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<channel><item><link>https://www.spglobal.com/ratings/en/regulatory/article/sustainability-insights-chinas-energy-transition-cracking-the-profit-puzzle-of-power-storage-s101681063</link><description>This report does not constitute a rating action. China&amp;apos;s power storage sector is the missing piece to many energy puzzles. It will support the integration of wind and solar, reduce curtailment, and enhance system reliability. It will also contribute to the country&amp;apos;s decarbonization targets. More storage should also help rated renewable power firms transition to market-based pricing. Grid firms&amp;apos; pumped-hydro projects have dominated energy storage. Now, battery energy storage systems (BESS) will e</description><title>Sustainability Insights: China&amp;apos;s Energy Transition: Cracking The Profit Puzzle Of Power Storage</title><pubDate>10 June 2026 03:28:04 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/refined-products/060926-technip-energies-airbus-safran-form-esaf-venture-at-dunkirk</link><description>A consortium of industrial leaders has formed a joint venture to develop one of Europe&amp;apos;s largest alcohol-to-jet facilities, aiming to help meet rapidly rising EU mandates and contribute to energy security. Technip Energies, Airbus, Safran and agricultural cooperative Tereos will establish Rebound to build a plant at the Port of Dunkirk, France, capable of producing 160,000 mt/year of synthetic</description><title>Technip Energies, Airbus, Safran form eSAF venture at Dunkirk</title><pubDate>09 June 2026 12:53:06 GMT</pubDate><author><name>Thomas Washington</name></author><content><![CDATA[ Agriculture, Energy Transition, Refined Products, Biofuels, Renewables, Jet Fuel June 09, 2026 Technip Energies, Airbus, Safran form eSAF venture at Dunkirk By Thomas Washington Editor: Anoop Menon Getting your Trinity Audio player ready... HIGHLIGHTS Joint venture to produce alcohol-to-jet from agricultural residues Plant to help meet EU's 6% blending mandate by 2030 Project strengthens European energy supply security outlook A consortium of industrial leaders has formed a joint venture to develop one of Europe's largest alcohol-to-jet facilities, aiming to help meet rapidly rising EU mandates and contribute to energy security. Technip Energies, Airbus, Safran and agricultural cooperative Tereos will establish Rebound to build a plant at the Port of Dunkirk, France, capable of producing 160,000 mt/year of synthetic sustainable aviation fuel, or eSAF, using the alcohol-to-jet pathway, they said in a statement June 9. The facility will convert advanced ethanol derived from agricultural and forestry residues into drop-in aviation fuel that can be blended with conventional jet fuel. "Among the available production pathways, Alcohol-to-Jet is emerging as a scalable and cost-competitive option which converts advanced ethanol, produced from agricultural and forestry residues into drop-in aviation fuel that can be blended with conventional jet fuel and used in existing engines and aircraft," the statement said. The project aims to help address surging European demand for alternative aviation fuel driven by the EU's Refuel EU Aviation regulation, which requires airlines to blend 6% SAF with conventional jet fuel by 2030, rising to 70% by 2050. Alongside this, eSAF must account for 1.2% of aviation fuel supplied by 2030 and 35% by 2050. That regulatory framework is expected to drive an eightfold increase in SAF demand between 2030 and 2050, the statement said. Additionally, it aims to strengthen Europe's energy supply security, the statement said. Roadblocks Scaling alcohol-to-jet fuel technology at commercial levels will be critical to meeting near-term sustainable aviation fuel supply targets, with ethanol feedstock availability expected to increase substantially by the end of the decade, an official at the International Air Transport Association said June 3. There are 64 announced large-scale projects worldwide, with 26 due to be operational by 2030, driven by ReFuelEU and the UK SAF mandates, according to lobby group Transport &amp; Environment. If all the announced large-scale projects become operational, global production capacity could reach 2.1 million mt by 2030, and 5 million mt in total, accounting for roughly 10% of EU jet fuel demand, T&amp;E said. However, to T&amp;E's knowledge, except for Infinium's Project Roadrunner in the US, none of these projects have reached FID, and timelines remain uncertain, T&amp;E said on its website June 9. Analysts at S&amp;P Global Horizons forecast a global alcohol-to-jet supply of 46,692 mt in 2026, rising to 1.270 million in 2030, of which Europe will account for none. Horizons projects European alcohol-to-jet production will start in 2031 at 22,653 mt/year and rise from there, they said in a May 2026 long-term outlook. Levelized costs of production for eSAF will be $7,471/mt in 2026 and $6,213/mt in 2030, compared to $588/mt and $624/mt for jet fuel on a CIF basis in Northwest Europe, Horizons analysts said in a March 2026 forecast. Strategic positioning Steps ahead for the Rebound project include the selection of the technology licensor, permitting activities, launch of pre-FEED (Front-End Engineering Design) and FEED activities, finalization of feedstock supply and offtake agreements, and securing the financing for the construction of the asset, the companies said. "The creation of the joint venture is subject to customary closing conditions and approvals and is expected to be finalised in the second half of this year," they said. Tereos will supply the advanced ethanol feedstock, creating an integrated value chain from agricultural production to aviation end-use. The Port of Dunkirk has awarded Technip Energies an industrial site in northern France, offering logistical advantages for feedstock delivery and product distribution. The location provides streamlined permitting and access to existing port infrastructure for both imports and exports. The alcohol-to-jet pathway is an alternative production route to the established hydroprocessed esters and fatty acids route and Fischer-Tropsch synthesis. The technology converts ethanol into jet fuel through dehydration, oligomerization and hydrogenation processes. 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/060826-interview-xcel-energys-renewables-rich-footprint-is-primed-for-hyperscalers-ceo-says</link><description>Xcel Energy Inc. sees itself as uniquely positioned to continue leading on US power-sector emission reductions while accommodating a surge in demand from large-load customers such as data centers, Bob Frenzel, the company&amp;apos;s chairman, president and CEO, told Platts. &amp;quot;We think we can do that because we have a strategic geographic advantage,&amp;quot; Frenzel said in an interview with Platts, part of S&amp;amp;P</description><title>INTERVIEW: Xcel Energy&amp;apos;s renewables-rich footprint is primed for hyperscalers, CEO says</title><pubDate>08 June 2026 15:29:55 GMT</pubDate><author><name>Zack Hale</name></author><content><![CDATA[ Energy Transition, Electric Power, Renewables June 08, 2026 INTERVIEW: Xcel Energy's renewables-rich footprint is primed for hyperscalers, CEO says By Zack Hale Editor: Ronnie Turner Getting your Trinity Audio player ready... HIGHLIGHTS Google deal saves customers $1.5 billion over 15 years Company eyes 20 GW data center demand pipeline Xcel Energy Inc. sees itself as uniquely positioned to continue leading on US power-sector emission reductions while accommodating a surge in demand from large-load customers such as data centers, Bob Frenzel, the company's chairman, president and CEO, told Platts. "We think we can do that because we have a strategic geographic advantage," Frenzel said in an interview with Platts, part of S&amp;P Global Energy, on the sidelines of the Edison Electric Institute's annual investor-owned utility conference in Las Vegas on June 3. Maintaining customer affordability amid an estimated $1.4 trillion wave of planned US utility capital expenditures through 2030, driven in part by explosive growth in data center demand, was the overarching theme of the 2026 conference. Just a few years ago, US electric utility gatherings were broadly centered on climate targets and net-zero goals. Frenzel noted Xcel Energy's most recent sustainability report, released June 2, which shows that the company's four operating utility subsidiaries across eight states reduced their collective carbon emissions by 58% through 2025 compared to 2005 levels. Xcel Energy's residential electricity and natural gas rates were also 29% and 11% below the national average, respectively, over the last five years, according to the report. Minneapolis-headquartered Xcel Energy serves 3.9 million customers across the Great Plains region, including parts of North Dakota, South Dakota, Michigan, Minnesota and Wisconsin, as well as Colorado, eastern New Mexico and the Texas Panhandle. Frenzel said the company's aggressive investments in new wind and solar generation over the last 15 years, along with new transmission lines, have helped keep rates low even as the nominal US average retail price of electricity increased by 23% from 2019 to 2024. "We've been the leading provider of wind; we're a leading builder of transmission line miles in the US for the past 15 years," Frenzel said. "When you build infrastructure where it makes economic and reliability sense for your customers, you keep costs low and sustainable." Data center pipeline With consumer concerns mounting over the cost impacts of new data center development, Frenzel highlighted a deal Xcel announced in February with Google LLC to support a new 750-megawatt data center in Minnesota as a replicable model for protecting ratepayers. As part of the agreement, Google committed to procuring 1,900 MW of incremental new wind, solar and energy storage capacity, including 300 MW from a Form Energy Inc. iron-air battery, the world's largest long-duration energy storage resource announced to date. The deal, underpinned by a Clean Energy Accelerator Charge, requires Google to cover the cost of related grid upgrades. Frenzel said the agreement is expected to save regular Minnesota customers approximately $1.5 billion over a 15-year period, amounting to roughly 2% in annual savings on residential bills. "We're commercializing innovation with our technology customers, we're building a more resilient grid for our new customers, we're continuing to deploy clean energy, all while protecting our existing