeguard review expectations Asked about expectations from the Safeguard review, Train said the opening paragraph of the consultation paper stated the mechanism is working well and doing what it's supposed to do. "We wholeheartedly agree. So we don't expect it to change much," Train said. "From what we saw in the details of the review and the paper, we probably don't expect a whole lot of change." On whether caps should be imposed on ACCU use for compliance beyond 2030, Train said the scale of industrial decarbonization required represents a significant investment. "The ACCU market fills that gap really well. We expect the ACCU market to do what it's supposed to be doing, and we don't expect that the caps will come into place," Train said. Generic to rise, not premiums to fall Commenting on the Climate Change Authority's recommendation to examine whether 25-year permanence ACCUs remain appropriate for Safeguard compliance, Train said Corporate Carbon is supportive of the 100-year permanence. "We have existing projects which have 100-year permanence, and when we get the opportunity to transition projects to 100-year, we will," Train said. "It is effectively there to create permanent stores in the land, so we are supportive of it." Train said he would not expect significant market impact from greater emphasis on 100-year permanence, noting that compliance buyers would probably expect some pricing delta if market dynamics drive that decision. With Climate Active certification ending in June 2027, Train said the market should expect Generic ACCU prices to rise to meet the cost of production for higher-cost methodologies like Environmental Plantings, rather than premiums compressing. "What I'd expect is not so much the premium continuing, but rather a rebasing in the price in order to meet and attract pricing associated with higher-cost methodologies like environmental plantings," Train said. Train noted that the premium market has always traded on smaller volumes compared to Generic purchases, with the voluntary market becoming a smaller percentage as compliance grows. Gastaldi added that fewer than 5% of Climate Active buyers were actually buying ACCUs, and of those, mostly Indigenous credits. Offtake deals gaining traction Train said the appetite for longer tenor offtake deals is more relevant now than ever, with large emitters recognizing supply-demand imbalances. "We definitely are seeing large emitters who are coming into the sector, recognizing the supply-demand imbalances that are set to come," Train said. "So we are seeing offtakes coming in for five to 10 years and longer, which maybe two years ago weren't as prevalent." Regarding the permanent exit arrangement for fixed-delivery carbon abatement contracts, Train said Corporate Carbon views CACs as obligations to be managed at the business level to maximize value. Train said he does not expect CAC exits to materially impact spot supply. "Given the supply-demand imbalance, and how there's a supply overhang currently, the volume of what we would expect to go through via the CAC mechanism wouldn't impact spot supply today," Train said. Soil supply, SMC premium On soil carbon, Train said AgriProve's projects are expected to track in line with expectations, with the proposed 3 metric ton per hectare per year cap aligning with AgriProve's modeling. Train said the transition to remote sampling via satellite under module 2 will enable soil carbon credits to be generated at scale. On the Safeguard Mechanism Credit premium over Generic ACCUs, Train said the premium appears to reflect a specific buyer solving a specific need. "We don't see it as a sustainable trend where a premium would track higher than generics," Train said. Meanwhile, Gastaldi said the rapid international uptake of Savanna Fire Management methodologies across four major carbon frameworks in less than 12 months reflects recognition of a gap in available climate products. "It's on the back of the efforts made in Australia in the last few years to improve that method, with a strong track record, especially on integrity," Gastaldi said. "At a time when the international markets were struggling with relevance and integrity, it's been about showing that we had a community-led, high-integrity, measurement-based method that was directly tackling the issue of a warming climate," Gastaldi said. Maki is active in Botswana, Zambia and Brazil, with exploration work in Angola and Mozambique, while partners operate in Belize, Mexico, Papua New Guinea and Timor-Leste. The main focus is on sub-Saharan Africa, where the methodology has the most potential, Gastaldi said. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/091526-energy-affordability-takes-center-stage-in-new-york-gubernatorial-election</link><description>Energy affordability issues are at the forefront of New York&amp;apos;s gubernatorial election, following the incumbent&amp;apos;s moves to roll back parts of the state&amp;apos;s ambitious climate law. Incumbent Governor Kathy Hochul (Democrat) led Republican challenger and Nassau County Executive Bruce Blakeman 49-39, according to a Siena Research Institute poll released Aug. 12. While New York has not had a Republican</description><title>Energy affordability takes center stage in New York gubernatorial election</title><pubDate>15 September 2026 15:25:11 GMT</pubDate><author><name>Noah Schwartz</name></author><content><![CDATA[ Energy Transition, Electric Power, Natural Gas, Crude Oil, Emissions, Carbon, Renewables September 15, 2026 Energy affordability takes center stage in New York gubernatorial election By Noah Schwartz Editor: Meghan Gordon Getting your Trinity Audio player ready... HIGHLIGHTS Hochul leads Blakeman 49-39 in poll Climate law targets shift from 2030 to 2040 Energy affordability issues are at the forefront of New York's gubernatorial election, following the incumbent's moves to roll back parts of the state's ambitious climate law. Incumbent Governor Kathy Hochul (Democrat) led Republican challenger and Nassau County Executive Bruce Blakeman 49-39, according to a Siena Research Institute poll released Aug. 12. While New York has not had a Republican governor in 20 years, Hochul, who became governor in 2021 following Andrew Cuomo's resignation, has been seen as potentially vulnerable. She was elected in 2022 with about 53% of the vote, defeating the Republican nominee, former US Representative Lee Zeldin, who is now head of the US Environmental Protection Agency. Questions over compliance with the state's 2019 Climate Leadership and Community Protection Act (CLCPA), which called for steep reductions in carbon emissions, have been prominent during Hochul's first full term. The governor's position that full compliance with the law would impose high costs on ratepayers put her at odds with some members of her own party. New York had the third-highest electricity prices in the country, at nearly 30 cents/kilowatt-hour in May, according to a report by the Empire Public Policy Center. Hochul announced in May an agreement with lawmakers on the fiscal 2027 budget, which rolled back several provisions of the CLCPA. The changes included a new carbon emissions reduction target of 60% by 2040 compared to 1990s levels. The previous target was a 40% reduction in greenhouse gas emissions below 1990 levels by 2030. "The commonsense reforms Governor Hochul fought for in this year's budget protect New York's status as a climate leader, while prioritizing affordability for New Yorkers. Governor Hochul remains committed to building on the state's robust and nation-leading record of climate and clean energy successes," Ken Lovett, a spokesperson for Hochul, told Platts, part of S&amp;P Global Energy, in a statement. The CLCPA changes were supported by the business community, but drew criticism from environmental groups. Even with the changes to the law, Blakeman blames Hochul's climate policies for New York's high energy prices. "She's still wedded to the green energy scam. She's just extended the time," Blakeman told Platts in an interview. A Blakeman victory could lead to an even more significant rollback of the state's climate goals. When asked if he believed emissions from fossil fuels cause climate change, Blakeman said, "I don't know that. I'm not a scientist. I'm all for energy conservation and ways in which we can reduce emissions, because if, in fact, it is a significant factor, obviously we should address that." Power producers and advocates said Hochul's energy policy focus has pivoted from climate change toward affordability and sustainability. "The governor has changed her focus to affordability, certainly, but even more importantly, reliability, and her approach to energy policy, saying 'all of the above' must be on the table, is a sea change," Gavin Donohue, president and CEO of the Independent Power Producers of New York, said in an interview. Alexander Patterson, a campaign coordinator at Public Power NY, which advocates for the state to build and own 15 gigawatts of renewables, called the CLCPA changes a "huge step backward." "Both candidates have talked about an 'all of the above' energy approach. That literally just means the status quo and what has led our energy system to this point," Patterson said. Nuclear energy is part of both candidates' "all of the above" approach. In her January State of the State address, Hochul announced a plan to deploy 5 GW of nuclear reactors in the state. The governor has also directed the New York Power Authority to build a 1-GW nuclear project upstate. "We've got to take another look at nuclear," Blakeman said. Hochul easily fended off a Democratic primary challenge from progressive Lieutenant Governor Antonio Delgado, who ended his campaign in February. She has shored up support from fellow Democrats with endorsements from US Representative Alexandria Ocasio-Cortez and New York City Mayor Zohran Mamdani. Blakeman received President Donald Trump's endorsement after Republican Representative Elise Stefanik ended her primary campaign in December 2025. Offshore wind Offshore wind development is critical to the state's renewable energy plans, but has been hampered by the Trump administration. The 924-megawatt Sunrise Wind and the 810-MW Empire Wind project, both off the coast of New York, were impacted by the US Interior Department's December 2025 order halting work at offshore wind projects across the Atlantic Coast. At the time, Hochul, alongside other Northeast governors, said delaying offshore wind projects would drive up costs for ratepayers. The developers of the projects eventually prevailed in court, and both Equinor ASA's Empire Wind and Ãrsted A/S' Sunrise Wind are expected to begin delivering power to the grid in 2027. Like the Trump administration, Blakeman opposes wind generation. "I don't think that [offshore wind] is an efficient form of energy generation. I agree with President Trump. We should stop it," Blakeman said. In June, Hochul and New York Attorney General Letitia James announced a lawsuit challenging the Trump administration's settlement deal with TotalEnergies SE, in which the government agreed to pay $1 billion in exchange for the company dropping its offshore wind leases and investing in US fossil fuels. Gas supply questions Natural gas supply has become central to the energy affordability debate in New York. In January, a report by the New York Independent System Operator attributed the state's recent rise in power prices mostly to climbing gas prices. Blakeman said increasing gas supply by building new pipelines and extracting gas in New York could lower power prices. "Natural gas is cheap. It's abundant and it's clean. So obviously, if we're sitting on this huge natural gas reserve here in New York State, it is insane not to extract," Blakeman said. In December 2024, Hochul signed into law a bill to ban the use of carbon dioxide to extract gas and oil in the state, expanding an existing prohibition on fracking. If elected, Blakeman said he would support development of the Constitution Pipeline, a 650,000-dekatherm/day project proposed by Williams Cos. Inc. which would run 125 miles from Susquehanna County, Pennsylvania, to an interconnect with the Iroquois Gas Transmission System LP gas transmission system in Schoharie County, New York. Staff at the Federal Energy Regulatory Commission issued a favorable assessment of the project in August but said a dispute over a state water quality certificate was outside its scope. Hochul's administration has signaled some openness to new gas pipeline infrastructure, granting water quality certification in November 2025 to the Northeast Supply Enhancement pipeline project. Williams, through subsidiary Transcontinental Gas Pipe Line Co. LLC, shelved the 37-mile pipeline project, capable of delivering 400,000 Dth/d downstate, in 2020 after facing fierce opposition. The company revived the project in 2025 in response to Trump's executive orders supporting expedited energy infrastructure. FERC authorized the start of construction on the first segment of the Northeast Supply Enhancement project in August, shortly after a federal appeals court rejected a bid by environmental groups to vacate New York's water quality permits. However, a different appeals court on Sept. 8 ruled in favor of environmental groups who had challenged New Jersey's approval of a water quality certificate. Environmental groups have been critical of the gas pipeline expansions, arguing that New York's high power prices are driven not by a lack of gas supply, but by to lack of investment in renewables and the electric grid. "There's not a lack of supply of natural gas in the state, Public Power NY's Patterson said. "We have fundamental problems in our grid where we don't have enough transmission and we don't have enough cheap energy in the form of renewables coming on." Data center development In July, Hochul signed an executive order freezing construction for up to one year on data centers with at least 50 MW of capacity while the state develops energy and environmental regulations. The governor said the temporary moratorium, which is the first of its kind in the country, is part of her strategy to lower energy costs. "Governor Hochul is putting energy rebate checks directly in New Yorkers' pockets, taking on the big utility companies to bring down costs, and establishing the nation's first statewide data center moratorium to protect ratepayers," Hochul campaign spokesperson Ryan Radulovacki told Platts. As of May, there were 51 large load projects in NYISO's interconnection queue, which would add 12,670 MW to the grid, the grid operator said in its 2026 Power Trends report. Blakeman said he has talked to voters concerned about data center energy usage, but criticized the moratorium. "It's the future of our economy, and we should figure out a way to make it work," Blakeman said. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/091126-where-states-stand-on-data-center-sales-tax-exemptions-ahead-of-us-midterms</link><description>Having previously competed to lure data center development with a variety of tax incentives, states across theâ&amp;#x80;¯US are increasingly reconsidering the costs of theseâ&amp;#x80;¯exemptions ahead of the US midterm elections. Eight states have moved to pause or repealâ&amp;#x80;¯sales tax exemptions for data centers over May through August, according to an analysis by S&amp;amp;P Global Market Intelligence. Five states â&amp;#x80;&amp;#x94; Arizona,</description><title>Where states stand on data center sales tax exemptions ahead of US midterms</title><pubDate>11 September 2026 16:42:33 GMT</pubDate><author><name>Sarah Barry James</name></author><content><![CDATA[ Electric Power, Natural Gas, Water, Energy Transition, Renewables September 11, 2026 Where states stand on data center sales tax exemptions ahead of US midterms Sarah Barry James Editor: Giselle Rodriguez Getting your Trinity Audio player ready... HIGHLIGHTS Energy and water concerns drive opposition Political pressure mounts before elections Having previously competed to lure data center development with a variety of tax incentives, states across theâ¯US are increasingly reconsidering the costs of theseâ¯exemptions ahead of the US midterm elections. Eight states have moved to pause or repealâ¯sales tax exemptions for data centers over May through August, according to an analysis by S&amp;P Global Market Intelligence. Five states â Arizona, Illinois, Massachusetts, New Jersey and Ohio â paused sales tax exemptions or benefit programs, while three states â Maine, Minnesota and Nebraska â repealed them. A number of others â including Pennsylvania and Delaware â tightened regulations by adding stipulations around investment levels, power generation or job creation. The changes come amid rising opposition to data center development among constituents calling on both state and local lawmakers to address concerns about energy and water usage, among other factors. At the same time, those who support tax incentives note the economic impact of data centers can extend beyond state tax revenue. "Governors, or local political leaders of whatever size, are using whatever tool they have in their toolbox to slow down data center development â perhaps to appease voters' concerns that there are too many developments or that they're happening too quickly, or because people don't understand exactly what they might bring to the community," said Ammad Waheed, a real estate and corporate transactions partner at Norton Rose Fulbright LLP who advises hyperscalers, developers and landowners on data center leasing, land acquisition, development, zoning, financing and related transactions. States reconsider exemptions The recent tax incentive shifts come as dozens of elected officials face constituent scrutiny and concerns over high energy prices heading into the midterms. "We have 36 gubernatorial elections in November. We have like 88% of state policymakers up for election this year," said Morgan Scarboro, a vice president and economist at MultiState, who leads the teams monitoring data center legislation. "There is a really big tension right now for policymakers between: There is a lot of public attention on this issue; at the same time, it's driving a lot of the economic growth. So how do you sort of marry thoseâ¯two things?" In August, Pennsylvania Gov. Josh Shapiro (Democrat), who previously supported data center development in the state, signed an executive order restricting the sales and use tax exemption to data center operators that comply with the Governor's Responsible Infrastructure Development (GRID) Requirements, which cover power, sustainability, labor and community engagement concerns. Shapiro is up for reelection this cycle. That same month, Delaware Gov. Matt Meyer signed a package of energy consumer protection bills requiring data centers and other large energy users to pay for their own infrastructure costs. The legislation creates a separate utility rate class for large energy-use facilities, enforces a "bring your own generation" requirement, and prohibits them from qualifying for job-creation business tax credits. North Carolina legislators repealed the state's sales tax exemption on data center energy usage, making electricity purchases by data centers subject to the combined 7% state and local sales and use tax rate. The move followed a report from the state Department of Commerce that estimated existing data center operators in North Carolina receive $20 million per year in electricity-related sales tax exemptions. Elected officials in both branches of the state's legislature are up for reconsideration in the midterm elections. Gov. Josh Stein (Democrat) has called for the full repeal of North Carolina's data center tax exemptions at the end of 2032. Earlier in the year, Illinois Gov. J.B. Pritzker (Democrat), Massachusetts Gov.