customers," Frenzel said. Xcel Energy, in its first-quarter 2026 earnings presentation, reported a 20-gigawatt pipeline of potential demand from hyperscalers and other large data center developers, with individual project capacity ranging from 200 MW to more than 1 GW. To help meet that demand, Xcel Energy earlier this year entered into strategic partnerships with GE Vernova Inc. and NextEra Energy Inc. The strategic alliance framework with GE Vernova will support Xcel Energy's long-term capex plan, calling for 12 GW of new wind, solar, storage and natural gas generation from 2026 to 2030. "Structuring an enterprise-wide agreement on our side and their side allows us certainty, price flexibility, and access to their engineering talent and pipelines of tech development," Frenzel said. "It allows us to move with speed and scale." Meanwhile, a joint development agreement with NextEra Energy will see the two companies codevelop generation solutions for 2 GW of new data center capacity, with potential to expand beyond that. "We're great owners and operators of infrastructure, and they're great developers, and that partnership allows us to move faster to meet the needs of our data center customers," Frenzel said. Large-load tariff preference As utilities seek to shield ratepayers through new contract and business model arrangements for data center customers, Frenzel expressed a preference for large-load tariffs with minimum demand charges, long-term power purchase agreements and exit fees. "A large-load tariff is a simplified framework that allows you to move through the regulatory process quite quickly," Frenzel said. Xcel Energy has two proposed large-load tariffs pending with Minnesota and Colorado utility regulators, with decisions expected in the second quarter of 2026 and early 2027. Frenzel added that Xcel Energy can also "pivot" if a state has a different need. "We can be flexible, and we can be agile," he said. Even as utilities prepare for a historic level of infrastructure spending, questions remain about how much new data center demand will actually materialize. A recent JPMorgan analysis based on satellite imagery found that construction has yet to begin on roughly 60% of data center capacity planned for completion in 2027, with another 7% delayed. Frenzel cautioned against reading too much into reports of data center delays, while adding that he would not pretend "to have perfect insight into the compute needs of the hyperscalers." "The contracts that most people have with data centers, from the electric side, have minimum takes and values," he said. "So, to the extent we're building infrastructure on behalf of these large customers, we're largely protected from the cost side of this." "My job is to make sure the infrastructure is ready when they're ready and that I protect our existing customers from any shortfalls in the timing of their projects," Frenzel said. 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/2026/04/oil-supply-worries-economic-uncertainty-cloud-outlook-for-breakbulk-sector</link><description>Project cargo and breakbulk demand may shift toward electrification and renewables, but oil and gas still dominate despite Middle East war headwinds.</description><title>Oil supply worries, economic uncertainty cloud outlook for breakbulk sector</title><pubDate>01 May 2026 12:00:00 GMT</pubDate><author><name>Eric Johnson</name></author><content><![CDATA[ BLOG â May 1, 2026 Oil supply worries, economic uncertainty cloud outlook for breakbulk sector By Eric Johnson The mix of industrial sectors that drive project cargo and breakbulk demand could well shift toward electrification and renewable energy in the coming years, but the industry is still driven by the oil and gas sectors despite fresh headwinds caused by the war in the Middle East. That sentiment, laid out in detail at the Journal of Commerceâs Breakbulk and Project Cargo Conference 2026 in New Orleans last week, cuts against the notion that service providers are totally consumed with data center construction. Tim Killen, head of growth at forwarder Fracht, said oil and gas still represents 25% of the planned capital expenditure investment for new projects globally over the next decade, compared to 8% to 10% for data centers, the sixth-highest project category. âWe've had a lot of conversations over the last two days in terms of power generation and data centers,â Killen said at the conference. âBut let's recognize that both for North America and globally, oil and gas is critical. So we're still focusing on that.â Among the sectors sandwiched between oil and gas and data centers that are driving new project capex are transformers, which Killen said has seen 300% growth in the last five years; infrastructure, such as bridges and water projects; and renewable energy, which accounts for 15% of capex for new projects. Cyril Varghese, global logistics director at Fluor, said the biggest issue clouding any outlook by project shippers, forwarders or carriers right now is not knowing how long the war in the Middle East will last. âWhat are the trickle effects going to be?â he said at Breakbulk26. âWhat is the trade reconfiguration going to look like? How much is protectionism and all countries trying to have a trade surplus or a balanced trade book impact your cargo movements across the globe?â Varghese said he is focused on what a prolonged conflict does to global GDP growth. âWhen you look at the [International Monetary Fundâs] World Economic Outlook, the recalibrated baseline for global growth is in the range of 3.1% for â26 and 3.2% for â27,â he said. âNow that's in a baseline scenario, assuming that the conflict ends soon. A severe scenario takes the growth global growth rate to 2.5% and 2.2%.â Vargheseâs contention is that carriers should be careful to not over-order breakbulk and multipurpose vessels with that uncertainty hanging over the industry, especially since new vessels entering the fleet tend to be able to carry more cargo than ones exiting the fleet. âIf the overall [economic] growth slows down, and if there is more protectionism, which is coming, and if the industry just becomes sluggish, I think we would be prudent in terms of not going into an expansion spree,â he said. âFlexibility crisisâ A more near-term issue is whether disruption to the supply of bunker fuel at key ports, especially in Asia, extends transit times and increases costs for projects. âOn paper everything looks fine,â Melanie Drehkopf, chief commercial officer at dship Carriers, told the conference when asked about bunker availability. âIn practice itâs getting tighter. There are longer lead times and you cannot just order bunker as you did before. The pricing validity window is shrinking, so if you have an offer, you better jump on it. Our flexibility is getting less and less, which means switching cargoes from one ship to another is harder.â Drehkopf said the industry doesnât have a supply crisis yet, âbut we have a flexibility crisis, especially in heavy-lift, where you donât have regular ports.â Looking further out, she said if the war persists for another month and continues to curtail fuel supply through the Strait of Hormuz, lead times will get longer. âItâs all a big question mark,â Drehkopf said. âI donât think itâs going to get better. I donât think it will idle capacity, but maybe you need to wait two, three, or four days to get the bunkers you need. There are already bottlenecks of some commodities due to a mismatch of vessels and specific commodities.â This article was originally published in the Journal of Commerce on April 27, 2026. Subscribe to JOC.com 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/market-intelligence/en/news-insights/research/2026/05/middle-east-fuel-shock-exacerbates-rising-us-ag-export-costs</link><description>The Middle East war is driving up US ag export costs and sapping global demand, extending a slowdown after weak 2025 growth and Chinaâ&amp;#x80;&amp;#x99;s fading market.&amp;#xd;&amp;#xa;&amp;#xd;&amp;#xa;</description><title>Middle East fuel shock exacerbates rising US ag export costs</title><pubDate>07 May 2026 18:30:00 GMT</pubDate><author><name>Bill Mongelluzzo</name></author><content><![CDATA[ Research â May 7, 2026 Middle East fuel shock exacerbates rising US ag export costs By Bill Mongelluzzo The war in the Middle East will further increase the cost of US agricultural exports â and further diminish global demand â after a 2025 in which growth slowed despite the efforts by shippers to replace a rapidly vanishing Chinese market. War-linked bunker fuel surcharges, as well as soaring diesel prices for inland truck and rail movements, could âadd tens of thousands to hundreds of thousands of dollars to our costs,â Mike Symonanis, director of strategic network at Louis Dreyfus Company and chairman of the American Cotton Shippers Association, told the Journal of Commerce. Symonanis said agricultural exporters are closely scrutinizing the surcharges, which will be most significant for small and midsize shippers, to determine whether they accurately reflect higher fuel costs borne by container lines. âIf the carrier says it costs them âX,â how do we get to the point of substantiation? This will be an ongoing conversation between shippers and carriers,â he said. For their part, carriers are attempting to mitigate the impact of rising bunker fuel costs through more direct sailings and slower steaming of vessels. At the Port of Oakland, which handles agricultural exports from Californiaâs Central Valley, âcarriers are asking the terminals to work 24/7, so they spend less time in port,â said Bryan Brandes, the portâs maritime director. Peter Friedmann, executive director of the Agriculture Transportation Coalition (AgTC), noted that the impact of those fees will intensify the longer the war drags on. âGenerally, costs are going up and will continue to go up until there is an end to the war,â Friedmann said. âThe fuel surcharges will have a cascading effect on ag shippersâ costs as they are phased in.â And although the US itself is a large producer of fertilizers, growers could also face higher costs for fertilizers if the Strait of Hormuz remains closed for too long, with crops that consume large quantities of ammonia and phosphates particularly vulnerable. Piling on the pressure The additional costs for shippers â and resulting drag on demand abroad â come at a time when export growth was already slowing, primarily due to Chinese import tariffs in response to duties imposed by the Trump administration. Containerized US agricultural exports grew 2.9% last year, but that was down from 7.1% growth in 2024, according to PIERS, a sister product of the Journal of Commerce within S&amp;P Global. Perhaps more alarming, outbound agricultural product shipments have declined at a compound annual rate of 1.7% since 2020. âWhen the impact of tariffs is a higher price that other countries donât have to deal with, that certainly diminishes our market access and encourages competitors to develop longer-term strategies to expand their market access,â said Buddy Allen, president and CEO of the American Cotton Shippers Association. Both Allen and Mike Steenhoek, executive director of the Soy Transportation Coalition, said products from Brazil have largely taken the place of US cotton and soybeans in the Chinese market, creating what Steenhoek described as âconsiderable headwindsâ for exports. Mainland Chinaâs share of US agriculture exports fell to 6.2% from 15.7% in 2024 and as high as 23.7% in 2022, according to PIERS. In dollar terms, Chinese buyers purchased just $3.1 billion worth of soybeans in 2025, down from $17.9 billion the year before, Steenhoek said. The rapid shift of agricultural exports to other markets is also being felt at the port level. âSix years ago, about 70% of our cargo was tied to China. Today, itâs closer to 60%, with countries in Southeast Asia growing in importance,â said Noel Hacegaba, CEO of the Port of Long Beach. Cotton exports through Long Beach plummeted 90% last year, while soybean exports fell 95%, he said. The good news for growers is that there is growing global demand for soybeans, which move primarily in bulk ships, as well as higher-value processed soybean products like meal and oils, which tend to move in containers. Steenhoek said promising markets include the Philippines, Colombia, Mexico, Canada, Guatemala, and Vietnam. âPotentially, 2026 could be a good marketing year in terms of demand, but there are so many uncertainties ahead in terms of tariffs,â he said. âThis is an industry where you are making your commitments today for deliveries months away.â Originally published in the Journal of Commerce on May 4, 2026. Subscribe to JOC.com Register for Inland26 The must-attend conference for shippers and transportation and logistics providers moving goods from ports to inland destinations Click Here Learn more about our data and insights Click Here ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/2026/05/prolonged-middle-east-war-to-weigh-on-sputtering-us-auto-demand</link><description>Buyers of automobiles and auto parts will face another level of sticker shock if the war in the Middle East extends into the summer.</description><title>Prolonged Middle East war to weigh on sputtering US auto demand</title><pubDate>14 May 2026 12:00:00 GMT</pubDate><author><name>Bill Mongelluzzo</name></author><content><![CDATA[ BLOG â May 14, 2026 Prolonged Middle East war to weigh on sputtering US auto demand By Bill Mongelluzzo US demand for automobiles and auto parts has been straining under higher inflationary costs, but buyers, both consumers and manufacturers, will face another level of sticker shock if the war in the Middle East extends into the summer. Even before the war-driven spike in gasoline prices, the US automotive industry was steeling for a tough year. Prior to the start of the conflict, Journal of Commerce parent company S&amp;P Global forecast that vehicle sales would fall 2% from the previous year due to a long list of headwinds for the industry, including higher borrowing costs for vehicle buyers and steel tariffs upping input prices. But already relatively high prices for new vehicles and auto parts â the cheapest new 2026 model car available is $20,550, according to CARFAX â will increase significantly if the war continues through May, according to a mid-March report from S&amp;P Global. If the war lasts through the end of 2026, that elevated pricing will negatively impact consumer demand and, by extension, container volumes. A war scenario of more than a year will result in continued inflation and declining demand until prices reach a new âset point,â S&amp;P Global analysts said. Containerized US imports of automobiles and auto parts fell 9.4% year over year in 2025, dragging the five-year compound annual growth rate (CAGR) down to 3.8%, according to PIERS, a Journal of Commerce sister product within S&amp;P Global. Exports, meanwhile, spiked 15.3%, boosting the five-year CAGR to 6.6%. The majority of seaborne vehicle imports and exports travel via roll-on/roll-off (ro/ro) ships; those volumes are not captured by PIERS data. The uncertainties surrounding the length of the war will undoubtedly impact the US container trade in vehicles and parts as importers and exporters in the automotive sector review and possibly modify their business plans, said Chris Hopson, principal analyst for the global light vehicle forecast group at S&amp;P Global. â2025 was an uncertain year because of the tariffs, and the auto industry digested it better than we might have expected,â Hopson said. However, due to the war in Iran, how long the industry can continue to bear those higher costs âis open to question.â The weakening market for new US car sales has a silver lining for importers of aftermarket parts used to maintain and repair vehicles, such as filters, batteries and brakes. Customers of Advance Auto Parts, who are often in one of the most economically depressed cohorts, typically would rather keep their cars running a little longer than shop for a new car, said CEO Shane OâKelly. âThat car is how they get to work; itâs how they get to church; [how] they get the kids to activities,â OâKelly told investors during a March 11 earnings call. âIf that thing is not running, theyâre getting it fixed, so I donât necessarily see demand curtailing.â âGeneral inconsistenciesâ Auto parts importers have been looking â and will continue to look â at changing sourcing away from China to Southeast Asia and the Indian subcontinent because of the higher tariffs imposed last year, according to Steve Hughes, a consultant for the aftermarket auto parts industry. But those changes canât happen overnight, Hughes explained, because it takes anywhere from six months to two years to set up operations in a new location. Mainland China accounted for 35.2% of US containerized autos and parts imports last year, down from more than 40% as recently as 2021, according to PIERS. The primary beneficiaries of Chinaâs declining market share, South Korea and Japan, have increased their combined share of the market to 27% from 20.8% during that period. Noel Hacegaba, CEO of the Port of Long Beach, said the port has experienced a general shift of sourcing of most imports, including autos and auto parts, away from China to other countries. Imports of passenger vehicles landing in Long Beach, mostly on ro/ro ships, were flat in 2025, while exports rose 6.2% year over year, according to Hacegaba. Containerized auto parts imports through the port rose 1.1%, while exports fell 15%. Los Angeles-Long Beach is the busiest US port complex for containerized auto imports. The Port of Baltimore, also a major gateway for ro/ro and containerized auto imports and exports, continues to feel the impact of tariffs. Those impacts are reflected in the higher prices consumers must pay, but the problem runs even deeper than cost, said Jonathan Daniels, executive director of the Maryland Port Administration (MPA). âThe biggest issue we have seen with shippers is the general inconsistencies in the tariffs,â Daniels told the Journal of Commerce. Although original equipment manufacturers take higher tariff costs as a given, not knowing the exact rate for finished vehicles and components makes it difficult to make strategic sourcing and production decisions, Daniels explained. Depending on the level of tariffs on each, it might be cheaper to import fully assembled cars, or it might make more sense to import the necessary pieces and assemble them in the US. Despite these uncertainties, more than 700,000 automobiles and light trucks crossed Baltimoreâs docks for the 13th consecutive year in 2025, according to MPA data. Daniels said the port continues to develop infrastructure to support processing facilities in the region, adding that exports of damaged cars to West Africa to be used for parts remains a bright spot for the industry. For containerized exports, the largest individual markets are the United Arab Emirates and Georgia, which accounted for 12% and 11.8% of outbound auto and part shipments, respectively, with no other country exceeding 10%, according to PIERS. Subscribe to JOC.com Register for Inland26 The must-attend conference for shippers and transportation and logistics providers moving goods from ports to inland destinations Click Here Learn more about our data and insights Click Here ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/2026/05/ai-throwing-wrench-into-arbitrage-machine-for-forwarding-labor</link><description>AI has the potential to cut freight forwarders&amp;apos; costs by 15-35%, boost productivity, and reshape operations, enabling higher margins and market share in logistics.</description><title>AI throwing wrench into arbitrage machine for forwarding labor</title><pubDate>28 May 2026 12:00:00 GMT</pubDate><author><name>Eric Johnson</name></author><content><![CDATA[ BLOG â May 28, 2026 AI throwing wrench into arbitrage machine for forwarding labor By Eric Johnson Freight forwarders donât own cargo, and they are largely reliant on the assets of ocean, air, and road capacity providers. That liminal state puts them right at the center of the debate about whether artificial intelligence will transform how logistics is conducted. Beyond the rhetoric of whether AI can functionally replace hundreds of thousands of people currently employed in operational, sales, development and administrative roles at forwarders, thereâs a more basic metric thatâs worth tracking. That is, how will AI â or, more specifically, automation enabled by AI â impact a forwarderâs cost structure? Because until recently, the money a forwarder spent per shipment boiled down in large part to how much it spent on labor to perform core tasks along the shipment lifecycle. âFor a digitally mature forwarder with decent data and workflow discipline, AI should be able to cut routine file-handling costs by roughly 15% to 35% over the next two to three years,â said Amit Maheshwari, CEO of Softlink, a provider of freight management solutions for forwarders. âOn a poor-quality, exception-heavy import file, the savings will be lower. On a clean, repeatable lane with structured inputs, the savings can be higher. âAI changes the math by shrinking the clerical piece of the work, but it does not erase local import knowledge, customer escalation, customs risk, claims handling, or delivery trouble-shooting,â Maheshwari added. A simplistic way to view this challenge is that all the tasks a forwarder needs to execute on each shipment can be visualized on a spectrum of fully manual to fully automated. But that spectrum doesnât account for the reality that forwarders have long tried to minimize their labor costs outside of automation. Those efforts sometimes come in the form of handing off work to business process outsourcing (BPO) providers, overseas agents, or employees in lower-cost regions. That interplay of optimizing what work is done where, to maximize skills and customer engagement while making sure costs are in line with business expectations, is being upended by AI. Wider margins, higher growth JP Morgan, in a February report, posited that, âwith successful deployment [of AI], the top European players can gain up to 200 [basis points] of market share and reduce staff costs by 20%, driven by higher productivity and monetizing natural attrition.