â¯Maura Healey (Democrat), and Ohio Gov. Mike DeWine (Republican) indefinitely paused the acceptance of new data center sales tax exemption applications. And in Arizona,â¯Gov. Katie Hobbs (Democrat) approved a state budget that includes a three-year moratorium on the state's data center sales tax exemption. All four states have gubernatorial elections in November. As for New Jersey, the stateâ¯paused a $500 million tax credit program for AI data centers that was set to launch this year, with many now expecting the program to be eliminated. But calculations about how much sales tax revenue states might collect without incentives do not tell the whole story, according toâ¯Dan Diorio, executive vice president of state policy and government affairs for theâ¯Data Center Coalition tradeâ¯association. "When you see $1 billion or something like that, it makes headlines, and it's easy to harp on and say, 'Well, we're missing out on $1 billion of revenue,'" Diorio said in an interview. Thoseâ¯estimates, Diorio said, overlookâ¯a very real possibility that a data center project might not have been built in the state absent tax exemptions and other incentives. Effects on development The states that haveâ¯seen the most data center growth â including Virginia, Texas and Pennsylvania â have sales tax exemptions, Diorio said. By contrast, he pointed to his home state of Colorado, which does not offer any sales tax exemptions. "It would seem that Colorado would be ripe for development, but it really hasn't been," Diorio said. The Colorado state legislature considered a bill in 2026 that includedâ¯a 100% sales and use tax exemption for data center development as well as a less stringent set of renewable energy requirements, but the measure failed to advance.â¯ Even the possibility of tempered incentives can have an effect. In Georgia, the General Assembly introduced multiple bills that would have eliminated the state's existing statutory sales tax exemption. Though the bills did not pass, they still had an impact, according to 451 Research Director Dan Thompson, who leads the Data Center Services &amp; Infrastructure team. A number of companies building for two of the hyperscalers are "dragging their feet on developments" as they wait to see whether the bills would pass, he said. That said, 451 Research's "Voice of the Enterprise: Data Centers, Infrastructure 2026" surveyâ¯found that when asked to select the most important considerations for choosing the location of a new data center, compliance and existing regulation came in slightly behind environmental conditions and access to power, but slightly ahead of access to network infrastructure.â¯ Scale of impact Shifting the tax environment could have material implications both for tax revenue and for data centers' broader impacts, such as on power demand. The four major hyperscalers â Meta Platforms Inc., Alphabet Inc., Amazon.com Inc. and Microsoft Corp. â are expected to spend a collective $1.5 trillion in capex between 2026 and 2027 as the companies race to expand their infrastructure, according to the Visible Alpha AI Monitor as of August.â¯Developments are also being planned by smaller enterprises. 451's VotE survey of IT and line-of-business decision-makers found that 73.6%â¯of respondents said their organization planned to build a new data center,â¯including 35.6% who expect to build within the next 12 months. At the same time, local opposition has led to a growing number of projects being canceled or delayed. As of June, 47 projects that had been contested, delayed or canceled, according to 451 Research by S&amp;P Global, representing a significant uptick from the 53 projects counted in full-year 2025. "Previously, these things would be just quietly built and no one paid much attention," 451's Thompson said of data centers. "Now there is seemingly a spotlight being shown on every single development." While 451 noted that the reasons for public pushback are myriad, the two most common concerns involve power and water use. US data center power demand was estimated at about 195 terawatt-hours in 2023, according to 451 Research. For 2026, that demand is expected to more than double to 411 TWh before reaching close to 1,000 TWh in 2030. In part, that is because AI data centers consume more power, but it also reflects the sheer number of data centers expected to be built over the coming years. And though new generations of data center technology are becoming more efficient in terms of water usage,â¯indirect water usageâ¯for power generation remains significant, especially for nuclear power. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/ratings/en/blog/french-investors-are-becoming-more-vigilant</link><description>French institutional investors are adopting a more guarded stance. This indicates that current market conditions may not fully capture underlying risks. </description><title>French Investors Are Becoming More Vigilant</title><pubDate>12 May 2026 17:04:00 GMT</pubDate><content><![CDATA[ Investor Relations | 12 May 2026 French Investors Are Becoming More Vigilant Institutional investors from France are adopting a more guarded stance. Overview French institutional investors are adopting a more guarded stance. This indicates that current market conditions may not fully capture underlying risks. While financial conditions remain broadly supportive, investors are shifting their focus toward medium-term risks, structural vulnerabilities, and potential gaps between macroeconomic stress and market pricing. Overall investor sentiment is characterized by a tension between short-term stability and long-term vulnerability. While stable credit markets underpin resilience over the near term, concerns are rising over the delayed materialization of risks, particularly in credit and private markets. Additionally, investors pay more attention to sector and geographic exposures. What We Heard Medium-term risks are coming to the fore Investors are shifting their focus from short-term volatility to the long-term effect of geopolitical and energy shocks, and are increasingly moving toward scenario-based analysis. Key concerns include rising pressure on corporate profitability and earnings visibility, an increase in default risk in the case of prolonged stress, and uncertainty about how long energy shocks will last and how they will affect the broader economy. Uncertainty about market signals increases Mixed or inconsistent signals make traditional market indicators harder to interpret. This is underpinned by uncertainty about interest rate dynamics and yield curves, alongside limited visibility of forward-looking macro signals, particularly in rates and foreign exchange markets. Investors are therefore shifting from conventional indicators toward a more cautious, judgment-based approach. Central bank policy comes under scrutiny Investors have started to question the effectiveness of central banks' policy actions and see them as a source of uncertainty rather than stabilization. Among the main concerns are the potential acceleration of an economic slowdown in Europe due to policy tightening, the limited ability of monetary policy to address supply-driven inflation, and potentially less aggressive tightening than current market pricing implies. Credit markets might be less stable than they seem Financing conditions remain generally supportive, with spreads widening only moderately. Immediate stress is limited and there are no signs of widespread ratings pressure or liquidity events. However, this resilience is raising concerns about a potential disconnect between macro conditions and financial markets. Key risks include the capacity of sovereigns and corporates to absorb shocks, the possibility of sudden repricing due to delayed adjustments, and potential spillovers into the wider financial system. Sector selectivity is up Investors are adopting a highly selective approach. Sectors that are most vulnerable to current pressures include energy-intensive industries (margin pressure), transport and consumer-related sectors (sensitive to fuel and input costs), and agribusinesses (fertilizer supply volatility). Investors are increasingly reassessing their regional exposure and view Asia as more sensitive to energy dependence and supply chain vulnerabilities than Europe. Private credit risks remain elusive Even though private credit appears calm on the surface, it could become a central concern for investors--not due to immediate stress but because of structural vulnerabilities, such as limited transparency and weak mark-to-market mechanisms. According to investors, private credit may not trigger a financial crisis but could amplify it. Investors increasingly emphasize tail-risk scenarios. They note that systemic risk would most likely emerge from institutional balance sheets, particularly insurers, if they faced a combination of illiquidity, regulatory constraints, and sudden liquidity needs. Additionally, extensions and restructurings to "smooth" returns may only delay potential losses instead of eliminating them. This could lead to dislocation and concentrated losses over time. Risk exposure differs across regions. While European exposures remain contained and nonsystemic, the scale of the U.S. market--coupled with bank involvement and a broader investor base--has led to more investor vigilance. S&amp;P Global Claudio Viscomi Director of Market Outreach, EMEA Investor Engagement &amp; Market Insights Investor Engagement &amp; Market Insights S&amp;Pâs analyses, including ratings, are statements of opinion as of the date they are expressed, and are not statements of fact or recommendations to purchase, hold, or sell any securities, and should not be relied on when making investment or other business decisions. S&amp;P obtains information from sources it believes to be reliable, but does not audit and undertakes no duty of due diligence or independent verification of information it receives. S&amp;Pâs opinions and analyses do not address the suitability of any security. Please read our full disclaimer. ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/special-reports/energy-transition/horizons-top-cleantech-trends-2026</link><description>Discover 2026â&amp;#x80;&amp;#x99;s top energy trends: AI-driven power demand, Chinaâ&amp;#x80;&amp;#x99;s cleantech dominance, grid modernization needs, and the future of global carbon accounting.</description><title>Horizons Top Trends 2026</title><pubDate>09 December 2025 00:09:00 GMT</pubDate><content><![CDATA[ S&amp;P Global Energy Horizons S&amp;P Global Energy Horizons Top Trends 2026 AI growth and geoeconomic shifts in cleantech markets confirm that energy expansion and sustainability are linked imperatives Let's Talk Want to turn uncertainty into opportunity across energy expansion and sustainability? Contact us. Contact Sales On this page AI growth Solar Grids PPAs China's H2 SAF EV sales Carbon Geopolitics Adaptation On this page AI growth Solar Grids PPAs China's H2 SAF EV sales Carbon Geopolitics Adaptation Introduction Download report Profound geopolitical shifts and strategic repositioning in complex, interconnected energy and sustainability ecosystems will shape energy markets in 2026. The US is charting its own course, driven by rapid AI growth and evolving energy priorities. Europe is working to reconcile diverse objectives, while China consolidates its cleantech leadership and seeks to draw global markets closer. AIâs explosive power demand is testing grid limits, revenue models and sustainability goals. The pace of progress will depend on unlocking new capacity and flexibility, with grid modernization a key constraint on energy security and competitiveness. Geopolitical alignment is reshaping the trajectories of renewables, hydrogen, sustainable aviation fuel (SAF), electric vehicles and climate policy, with supply chain and carbon accounting battles intensifying. Chinaâs dominance in clean energy supply and technology is growing, while Europe and the US navigate policy swings and market volatility. Mounting physical and financial climate risks are turning adaptation from optional to essential. The interplay of these trends â AI-driven demand, grid bottlenecks, evolving procurement strategies, scaling technologies for hard-to-abate sectors, disjointed carbon rules, rising costs of climate risk and the urgent need for resilience â highlights how energy expansion and sustainability are not parallel ambitions, but intertwined imperatives shaping the global energy future. Back to Top Upcoming Horizons Top Trends Webinar: AI Growth and Geopolitical Shifts Reshape Global Energy Markets Register Now AI growth tests Download report As AI uptake soars in 2026, energy supply and sustainability commitments face a breaking point Access to sufficient energy is a critical enabler of a transition to an economy supercharged by AI. Energy may be the gating factor that will determine countriesâ speed of progress and, by extension, their geoeconomic competitiveness. S&amp;P Global Energyâs high-growth view shows global data center power demand increasing 17% to 2026 and 14% per year through 2030, reaching potential demand of over 2,200 TWh , roughly equivalent to Indiaâs current total electricity consumption. $500B Spending on US data centers nears $500 billion in 2026 Projected global data center power demand vs. total generation (TWh) Source: S&amp;P Global Energy; 451 Research 2026 2027 2028 2029 2030 Data center demand (low end) Demand Data center demand (high end) 31,854 32,977 34,103 35,055 35,935 1,388 1,003 1,618 1,168 1,832 1,322 2,030 1,464 2,192 1,580 As of September 2025. Although uncertainties around the magnitude of growth are considerable, expansion at this rate â or anything approaching it â will reverberate across the economy, influencing infrastructure planning, investment flows and national policy, as well as raising environmental concerns. The year 2026 will increasingly shine a spotlight on whether the industry can maintain rapid growth while balancing the sustainability side of the equation. Economics and speed to market will remain key determinants of data center power supply choice, particularly where there are options in supply, and those two top priorities will not always align with sustainability goals. Data center sustainability commitments vary significantly, and net-zero ambitions are not a given. Data from the 2024 S&amp;P Global Corporate Sustainability Assessment (CSA) shows that 38% of assessed companies with data center operations lack a net-zero commitment. Major tech firms have made net-zero commitments, including companies leading the AI charge such as Microsoft Corp., Alphabet Inc. and Meta Platforms Inc. However, meeting those commitments is getting harder, as is being acknowledged in the most recent company sustainability reports. Data center companies have been leading clean power procurement efforts to meet their power needs and climate ambitions, and we look for these to continue, although the pace of new near-term power purchase agreement uptake has been slowing. In 2026, we could see the start of revisions to existing targets and some fracturing of policies by key players and regions. Back to Top Solar growth peaks Download report Solar peaks (for now): First annual slowdown in renewables additions in 2026 The end of 2025 will mark a high point for renewables installations. By this time, the global solar market will have reached an extraordinary milestone, with installations surpassing 500 GW AC â an achievement unimaginable when the industry was in single-digit gigawatts just over a decade ago. This surge has been driven largely by China, which accounts for more than half of global additions. Our analysts now forecast that Chinaâs annual additions will fall from approximately 300 GW in 2025 to about 200 GW in 2026, a decline so steep that no other region will be able to compensate. A major policy shift in mid-2025 â from guaranteed pricing to competitive bidding â triggered a dramatic slowdown after an initial rush of installations. This led to a sharp drop in Chinese volumes in the second half of the year, creating intense price pressure and ultra-thin margins across the supply chain. 10% decline For the first time ever, global solar additions are expected to decline year over year, albeit by less than 10%. This anticipated contraction marks a turning point. For the first time ever, global solar additions are expected to decline year over year, albeit by less than 10%. While this signals the end of uninterrupted growth, it does not imply stagnation. Over the next five years, cumulative photovoltaic capacity will still double, supported by emerging markets, diversification into storage and innovation in operations and maintenance. The industry faces a new dynamic â growth without the guarantee of ever-increasing annual volumes â forcing consolidation and strategic shifts. But low module prices and solarâs inherent scalability will continue to unlock new markets. Such a prediction comes with caution. Analysts have systematically under-called the solar market for many years. Policy changes can alter the outlook significantly and suddenly, and market elasticity continues to surprise. Whether the market declines or not, what is significant is our arrival at the point where we can start talking about a peak in global demand growth. Back to Top Grid infrastructure key Download report Grid modernization becomes a key constraint in energy security, transition and competitiveness In 2026, grid infrastructure moves center stage. For decades, grid investment has lagged the pace of energy decarbonization and energy innovation across many markets. This underinvestment has now become a critical bottleneck. As the world races to address expanding energy needs â electrification, decarbonization and digitalization â the grid must evolve or risk becoming the weakest link in power systems. Power sector decarbonization in the EU â where 40% of EU grids are over 40 years old and built for a fossil fuel era â requires increasing investment in grid infrastructure to improve reliability and reduce dependence on gas. The European Commission estimates that â¬584 billion in grid capital expenditure is needed by 2030, rising to â¬1.2 trillion by 2040. Yet, permitting delays â averaging 12 to 17 years for new transmission lines â and the lack of dedicated investment vehicles make upgrading existing mid- and high-voltage infrastructure a more viable near-term solution. The US faces its own grid challenges. Explosive data center growth and power needs, driven by AI and cloud computing, are straining local and obsolete grids. Without urgent investment and smarter planning, the US risks a capacity crunch and even grid instability. Across the industry, calls are mounting â from hyperscalers to utilities and policymakers â to tackle structural roadblocks to power infrastructure buildout. Proposals range from expanding tax credits to streamlining permitting and accelerating component manufacturing, signaling a shared recognition that grid modernization is now a national competitiveness issue. The grid is no longer just enabling infrastructure. It is critical infrastructure. For policymakers, utilities and investors, the message is clear: The energy expansion required to satisfy AI-driven demand growth will only move as fast as the grid allows. The energy expansion required to satisfy AI-driven