â That, in turn, has the potential to help large, publicly traded forwarders reach margins of 30% to 45% and double-digit operating profit growth by 2028, the bank said. For argumentsâ sake, letâs say that a forwarder using an origin office to handle all administrative aspects of a shipment is paying $120, while that same work handled at destination would cost $180. That 50% premium is the target for AI-enabled workflow automation. âThe origin-destination spread is real,â said Jamie Andrade, senior vice president of product management at SEKO Logistics. âA lot of the client-facing work, i.e. the service and differentiation bits we donât want to offshore or automate away, sits on the destination side, and the labor differential is material. That said, it is getting eroded as costs rise [at origin]. Weâre seeing that in our own operation and with our offshore partners. And honestly, you can only shift so much to origin before service starts to suffer.â One example, from a software vendor who asked not to be identified, cited an example of a forwarding customer with nearly 100 IT and key account support staff, and 400 more employees handling basic freight forwarding operations at origin. âThey donât have a plan to reduce labor costs [via automation] because of the complexity of dealing with origin activities,â and because labor costs remain sustainable, the vendor said. âI think we will first see AI improving productivity and reducing manual labor more at the destination than at the origin,â said Hans Elmegaard, CEO of forwarding software vendor Moddule. âAt destination, people manually coordinate operational activities between customers, carriers, customs offices, trucking companies/rail services, and share information with [distribution centers] and warehouses across various fragmented datasets. AI-backed orchestration services will help freight forwarders reduce labor costs and increase accuracy for their customers.â Differentiator or table stakes? A broader question is the extent to which automation drives differentiation in a crowded market over the long term, and whether a theoretical lower cost to serve bleeds into customer pricing. Forwarding software WiseTech Global, in completely restructuring its pricing model last fall and later announcing it was reducing headcount by 30% over two years due to AI productivity gains, essentially signaled to the market that forwarders would have to reduce their cost to serve and that their customers would expect those gains to be passed through. But the danger, argues Graham Cousins, former chief strategy officer at Vanguard Logistics Services, is that automation undermines rather than enhances margin. âThe challenge is that, at scale, lower cost-to-serve is not a core differentiator, and perhaps a risk if passed on in customer pricing,â Cousins wrote in a paper on how the international logistics industry was transforming. âAI is not the bolt-on to make operatorsâ lives and workflows easier,â he wrote. âCustomer service processes must be restructured to be AI-native and ensure data coverage, not to augment existing manual operations. Procurement and low cost-to-serve are baselines, not differentiators. If it ends up in pricing, the rest of the market will follow.â So, at its core, the story of AI in forwarding is ultimately about how logistics services providers balance their current cost structure against one where automation plays a bigger role. What can be automated? âMost things along the shipment lifecycle are automatable,â said Robert Petti, CEO of forwarding software provider Prompt. â[WiseTechâs new pricing model] should have pushed people to do more automating. And the vast majority doesnât require new tech. Integrated systems and good [standard operating procedures] should reduce labor cost 30% to 50%. That should get you closer to the origin costs and maybe even lower.â Dan Bailey, CEO of forwarding workflow automation provider Nexcade, said itâs important for a forwarder to focus on a specific time horizon. âWeâve seen two times file-per-head improvements in the specific workflows we target, but weâre also heavily focused on areas with commercial benefit, like procurement and quotation, not just [operating expenditures],â he said. âOn simpler workflows itâs higher, but on an aggregate basis across the full lifecycle of all shipments, exceptions are still a primary driver of operational time and cost.â Bailey said those exceptions are impacted less in the short run by AI but are âsquarely in strike zone in the medium term,â adding that exception management was also largely unaddressed by business process outsourcing (BPO) efforts in the past. âWith automation levels of 60% to 80% of well-scoped processes, there can easily be a three- to four-times cost advantage for that specific process vis-Ã -vis lower origin per-shipment costs,â Fabian Struck, chief commercial officer of forwarding automation vendor Zauber, said. âThis advantage is respectively higher for high-wage geographies. In the long run, we can only speculate what will ultimately be possible. For now, I do not see any reasons why total end-to-end shipment costs should not go down as far as three to five times, or even more.â Low end of the curve JP Morganâs report cautioned that the forwarding industry still âsits low on the digitization curve,â with a reliance on manual processes and data that poses a risk to fully leveraging the benefits of AI for cost reduction. âWe do not expect AI to disrupt the fundamental prospects of the industry, given its exposure to physical transport and the movement of goods, with freight forwarding increasingly tapping into more complex services and moving further away from commoditized vanilla brokerage services,â the report said. The other factor for forwarders to consider is that investments in technology to automate are not likely to stay static, but in fact are likely to move in a linear fashion with usage. That may prompt some to build internally. âThatâs part of why Iâm leaning into building some of this ourselves for the easier use cases,â Andrade said. âIf I own the tooling, my costs stay flatter as we scale rather than growing in line with transaction volume. Itâs not the right answer for everyone, and you need [developer] resources and the appetite to maintain what you build. âBut weâve got that capability, and the new AI coding tooling makes it faster to stand things up than it used to be,â she added. âSo thatâs where Iâm placing my bets, at least on the BPO and automation side of the house.â This article was originally published in the Journal of Commerce on May 12, 2026. Subscribe to JOC.com Register for Inland26 The must-attend conference for shippers and transportation and logistics providers moving goods from ports to inland destinations Click Here Learn more about our data and insights Click Here ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/2026/06/canada-readies-legislation-overhauling-supply-chain</link><description>Canadian supply chain legislation may reshape labor reform, port infrastructure and operations, boosting trade resilience and reducing freight disruption.</description><title>Canada readies ambitious legislation to reform supply chain</title><pubDate>02 June 2026 18:00:00 GMT</pubDate><author><name>Eric Johnson</name></author><content><![CDATA[ BLOG â June 2, 2026 Canada readies ambitious legislation to reform supply chain By Mark Szakonyi A series of federal consultations in Canada this month have laid the groundwork for new supply chain-focused legislation seeking to reduce labor disruption at seaports and other transport modes. The consultations by the federal government on transportation labor, ports and digitalization lasted mere weeks, reflecting the speed of the current government and its intentions for legislation anticipated to be introduced as soon as mid-June, according to three sources familiar with the matter. The legislation is part of a larger effort by Prime Minister Mark Carney to double non-US exports within the decade and boost supply chain resilience by investing in ports and curbing freight disruptions. âTheyâre moving at the speed of Carney,â said one of the sources, referring to the prime ministerâs aggressive approach to reform and investment. The source added that the governmentâs first meaningful attempt to reform Canadaâs labor code in three decades was âunprecedented.â Still, Canadian labor groups are warning against any attempt to have port workers designated as essential employees, thus crippling their ability to strike and employersâ ability to lock them out. âUnifor has and will engage in good faith in this flawed process, but we can hear the dog whistles of union-busting weaved throughout the governmentâs questions and reference documents,â Lana Payne, the unionâs national president, said in a statement. â¯ But one source tied to federal labor relations said the legislation is unlikely to strip the right to strike from organized workers and instead to create a special mediator to guide contract negotiations through bumps and impasses. The mediator role was one of the recommendations to come out of a federal study on Canadian West Coast ports. Such an individual would get involved in negotiations from the beginning and provide recommendations publicly when negotiations grind down, according to the labor relations source. How much power this mediator would have to force arbitration, however, isnât yet clear. The federal study of West Coast ports labor was triggered by a 13-day work stoppage in 2023 at the ports of Vancouver and Prince Rupert, which was followed in late 2024 with a 10-day strike and then lockout. The disruptions were two of 16 that have impacted the transportation sector since 2019, according to Canadaâs Ministry of Transportation. The current contract between the International Longshore and Warehouse Union (ILWU) and British Columbia employers expires in March 2027, with formal negotiations expected to begin in November, according to the labor relations source. Increase borrowing limits of ports Through the supply chain legislation, port employer interests also want to enshrine into law that the ILWU can only negotiate with employers as a group rather than individually. The Canadian West Coast isnât recognized in Canadaâs labor code as a common geography similar to the East Coast with the ports of Halifax, Montral and Saint John. The union during past contentious negotiation cycles has threatened to complicate contract talks by negotiating with each of the West Coastâs more than one dozen employers rather than collectively with the British Columbia Maritime Employers Association. Out of the consultations focused on ports, backers hope the legislation that follows will allow ports to increase their borrowing abilities. It costs tens of thousands of dollars and takes at least a year for port authorities to increase their borrowing limits, said Daniel-Robert Gooch, president and CEO of the Association of Canadian Port Authorities. His group proposes rather than enforcing a strict borrowing limit, a debt-to-income ratio should be imbedded in the constitution, providing flexibility to faster-growing ports. Port authorities also want a freer hand to engage in activities outside their land and waterway such as being able to sell unused, prime downtown acreage, Gooch said. âIf Vancouver is challenged [borrowing for] projects, then surely, just about every other port in the country that is much smaller than Vancouver probably faces the same challenge to a degree,â said Peter Xotta, CEO of the Vancouver Fraser Port Authority. Fussing over fees In addition to wanting labor reform, ocean carriers and marine terminal operators want the Canadian legislation to inject more transparency into its leases with tenants, particularly as it pertains to special fees. The Canada Transportation Agency on Feb. 13 dismissed a request by the Shipping Federation of Canada to intervene against Vancouver Fraser Port Authorityâs empty container fee. Gooch, representing port authorities, downplayed how much more transparency is needed in terms of port fees, arguing the current system to challenge these fees is sufficient. Xotta said that tenants need to be able to understand and challenge fees, but it canât hamstring the port authorityâs ability to make a return on investment. The federal consultations also addressed potentially repealing the Shipping Conference Exemption Act, a move that ocean carriers and terminal operators support if the limited antitrust exemption allowing operating alliances remains. That protection could be granted by the government via a policy statement, according to one source close to the shipping industryâs thinking. The consultations tied to digitalization have been focused on harmonizing systems and could potentially lead to legislation requiring the creation of a maritime single window, a digital platform for the clearing of ships, cargo and crews. This article was originally published in the Journal of Commerce on May 29, 2026. Subscribe to JOC.com Register for Inland26 The must-attend conference for shippers and transportation and logistics providers moving goods from ports to inland destinations Click Here Learn more about our data and insights Click Here ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/2026/06/us-bolsters-customs-enforcement-of-small-and-foreign-importers</link><description>Trumpâ&amp;#x80;&amp;#x99;s executive order boosts CBP customs enforcement: higher bonds, stricter scrutiny of foreign IORs, beneficial-ownership checks, and tougher penalties.</description><title>US bolsters customs enforcement of small and foreign importers</title><pubDate>11 June 2026 12:00:00 GMT</pubDate><author><name>Mark Szakonyi</name></author><content><![CDATA[ BLOG â Jun 11, 2026 US bolsters customs enforcement of small and foreign importers By Mark Szakonyi US President Donald Trump has signed an executive order strengthening customs enforcement to enhance the scrutiny of importers, particularly smaller businesses and those based abroad. The executive order, signed June 3, will raise bonding requirements for importers of record (IORs) and require them to show they arenât shell companies by disclosing domestic assets. The order also places increased scrutiny on âforeignâ IORs, including not allowing them to make informal customs entries, which are typically used for low-value shipments. The order targets small, infrequent importers that are largely unknown to US Customs and Border Protection (CBP), as well as importers using diversions from one country to another to reduce their duty exposure. Importers will also be required to share volume forecasts with CBP, although the frequency hasnât been disclosed. âCustoms reform is long overdue. Systemic inefficiencies, loopholes, insufficient enforcement mechanisms, and outdated processes have created opportunities for malign actors to evade federal law,â Trumpâs order read. âExamples of noncompliance include undervaluing imports, withholding critical information about IORs and the goods being imported, and avoiding payment of duties through various arrangements and schemes.â The executive order requires US importers to show they have a physical US presence, generate business activity, and hold domestic assets. Importers will also be required to provide more detailed information, including proof of beneficial ownership and more exact product specification, and provide to the CBP within 90 days the identical paperwork given to customs agencies at the country of origin. The order also calls for Customs to not allow relief from penalties over 50% of the assessed value and limit repeat offendersâ ability to challenge penalties. Customs and the Department of Homeland Security are mandated within 180 days to create enhanced methods to fight the evasion of duty paying and other customs noncompliance. The immediate online response to Trumpâs executive order from the customs community has been mixed. On one hand, the order could answer a question that has long dogged customs brokers: Who truly owns the cargo and is thus legally responsible? Others fear that, besides creating more administrative work, the order will give license to customs agents to be heavy-handed. Higher scrutiny, more holds The executive order, which the White House says wonât take effect immediately, comes as customs brokers and shippers, at least anecdotally, report an increase since the start of this year in customs holds placed on their inbound containers. Shipments from Vietnam, where goods made in China can be misclassified to avoid higher tariffs, receive extra scrutiny, and sourcing shifts to Southeast Asia create unfamiliar origins on customs declarations, raising the interest of agents, various sources tell the Journal of Commerce. Thereâs been a recent increase in customs holds for containers from China at the ports of Los Angeles and Long Beach, said Alexander Owens, an attorney and partner at Pietrangelo Gordon Alfano Bosick. CBP doesnât disclose data on how many times it stops a container for inspection, something that delays shipments and opens cargo owners and consignees to additional storage fees. But thereâs no doubt Customs enforcement has ramped up. The Department of Justice through the first five months of the year has received more than $570.6 million in judgements and settlements tied to government contracting fraud, according to Owens, who represents whistleblowers who make claims under the False Claims Act, legislation that allows the federal government to pursue fraud committed against federal programs. âThe rise in customs holds is likely the result of a confluence of several factors: a protectionist administration, the end of the de minimis exemption, and CBPâs increasing use of AI to screen shipments for anomalies,â Owens said. âFrankly, given how hawkish this administration is on trade, it would be unusual if holds didnât rise.â Higher tariffs in Trumpâs second term have spurred some shippers to turn to a delivered duty paid (DDP) structure where the seller assumes all risks and costs but sometimes undervalues the tariffs that were owed, said Steven Heid, president of SJ Stile Associates, a customs broker and forwarder. As a result, Customs are taking a harder look at overseas shippers, foreign entities and those using questionable structures in duty payment, he said. âFrom an industry perspective, many customs brokers, freight forwarders, sureties, and compliance professionals began noticing increased scrutiny as tariffs became a larger component of landed costs,â Heid said. âThere is also a growing belief within the trade community that CBPâs increased use of advanced data analytics and artificial intelligence allows the agency to more effectively identify unusual trade patterns, importers-of-record changes, valuation anomalies, country of origin concerns and significant shipping arrangements over time.