demand growth will only move as fast as the grid allows. Back to Top Hybrid PPAs rise Download report Flexible PPAs become the new standard as price volatility reshapes risk management Increasing renewable capacity â especially solar PV â is leading to more zero- and negatively priced settlements in wholesale markets. This volatility is forcing a rethink in commercial structures: The market is moving from plain PPAs to flexibility-backed hedges, with hybrid PPAs combining multiple technologies and storage, to manage risk and monetize flexibility. For now, the market is in a âbrainstormingâ phase: Utilities and energy companies are early adopters of structured and flexibility products, while corporates and renewable developers are still catching up and often rely on simpler structures with less-nuanced risk allocation. A shift toward shorter contract terms and stronger downside protections could follow as capture rates deteriorate. Extreme price swings are most visible in Europe, where Platts, part of S&amp;P Global Energy, reports that PPA price indexes in Spain and Germany remain well below solar PV cost-based levels. Platts also notes wide spreads between buyer and seller expectations, reflecting changing perspectives amid rising risks of declining capture ratios and increasing zero and negative prices. Meanwhile, standalone and co-located battery energy storage systems (BESS) deals are rising, with strong growth underpinned by additions expected through 2026 in the US (Texas, California ), Europe (Germany, UK) and Australia. The US will be installing almost 15 GW of new BESS capacity in 2026, with Germany and Australia following with 5 GW, and the UK with 3 GW. In an environment of slowing sustainability commitments and uncertainties tied to greenhouse gas Scope 2 protocol guidance revisions, we are seeing fewer announced clean energy procurements, with S&amp;P Global Energyâs Corporate Renewables Contracts database showing that global corporate PPA activity has slowed. After a strong start to the year, third-quarter 2025 activity has touched a multiyear low across the globe, with only 9.5 GW in announced deals, compared with 13.9 GW in third quarter 2024. However, data centers have continued to procure clean power at the same level as in 2024, with 27 GW of PPAs announced through October 2025, accounting for over 43% of the total PPAs, compared with 36% in 2024. They remain the largest PPA offtakers globally in 2025, a trend expected to continue. Back to Top Chinaâs green H2 Download report As the rest of the world slows down, China gets serious about green hydrogen Hydrogen has been presented as the leading âgreen moleculeâ needed to decarbonize hard-to-abate sectors. However, even as global uptake has fallen short of ambitious expectations, China has emerged as the global leader in electrolytic (âgreenâ) hydrogen, with domestic deployment and exports set to grow exponentially in 2026. Green hydrogen is central to Chinaâs plan to dominate clean energy supply chains, mirroring its approach in solar and batteries. Policy support (including mentions in the 14th and 15th Five-Year Plans), regulatory changes and supply-side engineering have laid the foundation for rapid growth. This began to materialize in 2025: Chinese projects will install about 1.5 GW of electrolyzers in the year, nearly doubling the 1.7 GW total installed globally at the end of 2024. Almost 10 GW is under construction, and deployment is projected to reach 4.5 GW in 2026 and 6.9 GW in 2027, expanding global electrolysis capacity eightfold in just three years. Companies have piled in, creating over 50 GW per year of stated manufacturing capacity. Oversupply is driving fierce competition and steep price declines: Electrolyzer stack prices have plunged from $250/kW in early 2024 to under $100/kW, with similar system cost reductions. Chinese suppliers are also ramping up exports, with projects in Central Asia, Africa, South America and the Middle East procuring Chinese equipment over the past 18 months. Chinese firms aim to export energy as well as technology. At least two green ammonia plants have received EU renewable fuels of nonbiological origin (RFNBO) certification, paving the way for clean molecule exports. Price indications suggest Chinese players will sell at about $600per metric ton of ammonia FOB â about double the gray ammonia but competitive in Europeâs tight market. Prices should fall as first-of-a-kind challenges ease. Renewables oversupply creates pressure on power sector margins and utilization. Green hydrogen offers a strategic outlet: Converting excess electricity into molecules enables China to âmove electronsâ from northern provinces to other markets. To support this, China is investing heavily in hydrogen pipelines and port facilities for ammonia and methanol exports. The global hydrogen revolution has, so far, not materialized. But it is clearly emerging in the worldâs largest consumer of energy. In 2026 and beyond, one question looms: Will China export technology, molecules or both? Back to Top SAF grows up Download report Global SAF capacity expands by one third in 2026; Asia leads, Europe pays Horizons data show aviation accounts for about 3% of global energy-related CO2 emissions . Air travel has rebounded strongly after the COVID-19 dip, and continued growth is projected. Many airlines have pledged to reach net-zero carbon emissions, and current decarbonization efforts focus on reducing the carbon intensity of existing fuels, scaling up use of SAF, enhancing aircraft efficiency and utilizing carbon offsets. SAF growth will continue in 2026, but the pace slows. Global dedicated SAF capacity is expected to rise by about one third to 8 MMt; a strong increase but below the near-doubling seen annually from 2022 to 2025. The SAF market is still very small, at less than 0.5% of global jet fuel consumption. 3% in 2025 S&amp;P Global Energy data show aviation accounted for about 3% of global energy-related CO2 emissions in 2025. The industry is responding to trends in SAF consumption, which has surged since the start of the decade. The year 2025 was particularly strong, with SAF mandates introduced in the EU and the UK boosting demand. S&amp;P Global Energy estimates that SAF consumption more than doubled in 2025 to reach 2 million metric tons (MMt). In contrast, growth in 2026 will be less pronounced as EU targets remain unchanged and policy shifts in the US make SAF production less attractive. Investments are accelerating in Asia, where producers benefit from lower production costs and abundant feedstock supplies, particularly used cooking oil (UCO). More than half of global SAF capacity will be concentrated in Asia in 2026, even though regional demand remains modest. Asian producers are targeting the European market, which is forecast to face a supply shortfall and where willingness to pay is high. Beyond 2026, investments in SAF plants could accelerate sharply, with capacity potentially increasing eightfold to 42 MMt by 2030 if all announced projects materialize. Most projects are in North America (15.8 MMt), Asia (13.4 MMt) and Europe (7.2 MMt). However, only 7.3 MMt of capacity has reached a final investment decision, leaving 28.5 MMt still awaiting approval. Today, SAF is produced mainly via the commercially mature and cost-effective hydroprocessed esters and fatty acids (HEFA) pathway. One third of announced projects by 2030 plan to use newer technologies such as alcohol-to-jet (ATJ), gasification + Fischer-Tropsch (FT), methanol-to-jet (MTJ) and others. These face structural headwinds: technical challenges with integrating early-stage processes, high capital expenditure and production costs, reliable feedstock supply chains, and demand and price uncertainty. Overcoming these hurdles will be key to scaling up capacity if SAF is to remain a critical lever for decarbonizing aviation. Back to Top Global EV sales surge Download report China shows that EVs can be price-competitive with conventional ICE vehicles Global EV sales appear set to climb further in 2026. Yet, as in years past, adoption rates are likely to be uneven among key markets. An examination of world EV adoption begins and ends with China. Owing to the large size of Chinaâs vehicle market and its relatively large EV share, about two out of every three light EVs sold globally in 2025 are estimated to have been sold in China. Further, China is increasingly âexportingâ EV price deflation to the rest of the world. In 2025, China accounted for nearly two-thirds of global light EV sales. China appears on track for the full-year 2025 to become the first major âEV majorityâ new sales market globally â with battery-electric vehicles (BEVs) and plug-in hybrid electric vehicles (PHEVs) representing about 50% of new light vehicle (LV) sales in the first three quarters of the year. This is because EVs in China have, generally speaking, reached price parity with conventional internal combustion engine (ICE) vehicles, spurred by intense competition among automakers and suppliers. With EVs price-competitive with conventional ICE vehicles, Chinaâs EV share is set to keep rising in the years ahead as public chargers become more ubiquitous â and faster â reducing the âcost of inconvenienceâ of driving an EV. In Europe, after two years of stagnation, the EV market is showing signs of life in 2025. A key reason is a step-up in the stringency of EU CO2 standards. Automakers in Europe have brought new EV models to market and offered discounts to consumers to help meet the tighter standards. Looking ahead, the prospect of tighter EU CO2 regulations in 2030 and 2035 â even if potentially looser than what is currently in place â together with intensifying competition from Chinese automakers, is likely to spur the regionâs current market leaders to develop and price competitively new BEV models, supporting EV adoption. As for the US, in 2025, domestic EV policy once again swung sharply, with the federal government undoing support for EVs â both âcarrotsâ and âsticks.â The year 2026 will be the first in the modern EV era in which federal EV tax credits are not available to US consumers. The US auto industry is now undergoing a test of the strength of âorganicâ consumer demand. One trend that bears watching is how automakers position their EVs in a post-subsidy world as they move beyond the early adopter market. The rest of the world is a diverse grouping, and thus EV adoption will vary widely from market to market. A common variable, though, will be the extent to which policy constrains imports of Chinese EVs and localized production, with more open markets experiencing a tailwind. Recent analysis by S&amp;P Global Energy suggested that Thailand, Indonesia, Pakistan, Mexico, Nigeria and Malaysia are among the emerging market economies relatively ripe for the adoption of Chinese EVs. Back to Top Aligning carbon standards Download report Global trade and climate policy is increasingly focused on harmonizing emissions reporting What are GHG emissions? When it comes to corporate reporting, the definition can and often does differ. Early efforts to standardize emissions reporting were designed to be flexible so that they could apply across sectors. This intentional flexibility, however, has resulted in differences in how emissions are quantified and reported, limiting its utility. There is growing consensus that inconsistencies in product-level carbon accounting need to be addressed, and harmonization is a prerequisite for the market to differentiate products based on carbon intensity. The Sustainable Business COP, which was launched ahead of the 30th Conference of the Parties (COP30), featured carbon accounting as a key issue, with a new industry association, Carbon Measures, looking to accelerate the rollout of more robust product-level carbon accounting. Meanwhile, major revisions are being proposed for the worldâs leading emissions accounting standard â the GHG Protocol â to align reporting with current market realities. Changes in Scope 2 treatment can have wide-ranging implications for corporate choices to address power emissions. In 2026, carbon accounting is expected to heat up as a high-profile topic. Potential proliferation of regulations like the EU Carbon Border Adjustment Mechanism (CBAM) require companies to report different emissions to different regulators, complicating trade. The CBAM will take effect on Jan. 1, 2026, requiring accountability for the carbon intensity of goods imported into Europe, even as key policy elements will only be finalized at the 11th hour. Key countries around the world are introducing their own emissions pricing systems, which would lessen the impact. Among key policy questions is: Will the EU introduce export rebates to reimburse carbon costs for EU products to boost their competitiveness on global markets? Some of the EUâs major trading partners pushed back on CBAM at COP30. Criticism made it into the final COP Presidency report, promising more debate to come. Back to Top Energy geopolitics evolve Download report China leverages global clean energy leadership as US influence wanes The strategic energy divide between China and the US will widen in 2026. China has consolidated its leadership in clean energy technologies and supply chains, reinforcing its influence through state-led industrial policy and active climate diplomacy. Chinaâs cleantech overcapacity and weakening domestic demand make the export of cleantech products an economic imperative and a tool for geopolitical power projection. The US, meanwhile, is prioritizing fossil fuel exports. However, this approach depends on stable trade relationships at a time when tariff measures and shifting trade policies add complexity to global energy markets. These dynamics may influence how emerging economies weigh their options between fossil fuels and clean technologies. Chinaâs offering aligns more closely with long-term climate strategies, even as export controls on rare earth elements highlight supply chain vulnerabilities. 30% increase in cleantech spending over the next five years, with most of it moving East. Global financial flows in the energy sector reflect this trend. Spending in cleantech grows by nearly 30% over the next five years, while upstream spending remains roughly constant in real terms. The majority of new spending is moving East. Washington is adopting a more interventionist industrial strategy. Expect greater government involvement through equity stakes, price floors for critical minerals and targeted support for technologies such as nuclear and advanced geothermal. This marks a significant shift from the USâ historic model of funding early-stage innovation and letting markets pick winners and losers. A more interventionist approach provides clear signals for private capital as to which sectors and companies are favored. However, it also introduces new questions about competitive dynamics and the conditions for government backing. Meanwhile, surging AI-driven electricity demand is accelerating an energy expansion mindset, echoing Chinaâs decades-long linkage of energy policy with national security. Diplomatically, the contrast remains sharp. China continues to position itself as an active participant in climate negotiations, building on its role since the Paris Agreement and having recently released new emissions targets. The U.S., by comparison, has taken a more selective approachâskipping COP30 and challenging multilateral efforts such as International Maritime Organisation (IMO) shipping emissions pricingâcreating space for China to expand its influence. Back to Top Adaptation gap Download report With emissions potentially driving a 2.3-degree-C temperature rise by 2040, adaptation shifts from optional to essential in 2026 Extreme weather and climate hazards are creating on-ground risks for infrastructure, physical assets and the companies that operate them. The global average temperature from January to August 2025 was 1.4 degrees C above preindustrial levels â just short of the Paris Agreementâs 1.5-degree-C limit â and Horizons climate scientists estimate that there is a 50% likelihood of it exceeding 2.3 degrees C by 2040. A warmer, more volatile climate means extreme heat, drought, tropical cyclones and other hazards are likely to become more common and more severe and will incur heavy costs. These hazards are already posing challenges to communities and industries. A historic drought in Iran has led to the prospect of water rationing in Tehran and the near depletion of hydropower capacity. Soaring summer heat across Europe â where temperatures are expected to rise faster than in many other regions â is driving rapid adoption of air conditioning, stretching electric grids in countries where per-capita electricity consumption has been much lower than in the US. The cumulative economic effects of climate hazards â lost revenue from business interruption, repairs to physical damage and reduced employee productivity â translate into rising financial costs for companies. Given the observed trajectory of climate change, these costs will increase alongside physical risks. The Horizons Physical Risk dataset projects annual costs of about $885 billion in aggregate for large publicly traded companies in the 2030s. About $885B annual costs at risk The increasingly urgent question is no longer whether companies will adapt, but how â and how quickly. Climate risk assessments and physical risk adaptation planning are critical for resilience. Yet uptake across sectors remains patchy, according to data collected in the S&amp;P Global CSA. Industries historically under greater climate scrutiny, and with operational exposure such as electric utilities, grid operators, and oil and gas companies, show the highest rates of risk assessment and adaptation planning. In other parts of the global economy, risk assessment and adaptation planning remain the exception rather than the rule. Back to Top What's next? Download report In 2026, AI-driven load growth, grid bottlenecks, cleantech market fragmentation and geopolitics, evolving energy procurement strategies and carbon accounting, and rising physical climate risk will redefine the terms of progress. Chinaâs dominant position across cleantech supply chains â from solar and storage to green hydrogen and EVs â drives deployment but also generates new risks and will be a key factor in shaping the outcome of the China-US AI race. Back to Top Authors: Roman Kramarchuk, Francesco dâAvack Contributors: Anna Mosby, Brian Murphy, Bruno Brunetti, Christoph Berg, Conway Irwin, Cormac Gilligan, Edurne Zoco, Ina Chirita, Jeff Meyer, Kelly Morgan, Kevin Birn, Matt Macfarland, Sam Wilkinson Design: Content Design Let's Talk Interested to learn more? Contact our sales team. Complete the form and a team member will reach out to discuss how our solutions can support you. Section Section Section First Name* Last Name* Business Email address* Company (full legal entity)* Job Function* Job Function Industry* Industry Country/Region* Country/Region State* State City* Zip/Postal code* Phone Number* Country/Region of Residence* Country/Region of Residence [Yes] I would like to receive S&amp;P Global Energy promotional emails. Clicking on the confirm button means that you acknowledge that you have read and agree to our Terms of Use and Privacy Policy, including transfer of your personal information outside of the jurisdiction in which you are located . Confirm ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/podcasts/private-markets-360/private-markets-360-episode-51-davidson-kempners-approach-to-navigating-dislocation-in-private-markets</link><description>In