â This article was originally published by the Journal of Commerce on June 4, 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/oil-price-assumptions-raised-as-hormuz-disruption-deepens-and-inventory-buffers-erode-near-term-henry-hub-price-assumptions-lowered-s101689190</link><description>S&amp;amp;P Global Ratings believes there is a high degree of unpredictability around the duration and scale of the Middle East war and its potential effect on commodity prices, supply chains, economies, and credit conditions. As a result, our baseline forecasts carry a significant amount of uncertainty. As situations evolve, we will gauge the macro and credit materiality of potential shifts and reassess our guidance accordingly. This report does not constitute a rating action. S&amp;amp;P Global Ratings recent</description><title>Oil Price Assumptions Raised As Hormuz Disruption Deepens And Inventory Buffers Erode; Near-Term Henry Hub Price Assumptions Lowered</title><pubDate>05 June 2026 16:35:27 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/agriculture/060826-wef-warns-el-nino-poses-systemic-risk-as-shipping-flags-food-and-coal-risk</link><description>The World Economic Forum has warned that an emerging El Nino weather pattern poses a systemic shock to global markets, with shipping industry analysts flagging potential disruptions to Asian coal demand and agricultural trade flows as the climate event develops through mid-2026. The WEF said in a June 5 report that El Nino should be seen as more than a weather story, warning that the 2026-27 event</description><title>WEF warns El Nino poses systemic risk as shipping flags food and coal risk</title><pubDate>08 June 2026 18:58:39 GMT</pubDate><author><name>Samyak Pandey</name></author><content><![CDATA[ Agriculture, Coal, Energy Transition, Grains, Thermal Coal, Food, Meat, Vegetable Oils, Oilseeds, Renewables, Biofuels June 08, 2026 WEF warns El Nino poses systemic risk as shipping flags food and coal risk By Samyak Pandey Editor: Karla Sanchez Getting your Trinity Audio player ready... HIGHLIGHTS Asian coal demand surges amid power shortages Shipping faces trade flow shifts through 2027 The World Economic Forum has warned that an emerging El Nino weather pattern poses a systemic shock to global markets, with shipping industry analysts flagging potential disruptions to Asian coal demand and agricultural trade flows as the climate event develops through mid-2026. The WEF said in a June 5 report that El Nino should be seen as more than a weather story, warning that the 2026-27 event could strike a planet already facing brittle food systems, fragile public finances, stressed energy markets and growing geopolitical instability. The organization said the phenomenon will likely test the resilience of institutions already operating close to their limits, with far-reaching consequences for commodity markets and supply chains. The warning comes as the World Meteorological Organization confirmed on June 2 an 80% likelihood of an El Nino event between June and August 2026, while the US National Oceanic and Atmospheric Administration's Climate Prediction Center estimates a 96% probability the pattern will persist into early 2027. Shipping market analysts said the timing of the weather event coincides with peak Asian power demand, Indian monsoon risk and grain-crop formation across major producing regions, creating potential volatility for freight rates. For dry bulk markets, the greatest impact is expected through coal movements to Asia. India's peak power demand has already reached 270.73 gigawatts, above the government's summer expectation of 270 GW, after four consecutive days of record demand, according to shipping industry data. Coal still accounts for more than 70% of Indian power generation, and a hotter, drier summer is expected to extend the call on coal-fired generation and slow the rebuilding of domestic stocks. Freight implications Asian thermal coal imports are forecast at 76.26 million metric tons in May, up 23% from April and above last year's May level. China's seaborne arrivals are projected at 22.63 million mt, while India's are expected at 13.78 million mt,according to Intermodal data. The increased coal movements are expected to support incremental imports into India, mainly from Indonesia, Australia and South Africa, helping absorb Panamax and Kamsarmax ships supply in the Indian and Pacific Oceans. "El Nino is again becoming a factor for 2026, and its freight impact is likely to be felt mainly through Asian power demand, crop risk and trade-flow shifts," shipping analysts at Intermodal said in a May 26 market report. "The important point for shipping is timing; this is developing into the Northern Hemisphere summer, when Asian power demand, Indian monsoon risk, Pacific weather disruption and grain-crop formation all start to matter at the same time." The impact on agricultural commodities presents a more complex picture for shipping markets. El Nino leads to reduced rainfall in Australia, Indonesia and parts of South Asia, while improving moisture conditions in parts of southern South America. Current projections point to a 19% fall in Australian wheat output to 29 million mt in 2026-27, with exports falling 2.5 million mt to 23.5 million mt, according to industry forecasts cited by Intermodal. The WEF said El Nino threatens to further disrupt commodity markets already showing the impact of economic risks, warning that the world must be prepared for a climate shock layered on top of a cost-of-living shock. Rice is an important bellwether because it is both a traded commodity and a daily necessity for billions of people, the organization said. Asian farmers have already reduced rice planting amid soaring energy and fertilizer costs due to the war in the Middle East, and El Nino threatens supplies of the world's most consumed staple. Platts, part of S&amp;P Global Energy, assessed Vietnam 5% WR at $405/mt FOB on June 8, up $1/mt day over day. Platts assessed Fragrant 5% rice at $489/mt FOB, down $1/mt day over day. Global supply chains also face disruption as drought lowers river levels and impedes inland transport, floods damage roads, ports, warehouses and processing plants, and heat reduces labor productivity across sectors, the WEF said. Agriculture is especially exposed because input costs are rising just as climate risks intensify. The World Health Organization has warned that El Nino events are associated with heat stress, exposure to wildfire smoke, vector-borne diseases, drought-related health impacts, and nutrition shocks. In already hot regions, the phenomenon can push temperatures beyond safe thresholds for outdoor workers, older people, children and those with chronic illnesses. Trade flow shifts For agricultural freight, support may come less from higher volumes and more from trade-flow shifts, shipping analysts said. A weaker Indian monsoon could lift imports of vegetable oils, pulses, feed grains and fertilizers, while Indonesia and Malaysia's palm oil supply may redirect the vegetable oil trade. Platts assessed CPO CFR WC India at $1,232.50/mt June 8 for June loading, up $2.50/mt from June 5. South America could gain a relative export share in soybeans and meal if the weather improves there while Asian crops suffer, creating more Atlantic-to-Asia demand and ship repositioning, especially in the Supramax and Panamax segments. Platts last assessed the SOYBEX FOB Santos soybean contract for July loading at $443.33/mt on June 5, down $7.17/mt from the previously assessed June 3. "The freight conclusion is therefore selective," Intermodal said. "El Nino is more constructive for coal freight than for grain freight in the near term. It supports Pacific dry bulk utilization through Asian power demand, while creating downside risk to Australian grain exports and upside risk to Atlantic grain and oilseed tonne-miles." The strongest freight response will come if heat, weak monsoon rainfall and Indonesian supply disruption occur together, the analysts said. Without that combination, El Nino is expected to act as a volatility driver rather than a blanket bullish event for freight rates. 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-can-indias-sustainable-finance-market-boost-corporate-interest-s101689300</link><description>This report does not constitute a rating action. What we&amp;apos;re watching: Indiaâ&amp;#x80;&amp;#x99;s sustainable bond market is structurally shallow, with corporate issuers favoring alternative funding channels. After peaking in 2023-2024, the countryâ&amp;#x80;&amp;#x99;s sustainable bond issuance declined to about $2 billion in 2025 (see chart 1), with 62% of issuance being green bonds and 38% social bonds. Compared with other key emerging markets (EMs), Indiaâ&amp;#x80;&amp;#x99;s sustainable bond market has remained modest, with higher rates and h</description><title>Sustainability Insights: Can India&amp;apos;s Sustainable Finance Market Boost Corporate Interest?</title><pubDate>08 June 2026 10:02:00 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/060426-hydrogen-moves-from-blueprints-to-reality-as-capacity-set-to-double-hydrogen-council</link><description>The hydrogen sector has fundamentally shifted from planning to execution, with global operational production capacity expected to double in 2026 as industrial-scale projects come online, Hydrogen Council CEO Ivana Jemelkova told Platts, part of S&amp;amp;P Global Energy. The milestone reflects a step change in project scale and maturity, with companies now building multi-hundred megawatt-scale facilities,</description><title>Hydrogen moves from blueprints to reality as capacity set to double: Hydrogen Council</title><pubDate>04 June 2026 15:09:32 GMT</pubDate><author><name>James Burgess</name></author><content><![CDATA[ Energy Transition, Hydrogen June 04, 2026 Hydrogen moves from blueprints to reality as capacity set to double: Hydrogen Council By James Burgess Editor: Arushi Jain Getting your Trinity Audio player ready... HIGHLIGHTS Industry sees operational capacity doubling in 2026 Energy security, resilience become driving force EU RFNBO rules need quick, decisive rationalization The hydrogen sector has fundamentally shifted from planning to execution, with global operational production capacity expected to double in 2026 as industrial-scale projects come online, Hydrogen Council CEO Ivana Jemelkova told Platts, part of S&amp;P Global Energy. The milestone reflects a step change in project scale and maturity, with companies now building multi-hundred megawatt-scale facilities, Jemelkova said in an interview following the World Hydrogen Summit in Rotterdam in May. The first 10-MW-scale plants began operating only in the last few years. "Hydrogen is happening," Jemelkova said in the May 21 interview. "It is now a reality. We are in the middle of actually executing rather than planning or setting the vision. It's steel in the ground." S&amp;P Global Energy Horizons data shows a total of 3.7 GW of installed electrolyzer capacity globally, with over 2.1 GW of that coming online since the start of 2025. The shift comes as governments reassess energy investments in the wake of compounded crises. The Hydrogen Council estimates energy-importing countries in Europe and Asia have spent an additional $100 billion on fossil fuel imports and fiscal measures in just the first two months after the start of the US-Israeli war with Iran, which could have accelerated clean technology deployment. "Right now, we are spending billions of euros, billions of dollars on additional costs for the existing supply," Jemelkova said. "All of this could be invested into the