this episode of Private Markets 360Â°, we welcome Melanie Levine, Partner and Global Head of Client Partnerships and Business Development at Davidson Kempner. Melanie shares her insights on how Davidson Kempner differentiates itself in the competitive landscape, the impact of current market trends on investor allocations, and what lies ahead for private markets. Melanie also discusses her journey to Davidson Kempner, from being the second hire on the fundraising team to co-managing the client</description><title>Private Markets 360Â° | Episode 51: Davidson Kempner&amp;apos;s Approach to Navigating Dislocation in Private Markets</title><pubDate>18 September 2026 04:00:00 GMT</pubDate><author><name>Jocelyn Lewis</name><name>Chris Sparenberg</name></author><content><![CDATA[ Podcast â18 September, 2026 Private Markets 360Â° | Episode 51: Davidson Kempner's Approach to Navigating Dislocation in Private Markets By Jocelyn Lewis and Chris Sparenberg In this episode of Private Markets 360Â°, we welcome Melanie Levine, Partner and Global Head of Client Partnerships and Business Development at Davidson Kempner. Melanie shares her insights on how Davidson Kempner differentiates itself in the competitive landscape, the impact of current market trends on investor allocations, and what lies ahead for private markets. Melanie also discusses her journey to Davidson Kempner, from being the second hire on the fundraising team to co-managing the client partnerships and business development team today. Credits: Host/Author: Chris Sparenberg and Jocelyn Lewis Guests: Melanie Levine Producer: Georgina Lee Published With Assistance From: Feranmi Adeoshun, Kimberly Olvany View Full Transcript Chris Sparenberg [00:00:00]: Welcome to Private Markets 360, your insider's guide to the world of private investments. Today, we're thrilled to have Melanie Levine, partner and global head of client partnerships and business development at Davidson Kempner, joining us. With over 2 decades at Davidson Kempner, Melanie has been instrumental in building out the firm's global sales, investor relations, client service, and product development teams. Her extensive experience across fundraising, capital formation, and business development provides a unique perspective on the evolution of alternative investments, particularly how changing investor needs and evolving market dynamics are shaping allocations across alternative investments. Today, Melanie will share her insights on how Davidson Kempner differentiates itself in the competitive landscape, the impact of current market trends on investor allocations, and what lies ahead for private markets. Melanie will also discuss her journey to Davidson Kempner, from the second hire on the fundraising team to co-managing the client partnerships and business development team today. Melanie, welcome to Private Markets 360. It's great to have you with us. Chris Sparenberg [00:01:07]: How are you? Melanie Levine [00:01:08]: Doing great. Thanks so much for having me. Jocelyn Lewis [00:01:10]: We're thrilled to have you, Melanie, and we would love to start off with you sharing a bit about your career journey and how Davidson Kempner has evolved during your 20-plus years at the firm. And if you can also share insights from your background that have shaped your approach today. Melanie Levine [00:01:32]: Sure, happy to. I'll start with my career journey. I graduated from the Wharton School undergraduate class of 2000 after spending several summers in investment banking. My last summer actually was in equity capital markets at Merrill Lynch. This was during the 1999 tech bubble. Which actually has some very interesting similarities to the current AI bubble. But during that summer, I worked very closely with institutional equity sales, just collaborating on selling IPOs and secondary offerings. And that's really where I realized that I enjoy discussing and generating investment ideas much more than traditional banking analysis and number crunching. Melanie Levine [00:02:17]: So I really took a less conventional path after graduating Wharton at that time, I declined my full-time investment banking return offer and started interviewing to pursue institutional equity sales roles exclusively. So after I graduated, I joined Goldman Sachs in institutional equity sales. I was there for about 4 and a half years. I was developing and pitching equity investment ideas to hedge fund clients during that time. I then joined Davidson Kempner in January of 2005. I first focused on expanding the firm's non-US investor base. I helped launch a new hedge fund product in mid-2005 after the firm had operated with only a single hedge fund strategy for its first 20 years. So I've spent nearly the last 22 years at Davidson Kempner building out the global sales and client service platform. Melanie Levine [00:03:11]: Across wealth and institutional clients while institutionalizing the investor experience through dedicated product management teams, communications, client service, product specialists, and product development teams. So when I think about DK's evolution over nearly 22 years, I've been part of a great growth story from about $5 billion to over $40 billion in AUM. When I joined back in 2005, we had one strategy. I was the 28th employee, and today we're approaching 500 people across 8 global offices, and we reached our peak AUM of over $40 billion. So DK's really expanded from a single strategy to a diversified global platform. We grew from our merger arbitrage and distressed debt roots into more of a global investment platform spanning credit, convertible arbitrage, long-short equity, asset-based finance, opportunistic credit, and real estate, really across the liquidity spectrum. So we've been investing for over 40 years now across multiple cycles, and we've had 3 generations of leadership. So I think of today as DK 3.0, following our 3rd successful leadership transition back in 2020. Melanie Levine [00:04:28]: So in our view, we've continued to grow without becoming asset gatherers. We've been very disciplined about growth, and alignment really remains our core focus. As a private partnership, we're 100% owned by our partners and employees and invested alongside our clients and really focused on their long-term interests. So the culture has scaled, but the DNA hasn't changed. Despite the growth, we remain rooted in teamwork, collaboration, and a commitment to our investors. You asked about career insights that I would tell my younger self. So I would really say, don't follow the herd, follow your strengths. Melanie Levine [00:05:03]: Try to be independent-minded, know what you enjoy and where your natural talents lie, and have the confidence to choose your own path. Had I followed the more traditional route that was much more conventional at that time, I would've started in investment banking rather than sales. So my career may have looked very different. Chris Sparenberg [00:05:22]: Certainly seems like it would've, and that is a tremendous amount of growth that's happened in your time with the firm. I'm interested in digging into the culture element of that. So scaling assets, scaling people, but keeping the culture intact is critical, and I'm sure it's not an easy job. Can you tell us how Davidson Kempner's culture differs from other firms and how it contributes to the firm's longevity and success in navigating various market cycles? Melanie Levine [00:05:48]: Yeah, sure. The people and the culture are the big reason why I've stayed at DK for nearly 22 years. It's really a meritocracy. People are given more responsibility as they earn it. Long tenure is really part of our DNA. So my story's not unusual. Our CIO and managing partner, as well as 4 other of my partners, even started as summer interns. And the 14 active equity partners today have an average tenure at DK of roughly 16 years. Melanie Levine [00:06:19]: So at Davidson Kempner, we really try to develop leaders from within. We hire laterally, of course, when it makes sense, but many of our leaders have grown up at the firm. So that really creates continuity while allowing the organization to evolve. And our ownership structure really creates great alignment. We're 100% privately owned, and the partnership's the largest investor across our funds. So we're really invested alongside our clients. We like to say we really drink our own wine or eat our own cooking. And that alignment also drives collaboration. Melanie Levine [00:06:51]: Partners participate in the overall economics of the firm rather than being compensated only on their individual strategy or P&amp;L. So it's very different from a pod model. So it encourages people to work across strategies, geographies, and asset classes. So we can follow opportunity and don't have just organizational silos. As markets change, we're constantly comparing relative value and we really just allocate capital where we see the most compelling risk-adjusted returns, either across geography or even across collateral type. So over 40-plus years, we've evolved without changing our investment DNA. Across market cycles, we've remained very disciplined about investing. Because we want to focus where we have the people, sourcing relationships, underwriting expertise, and really operational resources where we can create an edge. Melanie Levine [00:07:47]: But there's a constant desire to get better at DK. We're constantly re-underwriting not just our investments, but our processes, our strategies, our investment platform. So ultimately, I think our longevity really comes down to 3 things: our aligned incentives, the collaborative culture, and our long-term discipline. Chris Sparenberg [00:08:08]: That discipline has certainly helped you scale, and I'm sure the focus on self-improvement is a critical piece to all of that. Let's talk about differentiators and strategies a little bit. You mentioned Davidson Kempner operates across various alternative strategies. I know you're active in hedge funds, opportunistic credit, real estate. There are other alternatives on the platform. Can you tell us what makes DK different from other alternative managers? How do these strategies differ in how investors utilize them, and both for the specific purposes, but then also across overall portfolios? And then thinking about the global scale as well, there's a lot to take into account there. Melanie Levine [00:08:46]: Yeah, absolutely. If you start with what we think really differentiates DK, we're built to follow opportunity where it exists, not just a benchmark or a silo. So our mandate is global and flexible. So this allows us to constantly compare relative value across geographies, strategies, asset classes, and the capital structure. We believe our crossover credit capability is a real competitive advantage. We can invest across public and private markets, credit and equity, and really the liquidity spectrum gives us a wider aperture to find attractive risk-adjusted returns. So part of our DNA really is turning dislocation into opportunity. We often gravitate towards markets or situations that we believe are less trafficked, more complex, or have higher barriers to entry where experience and sourcing really can matter. Melanie Levine [00:09:44]: We've been a distressed investor since the '80s, so we're comfortable with complexity. We're comfortable with workouts, restructurings, and really enforcing creditor rights. As we like to say, we're not in the origination business, we're in the repayment business. So we really try to combine global reach with local expertise. So research-driven underwriting, operational capabilities, and really deep local sourcing relationships allow us to identify and execute these opportunities globally. So if you want to turn the discussion to how investors really use our strategies within their portfolios, in our view, we think the different DK strategies really solve different portfolio needs. So investors could use us for absolute return and risk mitigation or diversification, opportunistic credit exposure, real estate, or really access to less liquid and more complex opportunities. Melanie Levine [00:10:45]: So we think our event-driven multi-strategy approach can really serve as a portfolio ballast within a portfolio. The objective is to compound attractive returns, really with low correlation to traditional equity and credit beta and relatively low volatility. We believe that ballast can give investors room to take risk elsewhere. So many of our longtime endowment and foundation clients, some of which we started working with back in the '90s, use our more liquid strategies alongside higher-octane closed-end private market funds. So for some investors, absolute return can play a role traditionally occupied by fixed income or even cash. But globally, the portfolio may differ, but the underlying need is really similar, whether investors characterize us as hedge funds, credit, alternatives, or absolute return. We believe they're really looking to DK for diversification, the downside resilience, and really differentiated sources of return. So ultimately, I think what differentiates DK is really a combination of global and flexible mandate, that crossover credit capability, our global sourcing advantages, and the decades of experience just navigating complexity. Melanie Levine [00:12:07]: I think this gives us the ability to where we believe we can really focus on the best risk-adjusted opportunities that exist at any given market cycle. Jocelyn Lewis [00:12:18]: It really sounds like there's just a wealth of knowledge at Davidson Kempner, and you've provided a really helpful overview of what makes Davidson Kempner distinct in all the different roles that these strategies can play for your investors. with such a global and flexible mandate that you've mentioned. Melanie, building on that, let's explore how you translate that breadth into portfolio construction discussions with clients. And with so many capabilities that you've mentioned across your platform, how do you help each individual investor determine where your strategies fit in their portfolio and how Davidson Kempner fits within the broader alternatives landscape? Melanie Levine [00:13:08]: Sure. I always say that the real secret to dealing with clients is to be a really good listener. So we have to think about our strategies first and foremost by the role they can play in a client's portfolio. So really across the platform, we think our funds can be meaningful diversifiers and really durable contributors through different market cycles. Our hedge fund strategies, we believe, are risk mitigators. We also believe our closed-end strategies are diversifiers within private credit portfolios. So we believe that some investors use our hedge fund strategies as fitting within a portable alpha program. Some use us in an absolute return program, or even an alternative to portions of fixed income. Melanie Levine [00:13:54]: Our private strategies can play a different role. We believe that clients with significant direct lending exposure may use our closed-end opportunistic credit strategies as a diversifier within private credit. Similarly, we believe that investors with substantial core real estate exposure may use our opportunistic real estate strategies to diversify that allocation. So we think that structure should really match the underlying opportunity. So more liquid strategies belong in vehicles that provide appropriate liquidity, while private and less liquid opportunities are better suited for closed-end drawdown structures. So a big part of our job here is education. And again, that really does start with listening. So we need to understand what an investor is trying to accomplish and then really clearly articulate why they might own a particular DK strategy. Melanie Levine [00:14:50]: And then we determine what role it could play and really how it complements what they already own. So we like to say that we go where others retreat. Our history has been about turning dislocation into opportunity, but having the flexibility, experience, and resources to provide capital when others may be constrained or stepping away. So our consistent investment philosophy really connects the platform. All of our strategies are grounded in rigorous underwriting, downside protection, and disciplined risk assessment, really due to our credit discipline. So we believe investors will benefit from the scale and breadth of this broader DK platform. But investor education doesn't end when someone invests. It's a continuous process here. Melanie Levine [00:15:38]: We've built a robust product specialist and investor relations organization. To provide transparency and really help clients understand not only what we're investing in, but why we're making these investments. So really, if I had to summarize our place, I think we aim to provide differentiated sources of return, really thoughtful diversification, and also that disciplined downside protection. So that's really the focus across the global platform. Jocelyn Lewis [00:16:08]: I really think it's so important to really listen to clients. Chris and I can really relate to that because we're out talking with clients every day as well. And like you mentioned, they all have different needs, and especially now with the private markets just continue to evolve and expand and change over time. So it's a really great way that you've where each of your strategies fits within a portfolio and taking a step back from your platform specifically. You're also having conversations with investors globally and seeing how they're approaching today's market environment and the unique characteristics or the unique items that they're really focused on. So I'm curious how those perspectives compare across different regions and investor types. Are you seeing meaningful differences in how allocators around the world are thinking about today's investment opportunities, where they want to deploy capital and which strategies they favor, or are priorities becoming more aligned? Melanie Levine [00:17:18]: Yeah, I think I'd really categorize it as global themes with meaningful regional and investor-specific nuances. So across the board, we're hearing from clients about a greater focus on liquidity, resilience, flexibility, diversification, uncorrelated returns. So investors today are really seeking strategies that will capitalize on market dislocations, but also complement or serve as diversifiers from existing exposures. So investors are increasingly seeing benefits of absolute return strategies. Over the last 12 months, we've seen existing hedge fund allocators and consultants increasing their allocations, particularly across the institutional market. However, we're not yet seeing new entrants or those who left absolute return reentering. I'm hopeful that they will, but not yet seeing that. In private capital though, liquidity is still very scarce and it's really hard to replace an incumbent manager. Melanie Levine [00:18:23]: Regional nuances remain important, as there are regulatory considerations and different risk appetites across the globe. But we try to have conversation tailored to each investor's objectives. So we wanna showcase the breadth of our platform, but be a solution provider. We wanna really meet investors where they are. Our job is to show how when added to a portfolio, in our view, our strategies can really serve as a diversifier. So I think, really, as far as the differences between the US versus international markets, over the past 12 months, we've seen the strongest increase in hedge fund strategy allocations and liquid alts from US investors. But that said, interest is by no means limited to the US. Melanie Levine [00:19:09]: Our pipeline actually includes several sizable international allocators. So that does suggest to me that the appetite for hedge fund strategies is increasingly global and increasing globally as well. If I think about endowments and foundations versus pensions versus other institutional investors, endowments and foundations have often used Davidson Kempner as a portfolio ballast, particularly alongside their historically larger allocations to venture capital and other less liquid, higher-octane strategies. But we're starting to see the pendulum shift a bit. After several years of constrained distributions, reduced deployment, improving DPI year to date is giving some endowments and foundations greater flexibility to increase allocations to alternatives again. And really over the last 6 to 12 months, conversations have increasingly moved from managing liquidity constraints to selectively putting capital back to work while still maintaining that strong focus on liquidity and diversification. Pension funds on the public side often come at it differently. Melanie Levine [00:20:20]: Many have substantial direct lending and private market exposure in private credit. So we're generally not seeing the same appetite to simply add more illiquidity. Conversations increasingly about what is truly additive and a diversifier to what they already own. Internationally, the objectives can be similar but may differ. So there's regulation to contend with, liquidity requirements, risk appetite, governance, and then existing portfolio constructions really does vary by region. So there really isn't any one-size-fits-all solution. So that's, I think, where the breadth of our platform is helpful. So rather than starting with what products can we sell, we have to really think about what does this investor's portfolio need? And then determine whether a liquid absolute return strategy, some opportunistic credit, real estate, or another part of the platform can really address that specific investor's need. Melanie Levine [00:21:22]: So the common thread globally really is that investors are being more intentional and there's really that focus on a total portfolio. They're asking not simply, is this an attractive strategy? But you have to really think about what does this add to my total portfolio? In our view, our job is to demonstrate how a decay allocation can provide genuine diversification and really improve the overall portfolio. Chris Sparenberg [00:21:50]: And of course, all this is happening against the backdrop of a vastly different market than we were facing 20 years ago. So investors are making different decisions, but market mechanics themselves have changed. Davidson Kempner described today's environment as being the early innings of a broader capital structure reset as rates remain elevated. How do you expect this shift to influence investors' asset allocation decisions and the overall portfolio construction that they're considering? Melanie Levine [00:22:18]: So when we talk about that capital structure reset, we're really talking about the consequences of moving from the decade of cheap money to a more normalized cost of capital. So that adjustment takes time, and we think that we're still in the early innings. So for investors, that should change the portfolio construction conversation. So we believe the last decade rewarded owning beta and illiquidity. So going forward, we believe there'll be greater value in liquidity, flexibility, active management, and strategies that can really capitalize on dispersion and dislocation. So we think expectations around private credit are going to need to reset as well. Significant capital formation across direct lending has really compressed spreads and in some cases weakened lender protections. So we believe traditional private credit should increasingly be viewed more as a single-digit return asset class rather than something that consistently delivers double-digit returns. Melanie Levine [00:23:22]: But at that same time, the stress is creating opportunity. Higher rates are putting pressure on capital structures, and these capital structures were built for a very different rate environment. So extensions, PIK, liability management exercises, they all can postpone that stress, but they don't necessarily eliminate it. So that makes the flexibility across the capital structure increasingly value. So we believe the ability to move between public and private, performing and stressed, liquid and illiquid credit can provide a significant advantage as opportunities migrate from one market to another. And we believe it also makes opportunistic credit and asset-based finance increasingly interesting portfolio complements. So we're seeing investors looking beyond traditional direct lending towards strategies where collateral structure, underwriting expertise and complexity can really create differentiated sources of return. So as we also think this could be a very interesting decade for absolute return, just given the higher dispersion and higher rates, you can see more idiosyncratic winners and losers. Melanie Levine [00:24:34]: So that's an attractive backdrop for event-driven strategies that we don't really need markets to go up to generate returns. So you see that dispersion really in something like AI. It may create tremendous economic growth, but also creating winners and losers. So private market portfolios may not necessarily capture all the upside, but they could be still exposed to businesses that are disrupted. So that's another reason why you need diversification and truly active risk management. So this reset's global. But it isn't happening everywhere at the same speed. So we believe the US direct lending is highly competitive today, but parts of Europe and Asia may offer different points in the cycle, so they may be more attractive risk-reward. Melanie Levine [00:25:23]: And we believe that this global platform really allows us to widen the aperture so we don't have to force capital into the most crowded markets. So the big portfolio implication we believe will be further diversification, really beyond traditional beta and traditional private credit. So we believe the next several years could really reward investors who preserve liquidity and give managers the flexibility to really go where the dislocation is rather than trying to predict exactly where it will occur ahead of time. Chris Sparenberg [00:25:59]: It's a great point on how LPs are gearing up for, or rather, reacting to the market and its changes. And I imagine that's not even across the global landscape. But when we think about the current economic environment and the points you're making around preserving liquidity, and I would say thinking tactically a little bit more, what does that do for driving demand for strategies that DK offers? What's attracting capital that, that might not have a year ago? And what specific opportunities are you seeing on the horizon? Melanie Levine [00:26:32]: I think what's changed is that investors are really looking for strategies that can benefit from complexity rather than just simply providing market exposure. So there's been particular interest in absolute return strategies so far year to date in 2026. We've seen an increased opportunity set to invest in US liquid credit. Convertible arbitrage strategies have remained very interesting in both the US and Asia. Convertible arbitrage has been interesting over the last few years, just as we've seen increased issuance given the more normalized rate environment. But we don't think that's ending anytime soon. And we think the backdrop for absolute returns is especially compelling. And we think investors are really starting to warm up to the strategy again. Melanie Levine [00:27:17]: We've really seen that over the last 12 months, just given the higher rates, the dispersion, and the volatility. So there's been more idiosyncratic winners and losers. So this is an environment that we think favors active event-driven investing rather than just relying on markets to move all in one direction. So we've even said this in a white paper that the 2020s could be the decade of absolute return. We believe investors are increasingly focused on strategies that can offer this diversification from traditional equity and credit beta. In credit so far in 2026, I mentioned we've been excited about the US liquid opportunity set. I think this combination of maturity wall, refinancing needs, and just these capital structures adjusting to higher rates are creating more opportunity for our flexible capital. AI's been another source of dispersion, creating winners and losers. Melanie Levine [00:28:19]: So that's generated opportunities for us in areas like convertible arbitrage and credit. But the key for us is not having to predict which single opportunity will dominate. In our view, the global flexible mandate really allows us to capture these opportunities across geography, asset class, and capital structure. So we can move capital where we see the best risk-adjusted opportunities as they emerge. So I think ultimately in today's environment really is playing towards our core philosophy, turning dislocation into opportunity. So we think dispersion and complexity can create a really attractive opportunity set for disciplined event-driven investors like us. Jocelyn Lewis [00:29:08]: Thank you for joining us for this episode of Private Markets 360. Where we had the pleasure of speaking with Melanie Levine, partner and global head of client partnerships and business development at Davidson Kempner. Melanie shared invaluable insights into Davidson Kempner's diversified asset management platform, which is focused on event-driven and opportunistic credit strategies, how the firm navigates market dislocations, and how allocator priorities are evolving across the alternatives landscape. We delved into the differentiators that set DK apart globally and the changing landscape of investor demands and the shifting expectations for returns across various strategies. Melanie also highlighted the growing interest in hedge funds and the promising opportunities in asset-based lending, opportunistic credit, real estate, and absolute return strategies. If you found this episode insightful, please subscribe to Private Markets 360 for more expert discussions on private investments. Thank you to Melanie for her contributions and to our listeners for tuning in. Until next time. ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/economic-research-economic-outlook-europe-q4-2026-resilient-demand-meets-persistent-pressure-s101706636</link><description>This report does not constitute a rating action. Resilient demand is lifting our 2026 growth expectations, but inflation pressure and higher rates persist. S&amp;amp;P Global Ratings expects the eurozone and U.K. economies to grow by 0.9% and 1.3%, respectively, in 2026, and by 1.1% in 2027. Compared with our previous forecast, we have revised growth higher for 2026, while the outlook for later years remains broadly unchanged. At the same time, we expect slightly lower inflation in 2026 and higher infla</description><title>Economic Research: Economic Outlook Europe Q4 2026: Resilient Demand Meets Persistent Pressure</title><pubDate>23 September 2026 08:17:57 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/blog/energy-transition/092326-et-highlights-data-centers-energy-transition-uk-hydrogen-pipeline-japan-airlines-co2-credit</link><description>Energy transition highlights: Our editors and analysts bring you the biggest stories from the industry this week, from renewables to storage to carbon prices.</description><title>ET Highlights: Data center impact on energy transition, progress in UK hydrogen pipeline project, Japan Airlinesâ&amp;#x80;&amp;#x99; CO2 removal purchase deal</title><pubDate>22 September 2026 20:05:00 GMT</pubDate><author><name>Staff </name></author><content><![CDATA[ Energy Transition, Renewables, Emissions, Carbon September 23, 2026 ET Highlights: Data center impact on energy transition, progress in UK hydrogen pipeline project, Japan Airlinesâ CO2 removal purchase deal Energy Transition Highlights: Our editors and analysts bring together the biggest stories in the industry this week, from renewables to storage to carbon prices. Top story Global AI data center, air conditioning power demand stalling energy transition: ETC Surging electricity demand from AI data centers and air conditioning is slowing progress on the global energy transition, even as clean-energy technologies are being deployed faster and more cheaply than expected, according to Adair Turner, chair of the Energy Transitions Commission. Much of the new demand continue to be met by coal- and gas-fired power generation, limiting emissions reductions. Turner said rapid growth in renewables is largely meeting previously unforeseen increases in demand rather than meaningfully displacing coal use. As a result, clean-energy expansion has not yet translated into the emissions declines needed to meet global climate goals. He noted that falling costs for solar photovoltaics, batteries and electric vehicles, together with strong deployment rates, provide reasons for optimism. Clean electricity supply grew at 2.3 times the rate of overall energy supply in 2025, underscoring the pace of technology adoption. Despite those gains, global emissions have only plateaued rather than fallen. Turner said the world is not making progress at anything close to the pace required to meet the Paris Agreement's goal of limiting warming to well below 2Â°C, let alone 1.5Â°C. The warning comes as the UN Environment Programme reported earlier this month that the world is on track to overshoot the 1.5Â°C warming threshold, highlighting the urgent need for stronger action to reduce emissions and accelerate decarbonization. Benchmark of the Week $39.99/allowance Platts-assessed Regional Greenhouse Gas Initiative (RGGI) current-month strip on Sept. 16. Explore Platts Energy Transition Price Assessments Editor's Picks: Free and premium content SPGlobal.com/energy Groups sue US EPA over repeal of power plant greenhouse gas standards Multiple health and climate organizations filed a petition for review of the US Environmental Protection Agency's finalized rule repealing carbon dioxide limits imposed on power plants. The Sept. 17 petition from the American Health Association, American Lung Association, Clean Air Council, Environmental Defense Fund, Natural Resources Defense Council and Clean Wisconsin asks the US Court of Appeals for the District of Columbia to determine whether the EPA's actions violate the Clean Air Act. National Gas advances UK hydrogen pipeline project with engineering design National Gas has moved into the advanced engineering design phase for a 350-mile hydrogen pipeline linking St Fergus in northeast Scotland to Teesside on England's east coast, the gas transmission system operator said. The pipeline is the second phase of Project Union, and National Gas plans to develop a 1,500-mile national hydrogen network connecting major industrial clusters and hydrogen production centers, it added. The engineering design will define technical requirements, estimate costs and assess risks before detailed construction work begins. - Hong Kong plan sets 1%-3% SAF target for departing flights by 2030 Hong Kong has set a target for 1%-3% of the jet fuel used on departing flights from Hong Kong International Airport to come from sustainable aviation fuel by 2030, as part of its 2026-30 development plan, which anchors a broader push to build a regionally competitive supply chain across the Guangdong-Hong Kong-Macao Greater Bay Area. The policy is gaining commercial weight as Hong Kong-based EcoCeres advances plans for a 450,000 metric ton/year production hub in Dongguan that could affect jet fuel trade flows across southern China. S&amp;P Global Energy Core Latest RGGI auction drives bearish pricing on secondary market The third-quarter 2026 Regional Greenhouse Gas Initiative auction cleared at a record high, RGGI data shows, with prices and volumes surging as Virginia resumed participation in the multi-state carbon trading program. Auction 73 cleared at $37.65 per emissions allowance, up 8% from Q2 2026 and up 21% from the previous record set in Q4 2025. Some market participants paid close attention to the results for signs indicating the supply-and-demand dynamic. All 28.5 million allowances offered were sold at the auction, including 5.74 million allowances from Virginia, marking a 56% increase in auction volumes quarter over quarter, and an expansion in the programâs size. Japan Airlines, Climeworks forge first CORSIA-eligible carbon removal deal Japan Airlines and Climeworks Solutions have signed what the companies describe as the world's first purchase agreement for carbon dioxide removal credits designed to meet the requirements of the Carbon Offsetting and Reduction Scheme for International Aviation, they said. This deal marks a potential turning point for the broader integration of carbon removal into compliance markets and comes as the aviation sector faces mounting pressure to find credible decarbonization pathways beyond sustainable aviation fuel, particularly for long-haul routes where abatement options remain limited. EU Council raises the bar on free carbon allowances for energy-intensive industries The EU Council has moved to substantially expand free carbon allowances for energy-intensive industries from 2026 to 2030, agreeing a more generous allocation package than the European Commission had proposed in July in a bid to protect sectors most exposed to carbon leakage. EU ambassadors agreed to release around 88 million additional allowances under the bloc's Emissions Trading System for sectors covered by heat and fuel benchmarks, equivalent to roughly â¬6 billion in cost savings according to European Commission estimates. ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/lng/091526-gastech-2026-indias-power-sector-likely-to-absorb-more-lng-as-prices-stabilize</link><description>India has no shortage of LNG demand, and the power sector offers significant potential to absorb additional volumes as prices stabilize and become more affordable, Petronet LNG Limited Managing Director and CEO Akshay Kumar Singh said Sept. 15 at an industry event. India uses about 28% of its natural gas in the fertilizer sector and about 24% in city gas distribution, including piped natural gas</description><title>GASTECH 2026: India&amp;apos;s power sector likely to absorb more LNG as prices stabilize</title><pubDate>15 September 2026 15:01:58 GMT</pubDate><author><name>Surabhi Sahu</name></author><content><![CDATA[ Natural Gas, LNG, Energy Transition, Coal, Renewables, Hydrogen September 15, 2026 GASTECH 2026: India's power sector likely to absorb more LNG as prices stabilize By Surabhi Sahu Editor: Meghan Gordon Getting your Trinity Audio player ready... HIGHLIGHTS Petronet CEO sees power sector demand rising India aims to raise gas share of energy mix to 15% Petronet expands Dahej terminal capacity to 22.5 million mt/y India has no shortage of LNG demand, and the power sector offers significant potential to absorb additional volumes as prices stabilize and become more affordable, Petronet LNG Limited Managing Director and CEO Akshay Kumar Singh said Sept. 15 at an industry event. India uses about 28% of its natural gas in the fertilizer sector and about 24% in city gas distribution, including piped natural gas and compressed natural gas, while the power sector accounts for only about 12%, Singh said at the Gastech 2026 conference in Bangkok. The country has around 25 GW of installed gas-based power capacity, but many plants are not operating because of high gas prices, Singh said. While some demand can be replaced by alternative fuel, some consumption stays "heavily dependent" on natural gas, according to Singh. "We are not expecting LNG to replace renewable fuels, hydrogen, or coal. But definitely, from India's perspective, we are looking at liquid fuels," Singh said. India remains heavily dependent on liquid fuel imports, with imports meeting almost 90% of demand. Replacing even a small share of liquid fuels with LNG would be beneficial from an environmental standpoint and could also be economical once global supply eases, Singh said. India accounts for only about 6% of global energy consumption despite having 18% of the world's population, while natural gas makes up just 6% of its primary energy mix, compared with a global average of 24%, Singh said. The government aims to raise gas's share to 15% over the next four to five years, a target that would require a three- to fourfold increase in gas consumption and sharply higher LNG imports, he said. Currently, about half of India's gas demand is met through imports, and the other half is met through LNG imports, Singh said. Achieving the 15% natural gas target could lift LNG imports to more than 100 million mt/year from about 25 million mt/year and raise LNG's share of the country's gas basket significantly, Singh said. Petronet LNG currently operates two LNG terminals â Dahej on the west coast and Kochi on the southern coast, according to the company's website. Petronet LNG has been expanding infrastructure to support this growth, including increasing the capacity of its Dahej LNG terminal to 22.5 million mt/year from 17.5 million mt/year earlier this year, Singh shared. The company is also developing a 5 million mt/year LNG terminal on India's east coast, with scope for future expansion as demand grows, he said. In August, Singh had shared that this land-based LNG terminal at Gopalpur was awaiting environmental clearance from the federal government. According to Singh, these infrastructure investments would allow India to ramp up LNG consumption quickly when a reasonably priced supply becomes available. Past trends have shown that consumption rises sharply amid stable prices, he continued. Meanwhile, Singh also turned attention to India's approximate $65 billion investment program across the natural value chain, which includes LNG terminal facilities, transmission pipelines, distribution networks, and fuel-conversion infrastructure, to support future demand once LNG becomes more affordable. The country currently has about 25,000 km of gas transmission pipelines, with another 10,000 km under development, and the expanded 35,000-km network is expected to improve grid connectivity across India and help serve its vast population, Singh noted. Platts, part of S&amp;P Global Energy, assessed the October JKM, the benchmark price for LNG cargoes delivered to Northeast Asia, at $28.945/MMBtu Sept. 15, down 2.66% from the previous close. It assessed the LNG West India Marker, or WIM, for October at $28.595/MMBtu on Sept. 15, at a discount of 35 cents/MMBtu to the October JKM assessment. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/091426-india-i-rec-market-expands-amid-record-issuances-eyes-price-stability-panel</link><description>India&amp;apos;s International Renewable Energy Certificate market is growing rapidly, with record issuances and some of Asia&amp;apos;s highest redemption rates, but lower prices and the need for more sophisticated procurement tools are emerging as key challenges, panelists said at I-TRACK Day India on Sept. 11. Issuances for 2025 vintage certificates reached a record 16.9 million on the Xpansiv Evident registry,</description><title>India I-REC market expands amid record issuances, eyes price stability: panel</title><pubDate>14 September 2026 07:38:57 GMT</pubDate><author><name>Ahmad afiq Muhammad zahir</name></author><content><![CDATA[ Electric Power, Energy Transition, Renewables September 14, 2026 India I-REC market expands amid record issuances, eyes price stability: panel By Ahmad afiq Muhammad zahir Editor: Ankit Ajmera Getting your Trinity Audio player ready... HIGHLIGHTS Prices slid despite growing redemption rate Hydro issuances effectively cease after 2024 halt vPPAs emerge as long-term stability tool India's International Renewable Energy Certificate market is growing rapidly, with record issuances and some of Asia's highest redemption rates, but lower prices and the need for more sophisticated procurement tools are emerging as key challenges, panelists said at I-TRACK Day India on Sept. 11. Issuances for 2025 vintage certificates reached a record 16.9 million on the Xpansiv Evident registry, while redemptions rose 26% year over year to 14.1 million, according to data presented by EKI Energy Services Chairman and Managing Director Manish Dabkara at the event in New Delhi. EKI Energy Services provides climate change and sustainability advisory services. "Yet prices have slid to 50-60 cents/megawatt-hour, well below regional peers with lower redemption rates," Dabkara said. Price lag Bangladesh commands prices above $2/MWh at a redemption rate of around 59%, while prices in Malaysia trade over $2/MWh at a redemption rate of about 82% and those in Sri Lanka are above $1/MWh at 70%, according to data presented by Dabkara. India, despite its 85%-86% redemption rate, trades below all three markets. "The demand growth is there, and supply is not very much oversupplied," Dabkara said. "Whatever loss is happening, it's a loss for the country and for the sellers." Platts, part of S&amp;P Global Energy, assessed India solar I-REC vintage 2026 at 47 cents/MWh on Sept. 11, unchanged week on week. Prices across Vietnam, Thailand and India have all declined from levels seen two years ago, according to panelists. India's I-REC market has followed a seasonal price cycle, with prices declining from March onward before recovering during the December-to-March peak demand window. Solar dominated India's technology mix, with certificates reaching 19.63 million through 2025 -- the highest ever for any single technology in the I-REC system, according to Bharti Ladiya, senior manager of strategy and business development at ICX, a local issuer of I-RECs in India. "Total active capacity registered with I-REC stood at about 22 gigawatts (through 2026), with hydro issuances having effectively ceased following a halt in 2024," Ladiya said. Next frontier Virtual power purchase agreements, or vPPAs, are emerging as a complementary instrument for corporate buyers seeking longer-term price certainty and stronger additionality claims beyond spot I-REC markets, said Eesha Peshawaria, who leads vPPA sales at renewable energy developer CleanMax. A vPPA is a bilateral financial agreement to supply energy attribute certificates from a new, dedicated renewable plant without physical power delivery, allowing buyers to support new renewable capacity while managing energy cost exposure, Peshawaria said. She said the Indian vPPA market was still nascent but evolving rapidly, driven by multinationals seeking to replicate procurement structures from their home markets in Europe and the US. India's installed renewable capacity accounts for nearly 50% of total capacity, but actual generation from renewables represents only about 20% of the mix -- a structural gap contributing to curtailment challenges and reinforcing the case for instruments such as vPPAs that support new capacity addition rather than recycling existing generation into certificates, according to panelists. The concentration of redemptions in the December-to-March window leaves prices under pressure for much of the year, panelists said, underscoring the need for more programmatic, year-round procurement to stabilize the market. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/092226-indonesia-maps-grid-strategy-for-hyperscale-data-center-boom</link><description>Indonesia is planning to rapidly build the power infrastructure needed to support expected growth in artificial intelligence and hyperscale data centers, with government officials and the state electricity company outlining coordinated strategies to nearly tenfold national data center capacity by 2029 while managing grid pressures from a sharp rise in connected power capacity by 2034. At the Enlit</description><title>Indonesia maps grid strategy for hyperscale data center boom</title><pubDate>22 September 2026 16:43:46 GMT</pubDate><author><name>Rachel Tan</name></author><content><![CDATA[ Energy Transition, Electric Power, Renewables September 22, 2026 Indonesia maps grid strategy for hyperscale data center boom By Rachel Tan Editor: Ankit Ajmera Getting your Trinity Audio player ready... HIGHLIGHTS Peak additions of 7,798 MW forecast for 2028 Grid readiness, not land, is Indonesia's key challenge Renewables lag risks coal, gas filling data center gap Indonesia is planning to rapidly build the power infrastructure needed to support expected growth in artificial intelligence and hyperscale data centers, with government officials and the state electricity company outlining coordinated strategies to nearly tenfold national data center capacity by 2029 while managing grid pressures from a sharp rise in connected power capacity by 2034. At the Enlit Asia 2026 conference in BSD City on Sept. 22, senior officials from Indonesia's Ministry of Communication and Digital Affairs and PT PLN (Persero) outlined the scale of the challenge and the policy and infrastructure responses under development, warning that power grid readiness could determine whether Indonesia captures the surge in hyperscale investment sweeping Southeast Asia. "The future of digital infrastructure depends not only on how fast we grow, but on how well we build resilience from the beginning," said Denny Setiawan, director of digital infrastructure strategy and policy at the Directorate General of Digital Infrastructure of the Ministry of Communication and Digital Affairs. Setiawan was speaking at a seminar titled "Powering Indonesia's AI and Hyperscale Data Center Ecosystem Sustainably." Nayusrizal, executive vice president for retail and commerce at PT PLN (Persero), said the scale of data center demand was fundamentally transforming the utility's role, describing a shift from "selling electricity" to enabling "digital infrastructure growth." Behind every AI model and every data workload, he said, there lies a power requirement that must be planned for from the outset. Grid and capacity The ambition is anchored in Indonesia's 2025-29 National Mid-Term Development Plan, or RPJMN, which targets national data center capacity at 6.87 watts/capita by 2029, up from a baseline of just 0.74 W/capita in 2024, an increase of more than 800%. The plan also calls for the fiber optic network reach to expand from 70.53% to 90% of sub-districts, and for mobile broadband population coverage to rise from 97.16% to 98%, forming what the ministry describes as the combined foundation for an AI-ready Indonesia. Indonesia's data center power capacity pipeline is projected to reach 25,297 MW by 2034, up from an existing connected capacity of 1,990.5 megavoltampere, requiring an unprecedented pace of grid investment, substation expansion and generation capacity additions concentrated within a narrow geographic corridor, according to Nayusrizal. The existing data center landscape is already heavily concentrated. The JAMALI system -- covering Java, Madura and Bali -- served 142 of Indonesia's 159 data center customers as of July 2026, accounting for 99% of the total connected capacity of 1,989.5 MVA, Nayusrizal's presentation showed. Greater Jakarta leads with 50 customers and 1,047 MVA of connected capacity, closely followed by West Java with 63 customers and 1,036.36 MVA, according to Nayusrizal's presentation. Outside Java, regions including North Sumatra, Riau, Kalimantan and Sulawesi collectively account for less than 1% of total connected capacity. The expansion pipeline deepens that concentration further. West Java dominates projected capacity additions, with the largest single-year increases forecast for 2027 at 6,884 MW and for 2028 at 7,798 MW, the peak year for additions, Nayusrizal's presentation showed. This compression of massive load growth into a two-year window within a single regional grid system represents one of the most acute infrastructure planning challenges Indonesia's power sector has faced, according to Nayusrizal. Setiawan said effective development requires coordination among the ministry, PLN, local governments and industrial estate managers for priority location mapping, capacity planning, load scheduling and permitting. "Hyperscale and large-scale colocation data centers typically require between tens and hundreds of megawatts of electricity on a sustained, long-term basis, with requirements for 24/7 operational reliability, high power quality, uninterrupted supply, dual feeds and backup systems," Setiawan said. Clean energy To manage the risk of grid misalignment, PLN has developed an early alignment strategy under which AI requirements, data center site selection, grid and substation readiness, generation supply and green energy solutions are coordinated from the earliest planning stage. Without such alignment, Nayusrizal said, operators risk selecting sites without adequate grid capacity, facing substation and transmission gaps with long lead times, failing to secure generation and green power in advance, and ultimately suffering delayed commercial operation dates and higher costs. "PLN proactively aligns AI requirements, data center site selection, grid and substation readiness, generation supply, and green energy solutions from the earliest planning stage, ensuring that time-to-power becomes a competitive advantage in accelerating data center development in Indonesia, rather than an investment bottleneck," Nayusrizal said. PLN outlined a four-pillar service framework for data center customers, encompassing clean and flexible generation, a strengthened grid with N-1 reliability, dedicated infrastructure with scalable capacity and reliable data center services with tailored service-level agreements. On clean energy, Nayusrizal said PLN is actively developing renewable energy sources and offering green tariffs and renewable energy certificates to meet the decarbonization requirements that hyperscale operators increasingly impose as conditions of investment. Platts, part of S&amp;P Global Energy, assessed vintage 2026 solar I-REC for Vietnam at 29 cents/MWh, Thailand at 57 cents/MWh, Malaysia at $3.35/MWh, India at 46 cents/MWh and Singapore at S$31.50/MWh ($24.665/MWh) on Sept. 22. Nayusrizal identified four core requirements that data center operators demand from utilities: large capacity and high power reliability; fast grid connection and dedicated infrastructure; access to renewable energy and green tariffs; and long-term commercial commitments with predictable costs. "PLN's evolving model is structured to address all four," Nayusrizal said, as the utility transforms from a traditional electricity supplier into what it describes as an integrated energy partner for Indonesia's digital economy. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/abs-frontiers-are-direct-lending-feeder-funds-clos-in-disguise-s101703325</link><description>This report does not constitute a rating action. RNFs are feeder funds that typically invest into a single limited partner (LP) interest in a master fund, creating tranched exposure to the LP interest through the issuance of one or more classes of debt and a residual equity component. By obtaining credit ratings on the debt instruments, certain institutional investors--such as insurance companies--may benefit from lower regulatory capital charges compared to direct equity investments in the unde</description><title>ABS Frontiers: Are Direct Lending Feeder Funds CLOs In Disguise?</title><pubDate>22 September 2026 15:11:19 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/special-reports/energy-transition/energy-scenarios-report-2026</link><description>Geopolitical disruption, rising import exposure, accelerating electricity demand and the intensifying impacts of climate change are reshaping the way policymakers and corporates think about energy and environmental security.</description><title>In Search of Resilience</title><pubDate>04 September 2026 19:31:00 GMT</pubDate><content><![CDATA[ S&amp;P Global Energy In Search of Resilience A scenario-based assessment of energy and environmental security Let's Talk Interested in our product? Contact us. Contact Us On this page Introduction Energy Scenarios Pathways to Resilience Resilience Outcomes Strategic Implications On this page Introduction Energy Scenarios Pathways to Resilience Resilience Outcomes Strategic Implications Key Takeaways Resilience now drives the global energy future: building systems, strategies and institutions that adapt to volatility. S&amp;P Globalâs 2026 Energy Scenarios outline four pathways to 2060, each requiring governments, corporations and consumers to manage trade-offs across growth, technology, energy security and governance. Decarbonization remains essential, but must be balanced with import exposure, reliability, supply chains, climate adaptation and affordability. Fossil fuels will remain significant for decades, but clean technology will shape future energy systems; in the Base Case, wind and solar supply over half of global power by 2060. S&amp;P Globalâs Energy Scenarios project by 2100 a warming ranging from 3.1 Â°C to 2.0 Â°C above pre-industrial levels, signaling rising climate risk despite emissions progress. Introduction Download report Geopolitical disruption, rising import exposure, accelerating electricity demand and the intensifying impacts of climate change are reshaping the way policymakers and corporates think about energy and environmental security. In this environment, resilience is no longer simply about withstanding shocks; it is about building systems, strategies and institutions capable of adapting to a more volatile world. S&amp;P Globalâs 2026 Energy Scenarios explore four distinct pathways through this uncertainty. Each offers a different route to resilience, and each demands compromise. Together, they show that the future of energy will be defined not by a single pathway, but by the ability of governments, energy companies and industrial consumers to manage trade-offs between security, affordability, competitiveness and climate risk. Building resilience In July 2025, we introduced three brand new Energy Scenarios (Adaptation, Fracture and Renaissance) alongside an updated and refreshed Base Case. Since then, the instability and uncertainty that has so far characterized the 2020s has only been amplified. The ongoing conflict in the Middle East between Iran, the United States and Israel is the latest and perhaps most consequential example of the upending of geopolitical norms that began in 2025. Whatever the outcome of the conflict, it is now clear that the post-WW2 period that previously defined the global geopolitical landscape has drawn to a close. What follows is unknown. But with future market, geopolitical and environmental shocks increasingly likely, resilience has become the new mantra for policymakers and corporate strategists alike. S&amp;P Globalâs Energy Scenarios, updated for 2026, explore this concept of resilience in different ways, each finding solutions to the twin challenges of energy and environmental security, but also sometimes demanding difficult compromise, depending on the pathway followed. To learn more or to request a demo, visit spglobal.com/energy-scenarios. The 2026 Energy Scenarios Download report The 2026 Energy Scenarios update the analysis we introduced in July 2025. The suite of outlooks comprises the Base Case as well as three alternative scenarios: Adaptation, Fracture and Renaissance. The S&amp;P Global Energy Base Case describes a world attempting to manage the instability and uncertainty of the early- to mid-2020s and facilitate an energy transition that conclusively pivots the global energy system away from fossil fuels, while still meeting the growing energy needs of developed and emerging economies alike. Base Case Pragmatic transition with gradual decarbonization Adaptation Economic resilience outweighs emissions reduction Fracture Rapid innovation amid weak governance Renaissance Accelerated clean energy in a multipolar world Base Case Pragmatic transition with gradual decarbonization Adaptation Economic resilience outweighs emissions reduction Fracture Rapid innovation amid weak governance Renaissance Accelerated clean energy in a multipolar world In this effort, the world is not entirely unsuccessful: the energy system of 2060 is far less reliant on fossil fuels than in 2026, and greenhouse gas emissions see decades of sustained decline, although the transition away from fossil fuels remains incomplete by the end of the outlook period. The Adaptation scenario balances fossil-fuel-powered economic growth against the risks of heightened global warming. Countries pivot toward strategies that emphasize adaptation to climate change via stronger, more resilient economies over emissions mitigation. This focus on economic growth underpins robust energy consumption and resilient demand for fossil fuels, especially oil and gas, over the long term. The Fracture scenario explores the possibility of accelerated technological progress in a weak policy and governance environment. Fracture sees rapid technological advancements, but also complex governance issues and significant shifts in global energy dynamics as some markets decarbonize very rapidly, while others lag. The combination of poor governance and accelerated technological progress has profound implications for geopolitics and economics, as well as environmental issues such as climate change, creating a complex and often difficult future for energy markets and society at large. In the Renaissance scenario, major shifts in the global balance of power result in a more multipolar geopolitical landscape. A faster-than-expected rise of key emerging markets and developing economies (EMDEs) play a significant role in driving strong global economic growth and a more accelerated pathway of clean energy technology (CET) uptake across the world. 