future." Recent energy shocks -- including the post-COVID disruption, the Russia-Ukraine conflict and the war in the Middle East -- have prompted governments to fundamentally rethink energy strategies, Jemelkova said. The crises have heightened awareness of energy security and costs, creating new urgency around domestic resource development and diversified supply partnerships. "Imagine what we could do with that if we were to invest it into clean technologies, into resilience measures," Jemelkova said. "The value that we're wasting right now is tremendous." The Hydrogen Council's 2025 Compass report identified $110 billion in committed low-carbon hydrogen investments. Hydrogen inflection point The doubling of operational hydrogen capacity represents a crucial inflection point for an industry that has moved rapidly from the megawatt to gigawatt scale. Of some 1,700 announced projects globally, around 510 have reached advanced stages, passing final investment decisions or entering construction, according to the Hydrogen Council's tracking data. Those statistics were reflected in the mood at the World Hydrogen Summit, with executives optimistic about the sector following a period of policy uncertainty, project delays and cancellations, and consolidation. Discussions have focused on scaling production, whereas just a year ago the emphasis was on implementation of policy, plans and projects. The Hydrogen Council has called on governments to accelerate implementation of existing policies, particularly in Europe where ambitious strategies have not fully translated into market reality. Jemelkova said the Hydrogen Council's call to action had received a positive reception from officials, including the Dutch energy minister who chaired the meeting. She said the practical implementation of frameworks like the EU's Renewable Energy Directive and rules for renewable fuels of non-biological origin could provide significant momentum. "Just the implementation of what we already have could be a big boost," Jemelkova said. "Obviously, it wouldn't be enough, but it would give industry the confidence to keep going and keep building." European hydrogen rule review The European Commission's review of rules governing renewable hydrogen production has divided industry participants, with some supporting the postponement of requirements like additionality and temporal matching, while first movers who have already taken investment decisions seek regulatory certainty. The planned move to hourly matching of hydrogen production with renewable generation would add about Eur2/kg to production costs, industry leaders say. Platts assessed the cost of EU-compliant green hydrogen production via alkaline electrolysis in the Netherlands, backed by renewable power purchase agreements, at Eur9.46/kg ($11/kg) on June 3. The Hydrogen Council advocates rationalizing Renewable Fuels of Non-Biological Origin rules to enable broader market participation while protecting first movers who responded to regulatory signals. "It doesn't matter if you win the race if you're the only one running," Jemelkova said. "It is really important that we unlock the market, and that requires pragmatism. We need to be practical to allow more players to come in and give everyone the opportunity to transition." Jemelkova said any review must be completed quickly and decisively, potentially through mechanisms like grandfathering to balance opening markets with maintaining advantages for early projects. "We cannot have another two or three years of wondering which way to go," Jemelkova said. "If the European Commission wants to review, please do it quickly and decisively so that we know where we stand." 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/060326-brazilian-cbio-prices-hit-lowest-level-in-platts-series</link><description>Platts assessed the Brazilian Decarbonization Credit, or CBIO, at the lowest level in its historical series June 2, at Real 24/metric ton of CO2 equivalent. The series dates back to June 3, 2024, with the previous low on Dec. 16, 2025, at Real 24.5/mt. The move followed a preliminary injunction issued May 27 by Brazil&amp;apos;s federal audit court, the TCU, suspending the effects of administrative</description><title>Brazilian CBIO prices hit lowest level in Platts series</title><pubDate>03 June 2026 20:00:42 GMT</pubDate><author><name>Monique Murer</name></author><content><![CDATA[ Agriculture, Energy Transition, Biofuels, Emissions June 03, 2026 Brazilian CBIO prices hit lowest level in Platts series By Monique Murer Editor: Derek Sands Getting your Trinity Audio player ready... HIGHLIGHTS CBIO prices fall to record low at Real 24/mt Court suspends penalties for pre-2025 compliance shortfalls Higher 2026 mandate fails to tighten market Platts assessed the Brazilian Decarbonization Credit, or CBIO, at the lowest level in its historical series June 2, at Real 24/metric ton of CO2 equivalent. The series dates back to June 3, 2024, with the previous low on Dec. 16, 2025, at Real 24.5/mt. The move followed a preliminary injunction issued May 27 by Brazil's federal audit court, the TCU, suspending the effects of administrative sanctions against fuel distributors that failed to meet RenovaBio compliance obligations for cycles closed through Dec. 31, 2024. The decision did not suspend current or future compliance obligations. It ordered the National Agency of Petroleum, Natural Gas and Biofuels, or ANP, to design a regularization program for distributors with past shortfalls, while temporarily suspending penalties, such as fines and restrictions on fuel commercialization, tied to those earlier cycles. That means that distributors previously exposed to penalties for past non-compliance may now have less incentive to buy and retire CBIOs in the prompt market while they wait for ANP's regularization framework. As a result, the decision is likely to weigh on near-term CBIO demand, even though the underlying obligation has not been canceled. Higher 2026 mandate fails to tighten prompt market The 2026 national CBIO target is higher than in 2025, at 48.09 million CBIOs, compared with 40.39 million CBIOs in 2025, an increase of 19.1%. Despite the higher annual target, the market does not appear as tight as the headline obligation would suggest, with CBIOs prices at a record low. Brazil CBIO market indicators, Jan. 2-June 2 2025 2026 Difference Year over Year Annual target million CBIOs 40.39 48.09 19.1% Accumulated retirements million CBIOs 6.17 8.73 41.5% Retirements / annual target % 15.3% 18.2% 2.9% Remaining annual target million CBIOs 34.22 39.36 15.0% Total stocks million CBIOs 28.27 28.52 0.9% Stocks / annual target % 70.0% 59.3% -10.7% Definitive trading volume million CBIOs 34.00 40.59 19.4% Definitive trading volume / annual target % 84.2% 84.4% 0.2% Retirements reached 8.73 million CBIOs from Jan. 2 to June 2, 2026, compared with 6.17 million CBIOs in the same period of 2025. As a share of the annual target, retirements stood at 18.1% in 2026, up from 15.3% in 2025, indicating stronger year-over-year compliance progress. CBIO stocks, meaning all CBIOs available in the market and not yet retired, also remained broadly stable in absolute terms, while declining relative to the annual target. Total stocks stood at 28.52 million CBIOs on June 2, 2026, compared with 28.27 million CBIOs on the equivalent date in 2025, an increase of only 0.9%. But because the 2026 target is materially higher, stocks represented a lower share of the annual target -- 59.3% in 2026, compared with 70.0% in 2025. CBIOs over the long term When considering potential movements in CBIO prices over the mid- and long-term, several factors should be taken into account. According to Frank Nadimi, consultant at S&amp;P Global Energy Horizons, one important variable is the "compliance rate." This means that the price level of CBIOs will increase when compliance levels compared to the obligations set by the Ministry of Mines and Energies increase. Another aspect is the biofuels considered under the CBIOs. Brazil's supply/demand for ethanol and biodiesel, which comprise the majority of emitted CBIOs, is well established with a large domestic balance. "When considering sustainable aviation fuel and renewable diesel, these biofuels should be evaluated in a more international context, as the SAF and RD markets are in an earlier stage of development and global supply chains are being formed," Nadimi said. "Hence, SAF- and RD-related CBIO levels will likely show a degree of correlation with international credit levels, whereas the majority of CBIOs will remain ethanol- and biodiesel-related." S&amp;P Global Energy Horizons has developed a proprietary, long-term CBIO price-forecasting methodology through 2060, with different scenarios impacting CBIO value. 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/060526-interview-australias-nh3-clean-energy-targeting-wah2-project-fid-by-year-end-chairman</link><description>Australia&amp;apos;s NH3 Clean Energy aims to take a final investment decision on its WAH2 project by year-end, with commercial ammonia-bunkering operations set to start in 2030, aiding the use of cleaner fuels to accelerate decarbonization, Chairman Charles Whitfield told Platts, part of S&amp;amp;P Global Energy, in an interview. The WAH2 project is NH3&amp;apos;s flagship project to supply low-emissions ammonia. The</description><title>INTERVIEW: Australia&amp;apos;s NH3 Clean Energy targeting WAH2 project FID by year-end: chairman</title><pubDate>05 June 2026 10:31:27 GMT</pubDate><author><name>Surabhi Sahu</name><name>Ruchira Singh</name></author><content><![CDATA[ Natural Gas, LNG, Fertilizers, Chemicals, Energy Transition, Electric Power, Coal, Renewables June 05, 2026 INTERVIEW: Australiaâs NH3 Clean Energy targeting WAH2 project FID by year-end: chairman By Surabhi Sahu and Ruchira Singh Editor: Aastha Agnihotri Getting your Trinity Audio player ready... HIGHLIGHTS WAH2 Project to produce 650,000 mt annually in Phase 1 Secure gas supplies under Western Australiaâs Dom Gas Policy Blue ammonia bunkering commercial operations targeted 2030 Australia's NH3 Clean Energy aims to take a final investment decision on its WAH2 project by year-end, with commercial ammonia-bunkering operations set to start in 2030, aiding the use of cleaner fuels to accelerate decarbonization, Chairman Charles Whitfield told Platts, part of S&amp;P Global Energy, in an interview. The WAH2 project is NH3's flagship project to supply low-emissions ammonia. The project is targeting not only powering bulk carriers carrying iron ore from Australia