2026 energy scenarios Source: S&amp;P Global Energy Adaptation 2026 Fracture Renaissance 2.4% 18% 53% -27% 2.6 Â°C 2.7% 34% 65% 5% 3.1 Â°C 1.9% 2% 55% -26% 2.6 Â°C 2.7% -3% 32% -68% 2.0 Â°C 2025 2025 2060 Base Case (CAGR 2000-25) (2000-25) (2000-25) (CAGR 2025-60) (2025-60) (2025-60) (est. change by 2100) 2.8% 57% 80% 44% (actual) of TPED in 2025 Fossil fuel % GHG emissions TPED Global GDP Fossil fuel % GHG emissions Global temp. TPED Global GDP of TPED in 2060 Pathways to resilience Download report All four 2026 scenarios build forward from the mid-2020s marked global increase in volatility and fragmentation of international relationships and trade. But the scenarios also take account of structural and long-term trends that have increasingly defined global energy markets in recent years, in particular the increased exposure of emerging economies to energy imports, and the growing role of electricity in meeting end-use demand. In addition, the scenarios are shaped by a world which is increasingly seeing the impacts of global climate change, driven by anthropogenic greenhouse gas (GHG) emissions. Over the last 30 years, the major global energy demand centers have typically increased their reliance on imported energy in order to meet demand. In 2025 Europe met over 45% of its energy demand with imports; India 36% and China 22% (although in volumetric terms China is by far the worldâs largest energy importer). In 2025 Europe met over 45% of its energy demand with imports; India 36% and China 22% With the Iran war representing the second major global energy crisis in only four years (after Russiaâs invasion of Ukraine in 2022), the import exposure of major global economic centers has become a strategic risk that can no longer be taken for granted. Of the worldâs major economies the US stands alone in not only having reduced its exposure to energy imports since 2005, but also having switched to a net energy exporter status, a result of radically increased production of oil and natural gas over the last 20 years. The second critical trend is the growth of electricity as the worldâs energy type of choice at the point of end use. Electricity is taking market share from other fuels in all sectors â from industry to transport, to residential and commercial. With the emergence of data center demand growth, electricity supply has become even more critical to the modern economy. Crucially, demand for electricity in emerging markets is now, on a per capita basis, significantly higher than it was in developed country peers at the same stage of economic development. In 2026, Europe endured numerous heatwaves, record-breaking temperatures and wildfires. In 2026, Europe endured numerous heatwaves, record-breaking temperatures and wildfires. In the Pacific Ocean, an El NiÃ±o is developing which could be the most intense ever recorded â and push 2027 global average temperatures to levels never before seen in human history. In this age of uncertainty, the challenge is to maximize energy security (particularly in those economies exposed to energy imports) and provide ever-increasing electricity supply at an affordable level, all while trying to minimize environmental impacts â especially those related to the global climate. Energy security In defining pathways to resilience, the two extremes for energy security solutions are illustrated by the Adaptation and Renaissance scenarios. In the former, energy security emerges from a "stronger for longer" use of fossil fuels. Countries that are able to exploit domestic fossil reserves do so, but demand is also supported by robust international energy trade. In the latter, energy security emerges via the accelerated deployment of clean energy technology, which by default brings more energy production back inside countriesâ borders. Energy security is achieved via a pragmatic balance between the deployment of clean energy technology and the continued use of fossil fuels. In the Base Case, energy security is achieved via a pragmatic balance between the deployment of clean energy technology and the continued use of fossil fuels. All countries demonstrate some level of energy transition, but this is fastest and deepest in select economies, principally China and Europe. In Fracture, energy security is sought but not always achieved. Energy trade is volatile and imports not always guaranteed, but the ubiquity and low cost of clean energy technology â especially solar and batteries â offers emerging economies in particular the opportunity to develop their energy systems even against the background of the poor governance and weak institutions that are a global theme in this scenario. Electricity demand and supply are the critical differentiators Across the scenarios, trends in electricity demand and supply underly the various pathways to energy security. All outlooks show the continuation of the trend since 1990 for electricity to take an ever-larger share of end-use (or final) energy demand. In the Base Case, power demand grows from 22% of final energy demand in 2025 to 36% by 2060. Meanwhile, the share of renewables in the power supply mix grows ever stronger; by 2060 wind and solar combined will supply more than half of global power demand. Adaptation In Adaptation, electricity increases its share of end-use energy demand over the decades, though not to quite the degree seen in the Base Case. Moreover, end-use demand for fossil fuels grows marginally in absolute terms. Top-line demand growth is strongest of all scenarios in Adaptation, and the role of EVs weakest: these two factors alone ensure a much longer future for oil demand in the transportation sector, which helps to underpin long-term end-use fossil fuel consumption. Meanwhile, the contribution of wind and solar (and other renewables) to power generation grows, but again not to the same degree as in the Base Case, leaving a much larger role in the power mix for coal, and especially gas, through the long term. Fracture The Fracture scenario shows complex regional, governance and technology dynamics which simultaneously result in an electricity end-use share of final energy demand which is second-highest in all the outlooks by 2060 (37%) even while delivered electricity is lowest in absolute terms. In Fracture, clean energy technology is available but not always deployed in the most effective or robust fashion, which prevents this scenario from achieving the accelerated energy transition seen in Renaissance (below). Nevertheless, end-use consumption of fossil fuels does fall in absolute terms in the Fracture scenario, and the role of renewables in the power sector does grow. By 2060, non-hydro renewables represent 65% of global power supply â with this total significantly higher in select countries, including China. Renaissance Renaissance is the scenario in which the twin trends of electrification of end-use energy demand and the decarbonization of power generation reach their apogee. A concerted and deliberate shift to "electrify everything" in almost all countries (or at least, electrify everything it is plausible to electrify) leads to power reaching almost 50% of end-use demand by 2060. Oil demand shrinks by about half and coal demand is almost totally eliminated from the last remaining industrial sectors where it is currently in use. On the power generation side, the same mantra to electrify everything is applied to renewable deployment, pushing this to the highest level of output in any of the scenarios. In Adaptation, electricity increases its share of end-use energy demand over the decades, though not to quite the degree seen in the Base Case. Moreover, end-use demand for fossil fuels grows marginally in absolute terms. Top-line demand growth is strongest of all scenarios in Adaptation, and the role of EVs weakest: these two factors alone ensure a much longer future for oil demand in the transportation sector, which helps to underpin long-term end-use fossil fuel consumption. Meanwhile, the contribution of wind and solar (and other renewables) to power generation grows, but again not to the same degree as in the Base Case, leaving a much larger role in the power mix for coal, and especially gas, through the long term. The Fracture scenario shows complex regional, governance and technology dynamics which simultaneously result in an electricity end-use share of final energy demand which is second-highest in all the outlooks by 2060 (37%) even while delivered electricity is lowest in absolute terms. In Fracture, clean energy technology is available but not always deployed in the most effective or robust fashion, which prevents this scenario from achieving the accelerated energy transition seen in Renaissance (below). Nevertheless, end-use consumption of fossil fuels does fall in absolute terms in the Fracture scenario, and the role of renewables in the power sector does grow. By 2060, non-hydro renewables represent 65% of global power supply â with this total significantly higher in select countries, including China. Renaissance is the scenario in which the twin trends of electrification of end-use energy demand and the decarbonization of power generation reach their apogee. A concerted and deliberate shift to "electrify everything" in almost all countries (or at least, electrify everything it is plausible to electrify) leads to power reaching almost 50% of end-use demand by 2060. Oil demand shrinks by about half and coal demand is almost totally eliminated from the last remaining industrial sectors where it is currently in use. On the power generation side, the same mantra to electrify everything is applied to renewable deployment, pushing this to the highest level of output in any of the scenarios. Resilience Outcomes Download report Evolution of global energy trade Electrification of energy demand and the decarbonization of power generation are the foundations of energy security, but energy security is ultimately defined by a country (or regionâs) dependence on imported energy. If energy imports represent a large share of energy demand, then secure and reliable trade is imperative. If trade is unreliable or volatile, minimizing import exposure and reshoring energy production is critical. For China, the strategic development of a clean energy technology industry has a marked impact on future energy import levels. In 2025, China is the worldâs largest energy importer, and imports are needed to meet almost 1/4th of total energy demand. By 2060, this picture has changed dramatically across all scenarios. In the Base Case, imports represent only 16% of energy demand, with this share falling to 7% in the rapid-decarbonization Renaissance scenario. In India, imported energy meets about 35% of demand in 2025. By 2060, the Base Case sees about the same share of energy met by imports, although in volume terms there has been material growth. The Adaptation scenario facilitates open international energy trade: here, in 2060 Indiaâs energy imports are about double the 2025 level in volume terms, and the share of demand has also risen slightly to 40%. Only in Renaissance is there a material decline in both energy imports in volume and demand share terms â a result of the very rapid electrification and decarbonization of the power sector in this scenario. In the wake of the Ukraine war and loss of gas supplies from Russia, EU policymakers leaned into accelerated decarbonization as a solution not just for emissions mitigation, but also for enhancing energy security. Despite the lack of a domestic cleantech industry akin to Chinaâs, the EU nevertheless sees declining imports of energy across all scenarios between 2025 and 2060, and a sharp reduction in the import share of energy demand. Only in the Adaptation scenario does the openness of global energy trade through the long-term mean EU energy imports stay above a 40% share of demand in 2060 â with few concerns arising around energy security issues. Greenhouse gas emissions Global GHG emission trends closely follow the energy supply and demand paths illustrated by each of the scenarios. Once again, Adaptation and Renaissance define the extremes. As a result of the "higher for longer" fossil fuel signature of Adaptation, global GHG emissions grow until 2040 and then only plateau: emissions are almost at parity (+5%) with 2025 levels by 2060. In Renaissance, the global drive to revive multilateral climate policy and invest heavily in clean energy technology means by 2060, global GHG emissions are 68% below 2025 levels â and some markets are approaching true net-zero status. In Renaissance, decarbonization is not just a power sector story â all sectors contribute to decarbonization. In the Base Case and Fracture, global GHG emission trends are almost identical at the total level. In both outlooks, global emissions by 2060 are approximately 25% lower than 2025 levels, though this similarity at the global level masks regional disparities between the two scenarios. In the Base Case, regional decarbonization trends are more balanced, while in Fracture some markets (China especially) reduce emissions more quickly, with this decline offset by a slower rate of decline in the fossil-heavy regions and markets of the world. All scenarios demand compromise All of the 2026 scenarios find resilience in different ways, but all pathways to resilience demand some compromise. For Renaissance, the lower-emissions future minimizes climate impacts (though, as a 2-degree pathway, does not eliminate them) while also maximizing domestic energy supply via an accelerated buildout of clean energy technology. But this buildout requires significant investment in infrastructure and pre-commercial energy technologies. It also requires a policy framework that is geared towards decarbonization globally, is stable, and is supported (even if it implies higher costs) by consumers, governments and corporates alike. The low cost and easy availability of clean energy technology do offer some optionality for countries looking to diversify energy supply or to build out power systems Adaptation also requires a return to good governance, though here most specifically in the arena of international energy trade. Adaptation posits that a solution to the Hormuz crisis is eventually found that decisively and permanently opens the Strait â while the reverberations of the energy crises of the 2020s create global agreement that the free flow of energy around the world is too important to fall victim to geopolitical schisms. Adaptation also demands compromise in the area of environmental security, with GHG emissions remaining stubbornly high for many decades hence. Adaptation is thus the warmest of all the scenarios, and implicit within that is an elevated risk of climate-related financial, ecosystem and infrastructure damage throughout the remainder of this century. In Fracture, a difficult geopolitical framework means guaranteed energy security via the free flow of coal, oil and gas across borders is impossible. The low cost and easy availability of clean energy technology do offer some optionality for countries looking to diversify energy supply or to build out power systems, but with the poor governance background of Fracture, effective implementation is always a challenge. The accelerated energy transition described by the Renaissance scenario remains out of reach, and while GHG emissions do decline significantly to 2060, and 2.6 degree warming pathway does imply an elevated (vs. to today) risk of climate damage. In the slower economic growth outlook of Fracture, this means economies â many of them in the emerging world â are more poorly placed to adapt to the changing climate. The Base Case is a story of pragmatism, where resilience and compromise are balanced in almost equal measure. Global energy trade is more reliable than in Fracture, although a return to the pre-Hormuz crisis, pre-Ukraine invasion status quo is never achieved. Cleantech is deployed globally, but a focus on cost effectiveness and practicality over emissions mitigation mean that the ambitious decarbonization policies of the post-Paris Agreement are not met. A pathway to warming of 2.6 degrees above pre-industrial levels by 2100 does mean increased climate impacts, but unlike Fracture, a larger and more dynamic global economy is better positioned to withstand these challenges. A pathway to warmingâ¨of 2.6 degrees aboveâ¨pre-industrial levels by 2100 does mean increased climate impact Strategic implications Download report Resilience is becoming the organizing principle for energy policy, industrial strategy and corporate capital allocation. The 2026 scenarios do not describe a single linear transition from fossil fuels to clean energy, but instead a world in which energy security, environmental security, affordability, industrial competitiveness and geopolitical positioning interact in increasingly complex ways. For policymakers and corporates alike, the task is not to predict which future will arrive, but to build strategies that remain robust across several plausible futures. For policymakers, this points to a necessary broadening of energy strategy. Decarbonization remains essential, but it is no longer sufficient as a standalone framework. Governments must also contend with energy import exposure, electricity system reliability, clean technology supply chains, climate adaptation and consumer affordability. The Base Case suggests that policy succeeds where it is pragmatic, durable and focused on system-wide outcomes. Renaissance shows the upside of coordinated policy, accelerated infrastructure build-out and sustained public support for clean energy deployment. Adaptation and Fracture, meanwhile, expose the costs of either prioritizing economic resilience over environmental mitigation, or allowing technology progress to outrun governance capacity. Decarbonization remains essential, but it is no longer sufficient as a standalone framework. Managing energy system resilience means accelerating investment in grids, storage, firm low-carbon power, permitting reform and demand-side flexibility, while maintaining credible plans for oil, gas and critical minerals security. It also means treating climate adaptation spending as a core part of economic resilience. A warmer world is now embedded in all plausible outlooks; the difference between scenarios lies in the scale of future damages and the capacity of economies to absorb them. From policy ambition to execution For energy companies, the scenarios argue against binary positioning. Fossil fuels remain material in every outlook, but their strategic role changes by scenario, region and sector. In Adaptation, long-duration demand for oil and gas supports upstream investment, LNG infrastructure and conventional energy supply chains, provided trade remains open and geopolitical risks are managed. In Renaissance, value migrates more rapidly toward power, networks, flexibility, low-carbon fuels, critical minerals and carbon management. Fracture creates a more volatile operating environment: technology costs fall, but policy coherence and trade reliability weaken. The Base Case points to a middle path in which disciplined investment in hydrocarbons coexists with an expanding set of low-carbon growth options. Fossil fuels remain material in every outlook, but their strategic role changes by scenario, region and sector. For energy corporates, portfolio resilience matters more than simple portfolio greenness. Companies will need to stress-test assets against divergent demand, price, policy and climate outcomes; preserve optionality across molecules and electrons; and avoid over-committing to strategies that depend on a single political or technology pathway. The winners are likely to be those that can combine reliability in conventional supply with credible participation in the build-out of future energy systems. For industrials, electricity becomes the critical input to competitiveness, not just a utility cost. Across all scenarios, power demand rises in importance; in the more accelerated pathways, access to abundant, reliable and low-carbon electricity becomes a decisive determinant of industrial location, supply-chain configuration and operating margin. Resilience is not the alternative to transition. It is the condition under which any transition must now be judged. Across the scenarios, three strategic tests stand out. The first is exposure: how vulnerable is a country, company or asset to imported energy, volatile trade, carbon costs, physical climate risk or constrained power supply? The second is flexibility: how quickly can policy frameworks, capital plans, supply chains and operating models adapt as technology and geopolitics evolve? The third is credibility: can governments and corporates sustain the investment, public support and execution discipline required for their chosen pathway? Resilience will be built through diversification, not retreat. Energy security does not mean autarky; environmental security does not mean emissions mitigation alone; industrial strategy does not mean protectionism without competitiveness. The most resilient actors will be those that manage interdependence intelligently: diversifying supply, investing in domestic capability where strategically necessary, maintaining access to global markets where advantageous, and preparing for a future in which shocks are more frequent and trade-offs more explicit. Resilience is not the alternative to transition. It is the condition under which any transition, or any enduring energy system, must now be judged. Go beyond this report Published on: September 04, 2026 Author: Paul McConnell, Head of Scenarios Editor: Beth Foote, Associate Director Design: Energy Content Design ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/blog/crude-oil/092226-ctracker-asia-crude-indonesia-ethanol-lme-copper-european-carbon-brazil-power-prices</link><description>The Asian oil industry is facing high prices and supply disruptions, while Indonesia is aiming at ethanol 20% gasoline plan. European carbon prices and Brazilian power prices are in focus this week. </description><title>COMMODITY TRACKER: 5 charts to watch this week</title><pubDate>22 September 2026 10:58:02 GMT</pubDate><author><name>Staff </name></author><content><![CDATA[ Agriculture, Crude Oil, Refined Products, Metals &amp; Mining, Energy Transition, Natural Gas, Electric Power, Sugar, Biofuels, Gasoline, Non-Ferrous, Carbon September 22, 2026 COMMODITY TRACKER: 5 charts to watch this week By Staff Editor: Shikha Singh Getting your Trinity Audio player ready... The Asian oil industry is facing high prices and supply disruptions, while Indonesia is aiming at ethanol 20% gasoline plan. European carbon prices and Brazilian power prices are in focus this week. 1. High crude prices tighten Asian supply, demand What's happening? Crude oil prices above $100/b are creating a dual challenge for Asia as supply constraints and elevated prices threaten both energy security and demand growth, industry sources and analysts said Sept. 14. The impact of high crude oil prices has extended far beyond direct fuel consumption and is impacting freight, manufacturing and household expenses, according to analysts, economists and industry sources. About 75% of Asia's crude imports from the Middle East transited the Strait of Hormuz in 2025, but by Q3 2026, that share had fallen to between 10% and 20%, according to S&amp;P Global Commodities at Sea. What's next? Analysts said early signs of demand curtailment were already visible and could intensify unless conflicts in the Middle East and Ukraine subside and prices decrease. This could hinder Asian countries' efforts to secure additional cargoes and build energy-security buffers. Global oil demand is expected to decline by about 2.4 million barrels/day in 2026 from 2025 levels, with Asia accounting for about 1.5 million b/d of the contraction, according to S&amp;P Global Energy CERA. 2. Indonesia targets sugarcane for E20 ethanol blend What's happening? Indonesian President Prabowo Subianto has ordered ministries to deliver a 20% ethanol gasoline blend within two years, sharply accelerating an April decree, which required only 5% blending through 2027 and 10% between 2028 and 2030. The supply gap is the binding constraint. Indonesian ethanol output was 160,946 kiloliters in 2024, according to industry body Apsendo, while E10 alone would require 1.4 million kl/year, nearly nine times current production, with E20 demanding substantially more. Platts, part of S&amp;P Global Energy, assessed the Asian fuel ethanol marker at $675/cubic meter CIF Philippines on Sept. 18, up $28.33/cubic meter month over month. What's next? The country has identified sugarcane as the primary feedstock for its E20 ethanol fuel blend program. The E20 volumes would be sourced entirely from domestic production, Coordinating Minister for Food Affairs Zulkifli Hasan said after a Sept. 17 cabinet meeting at Merdeka Palace. "We will gradually move toward E50, as we did toward B50 (blending mandate of 50%)," Hasan said. Jakarta has signaled the ambition runs further still. 3. LME copper tops $14,400/mt as inventories rise What's happening? London Metal Exchange copper cash settled at $14,400.50/mt Sept. 17, up $10.50 week over week. Inventories climbed 21,150 mt week over week. The three-month contract was at an $8.50/mt premium to cash, indicating contango. Platts assessed clean copper concentrate CIF China at $4,124/mt Sept. 21, up $22/mt day over day, but below the all-time high price of $4,133/mt reached on Sept. 10. Platts assessed Chinese import premiums at $105/mt Sept. 21, down $5/mt day over day. US tariff uncertainty, regional inventory dislocation and persistent concentrate constraints have supported copper prices, even as metal flows into the US tighten availability elsewhere, CERA analysts said. What's next? CERA analysts expect prices to remain elevated near term as rising liquidity softens the US dollar. Falling inventories could ease tightness, though continued copper flows into the US could trigger another squeeze. CERA analysts forecast a global refined copper surplus at 288,000 mt, while the midterm outlook forecasts a copper concentrate deficit of about 530,000 mt in 2026. Related content: METALS MONITOR: EU flags ferronickel supply risks in MMG-Anglo deal; Indian, US steel markets buoy refractories 4. European carbon prices rise on strong gas prices What's happening? EU carbon prices rose over the week of Sept. 18 amid bullish gas support. The market remains apprehensive amid ongoing debate among lawmakers and member states over the future shape of the EU Emissions Trading System. Prices hit a more than seven-month high earlier in the week before participants took profit. Platts last assessed EU Allowances at â¬85.87/metric tons of CO2 equivalent Sept. 17, while the benchmark natural gas front-month Dutch TTF was assessed at â¬76.795/MWh, down from a more than three-year high of â¬83.525/MWh on Sept. 14. What's next? Analysts at CERA expect prices to average around â¬86/mtCO2e in the fourth quarter of 2026. Meanwhile, market participants have expressed concern about potential policy interventions that could depress the price of EUA and further deter financial players from taking positions. A Europe-based carbon trader expects limited upside after the Sept. 30 compliance deadline, noting no major fundamental catalyst beyond potential headlines this winter. 5. Brazilian power prices fall on unexpected rainfall What's happening? Brazil's power prices have fallen following unexpected rainfall, which has affected the outlook for hydroelectric availability in the country. Annually, over half of Brazil's electricity generation comes from hydropower plants, according to the Ministry of Mines and Energy. The change in weather, combined with new rain forecasts, has caused a sharp decline in forward power prices. Platts assessment of conventional power in Brazil's southeast-central region for the October forward price was at 143 reais/MWh ($28/MWh) on Sept. 18. The assessment for March 2027 dropped to 280 reais/MWh ($54/MWh), down from 319 reais/MWh on Sept. 1. What's next? "In the next six to eight weeks, our models are signaling that intense rain will continue," said Alexandre Nascimento, meteorologist and partner of the SÃ£o Paulo-based Nottus consultancy firm. "Cold fronts are coming with strength and not remaining restricted to the south but reaching southeastern and central states as well", he said. Reporting and analysis by Sambit Mohanty, Samyak Pandey, Shivam Prakash, Irina Breilean and Felipe Peroni. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/natural-gas/090926-infographic-regulatory-fragmentation-throws-wrench-into-europes-biomethane-market-growth</link><description>As governments race to scale renewable gases, biomethane markets are being shaped by a patchwork of rules that often differ across countries. Counterparties need to navigate shifting requirements for sustainability, certification, grid access, subsidies and emissions accounting in a rapidly evolving market, with prices varying across a range of specifications.</description><title>INFOGRAPHIC: Regulatory fragmentation throws wrench into Europe&amp;apos;s biomethane market growth</title><pubDate>09 September 2026 14:36:01 GMT</pubDate><author><name>Irina Breilean</name></author><content><![CDATA[ Natural Gas, Energy Transition, Renewables September 09, 2026 INFOGRAPHIC: Regulatory fragmentation throws wrench into Europeâs biomethane market growth By Irina Breilean Editor: James Leech Getting your Trinity Audio player ready... HIGHLIGHTS Patchwork rules complicate biomethane trading Certification standards vary by nation Prices fluctuate across specifications As governments race to scale renewable gases, biomethane markets are being shaped by a patchwork of rules that often differ across countries. Counterparties need to navigate shifting requirements for sustainability, certification, grid access, subsidies and emissions accounting in a rapidly evolving market, with prices varying across a range of specifications. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/creditweek-will-affordability-challenges-translate-into-significant-credit-impacts-in-the-us-s101706960</link><description>Beneath the U.S.â&amp;#x80;&amp;#x99;s current macroeconomic resilience and steady GDP growth, affordability pressures are building for many Americans, with potential credit implications for sectors including consumer products and retail, utilities, and U.S. public finance. Room for discretionary spending is shrinking for many amid decelerating real wage growth and rising costs for essential expenses. We view the potential for higher prices to curb consumer and business demand as a key credit risk for North Ameri</description><title>CreditWeek: Will Affordability Challenges Translate Into Significant Credit Impacts In The U.S.?</title><pubDate>17 September 2026 16:40:28 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/092126-ai-energy-surge-risks-eroding-record-renewables-gains-un-warns</link><description>Artificial intelligence&amp;apos;s surging energy demands are undermining global climate efforts and driving up fossil fuel consumption, UN Climate Change Executive Secretary Simon Stiell warned Sept. 21, calling on tech industry leaders to align with climate goals or risk losing their social license to operate. Speaking at an event during Climate Week in New York, Stiell delivered some of his sharpest</description><title>AI energy surge risks eroding record renewables gains, UN warns</title><pubDate>21 September 2026 13:01:27 GMT</pubDate><author><name>Eklavya Gupte</name></author><content><![CDATA[ Natural Gas, Electric Power, Coal, Energy Transition, Renewables, Emissions September 21, 2026 AI energy surge risks eroding record renewables gains, UN warns By Eklavya Gupte Editor: Alisdair Bowles Getting your Trinity Audio player ready... HIGHLIGHTS Stiell warns tech giants to go green or lose public trust Energy guzzling AI undermining climate progress COP31 targets electricity at 35% of global energy use by 2035 Artificial intelligence's surging energy demands are undermining global climate efforts and driving up fossil fuel consumption, UN Climate Change Executive Secretary Simon Stiell warned Sept. 21, calling on tech industry leaders to align with climate goals or risk losing their social license to operate. Speaking at an event during Climate Week in New York, Stiell delivered some of his sharpest remarks yet on the energy footprint of the AI sector, warning that data center expansion was already straining power grids and pushing up household and business energy costs worldwide. "Energy guzzling Artificial Intelligence is driving up planet-heating pollution from coal, oil and gas, while ratcheting up energy costs for households and businesses," Stiell said. "AI leaders are now on thin ice when it comes to license to operate, and sinking deep underwater when it comes to public support." The remarks carry significant implications for energy markets. Data center electricity demand, driven overwhelmingly by AI workloads, has become one of the fastest-growing sources of power consumption globally, intensifying pressure on grids and, in many markets, extending the operational life of coal- and gas-fired generation. Renewables surge Against that backdrop, Stiell pointed to new data from the International Renewable Energy Agency showing global renewable capacity additions reached a record 693 gigawatts in 2024 â equivalent to more than half the entire installed power capacity of the US. Renewables overtook coal as the world's largest source of electricity generation last year, with clean energy investment exceeding $2 trillion, Stiell said. "The shift to clean energy is now irreversible," he said. But he warned the AI industry risks eroding those gains unless technology companies set credible climate targets, invest in energy efficiency, disclose their energy and water consumption, and commit to powering data centers exclusively with renewable energy. He noted that data center projects were already being put on hold across the US, from New York to Texas, as well as in other parts of the world, signaling growing regulatory and public resistance to unchecked AI energy consumption. Stiell also acknowledged AI's potential to support climate solutions â including improving early warning systems for climate disasters and accelerating grid efficiency â but stressed these benefits needed to be accessible to developing countries rather than concentrated in wealthier nations. "We need every country to benefit from AI today, not vague promises of future solutions," he said. COP31 targets Looking ahead to the UN Climate Change Conference in November, Stiell outlined the energy-focused Action Agenda targets set by the Turkish COP31 presidency in close coordination with Australia. Australia is the President of Negotiations for COP31, which means it is leading the official negotiations. Chief among them is a goal for electricity to reach 35% of global energy use by 2035, a target which will impact power market investment, grid infrastructure and fossil fuel demand across both developed and emerging economies. Stiell urged governments, business leaders and investors to arrive at COP31 with concrete solutions to accelerate implementation, particularly in developing countries where the energy transition remains uneven. He also pointed to the UN carbon market, formally known as the Paris Agreement Crediting Mechanism under Article 6.4, as a potential new channel for investment in clean energy projects in emerging markets. On carbon dioxide removal, Stiell said the world could no longer afford to ignore the technology as a complement to fossil fuel phase-out, though he was explicit that CDR could never serve as a substitute for cutting emissions. "Transitioning away from fossil fuels can never be circumvented," he said. Stiell also warned that fossil fuel dependence was already inflicting measurable economic damage, estimating that the ongoing Middle East conflict had added more than $100 billion in extra costs to US consumers alone through higher gasoline and diesel prices since it began. US-Israeli Conflict with Iran Essential Energy Intelligence for today's uncertainty. See What Matters > ]]></content></item></channel></rss>