to Asia for sustainable shipping but also meeting the power needs of the Asia-Pacific region, including the Japanese and South Korean markets, as they decarbonize, Whitfield said. The WAH2 Clean Ammonia Project is one of the few projects that becomes even more important in the light of the conflict, due to its supply from a geopolitically stable source and its proximity to the Asia market, without relying on transshipment through maritime "pinch points", according to Whitfield. The Pilbara to Asia route, also known as the Iron Corridor, is the world's largest shipping route by tonnage. So, it is of prime importance to introduce clean marine fuels, Whitfield said. NH3 Clean Energy plans to offer blue ammonia bunker fuel to customers at the two major Pilbara ports â Port Hedland and the Port of Dampier âwith first production at WAH2 targeted for the end of 2029. Phase 1 will entail a total blue ammonia production of 650,000 metric tons per year, and pre-FEED cost estimates are about $600/metric ton, making the project "very cost-competitive", Whitfield said. Natural gas serves as feedstock for the project, Whitfield shared. "So, we get gas from the North West Shelf, and that comes onshore at Dampier. The Dampier Bunbury pipeline takes that gas towards Perth, and our plant is right next to that pipeline. So, supplies are secure," Whitfield said, reflecting minimal costs as additional infrastructure requirements are diminished. The company secures gas under Western Australia's Dom Gas Policy. That gas is sold at a fixed-price basis, and while it is inflation-linked, it is not linked to global gas or oil indexes, according to Whitfield. "So, we are not exposed to supply risks and volatile prices, particularly amid uncertain global geopolitics such as the prevailing Middle East crisis," he said. "That is very attractive for our customers because our input prices are fixed under long-term supply contracts, offering buyers a smooth and secure portfolio," he added. Meanwhile, some Asian buyers have been sitting on the edge of a volcano in terms of their risk profile related to energy dependence on the Middle East, according to Whitfield. With the Middle East conflict, "that volcano is erupting currently", emphasizing the need to diversify their energy sources, Whitfield said, adding that this will drive the push for using a blend of ammonia and coal in thermal stations, offering many Asian economies the flexibility of maintaining coal-fired power stations while also cutting emissions by blending ammonia. Forging partnerships NH3 Clean Energy has also forged numerous agreements to bring together the various elements of the supply chain ecosystem. In June 2025, NH3 Clean Energy inked a joint development agreement with Oceania Marine Energy, the operator of the bunkering vessel to provide ammonia via ship-to-ship transfers, and the Pilbara Ports Authority, a government enterprise that controls and manages the Port of Dampier, oversees safety in the port waters, and issues bunkering licenses, Whitfield shared. The company signed an MOU with Mitsui O.S.K. Lines, Ltd, which builds on the existing JDA between NH3, Pilbara Ports, and Oceania Marine to establish an ammonia hub in the Pilbara by 2030. More recently, NH3 Clean Energy also inked a deal with Japan's Itochu Corp. to build further on the JDA. The agreement aims to aggregate 300,000 TPA of demand to be supplied by NH3's planned WAH2 Project, investigate financing options, and support the FID. Whitfield is optimistic about ammonia's future as a bunkering fuel. "Compared to other alternative marine fuels such as methanol and LNG, we feel ammonia has key advantages," Whitefield said, adding that it is scalable and is carbon-free when combusted. LNG has low emissions, but it is not zero-carbon by any means, and future regulatory frameworks will determine how LNG gets treated from an emissions perspective, Whitfield said. As far as bio-methanol is concerned, it is a question of scale, Whitfield opined. "If you are looking to produce methanol from bio-waste, aggregating enough green waste near a processing hub and having that available at a point where it is required for bunkering is quite challenging," he said. Meanwhile, Whitfield said that some people were disparaging clean ammonia due to the challenges facing the cost and availability of "green" electrolysis-based production. However, blue ammonia does not face these issues as it is an established technology, plentiful, and a low-cost option, according to Whitfield. Platts assessed Australia Renewable-derived Ammonia delivered into Far East Asia, with high-capacity factors at $761.61/mt on June 1, down 0.12% from a month ago. It assessed conventional ammonia CFR, Far East Asia at $800/mt on June 5, up about 3.90% from a month ago. 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/060526-watchdog-agency-finds-us-doe-may-have-wrongly-redirected-clean-energy-funds</link><description>The Trump administration may have violated federal law by redirecting fiscal year 2025 funds away from clean energy research and development, the US Government Accountability Office concluded in a legal decision issued June 4. The DOE did not respond to a request for comment on June 5. The nonpartisan agency, known as an independent watchdog for the US Congress, issued the decision in response to</description><title>Watchdog agency finds US DOE may have wrongly redirected clean energy funds</title><pubDate>05 June 2026 20:49:39 GMT</pubDate><author><name>Zack Hale</name></author><content><![CDATA[ Electric Power, Energy Transition, Metals &amp; Mining, Renewables June 05, 2026 Watchdog agency finds US DOE may have wrongly redirected clean energy funds By Zack Hale Editor: Meghan Gordon Getting your Trinity Audio player ready... HIGHLIGHTS GAO finds DOE may violate federal funding law Wind, solar programs saw cuts of 78% and 87% The Trump administration may have violated federal law by redirecting fiscal year 2025 funds away from clean energy research and development, the US Government Accountability Office concluded in a legal decision issued June 4. The DOE did not respond to a request for comment on June 5. The nonpartisan agency, known as an independent watchdog for the US Congress, issued the decision in response to a request from Senator Patty Murray, Democrat-Washington, vice chair of the Senate Appropriations Committee, and Representative Marcy Kaptur, Democrat-Ohio, ranking member on the House Energy and Commerce Committee's Subcommittee on Energy and Water Development. In July 2025, Murray and Kaptur formally asked the GAO to issue a legal determination on whether the US Energy Department's fiscal year 2025 spending plan violated the federal Purpose Statute and the Antideficiency Act. The Purpose Statute requires that appropriated funds be used only for the specific purposes for which Congress intended and authorized them, while the Antideficiency Act prohibits agencies from spending in excess of appropriated amounts. In its June 4 decision, the GAO found that the DOE's fiscal year 2026 budget justification appears to show fiscal year 2025 funding obligations for five of six congressional "control point" accounts in excess of amounts originally set forth in a full-year fiscal year 2024 funding bill. The fiscal year 2024 amounts, as well as the fiscal year 2024 spending package's explanatory statement, were carried forward for fiscal year 2025 under a continuing resolution largely passed by congressional Republicans and signed by President Donald Trump The five DOE accounts identified by the GAO were for energy efficiency and renewable energy, nuclear energy, fossil energy, non-defense environmental cleanup and science. "On its face, DOE's obligations in comparison to the congressionally set ceiling amounts from the FY 2024 explanatory statement suggest that DOE may have violated the Purpose Statute and the [Antideficiency Act]," the GAO said. However, the GAO cautioned that "it may be possible that DOE's seeming over-obligations stem from other available funding sources, such as carry-over no-year appropriations from prior years or transfer authority." The GAO said the DOE "has not provided us with adequate information about its funding sources to determine whether a Purpose Statute or an [Antideficiency Act] violation has occurred." Democrats say decision confirms 'lawbreaking' In a news release, Murray and Kaptur went further by arguing that the GAO's June 4 decision "confirmed what's been clear from the start: the Trump administration broke the law when it gutted investments in affordable, clean energy." The Democrats noted that the fiscal year 2024 spending package â which was effectively carried forward into fiscal year 2025 â provided the DOE with $137 million for wind energy and $318 million for solar energy. But the Trump administration allocated just $29.8 million for wind and $41.9 million for solar in fiscal year 2025, resulting in respective cuts of 78% and 87%, they said. Meanwhile, Murray and Kaptur noted that the DOE issued a notice of funding opportunity in February, making $146.5 million in fiscal year 2025 funds available for geothermal energy despite Congress only providing $118 million for the technology. "American families have paid the price for this lawbreaking â in higher energy costs, in canceled university and industry research awards, and in national lab scientists who lost their jobs," Murray and Kaptur said. "The administration must take steps to immediately comply with the law, and we must work on a bipartisan basis to insist the Department follows the law." The GAO report comes as House Republicans advance a fiscal year 2027 energy and water spending package that would implement a 40% cut to Biden-era clean energy programs. The package would boost funding for nuclear and geothermal energy, as well as critical minerals, materials and manufacturing. 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/060526-philippines-adds-saf-production-to-strategic-investment-priority-plan</link><description>The Philippines has identified sustainable aviation fuel production as a strategic investment priority, positioning the biofuel sector to receive government incentives aimed at developing domestic manufacturing capacity and reducing reliance on imports. President Ferdinand Marcos Jr. approved the 2026 Strategic Investment Priority Plan on May 21, which places SAF production under Tier II priority</description><title>Philippines adds SAF production to strategic investment priority plan</title><pubDate>05 June 2026 19:50:19 GMT</pubDate><author><name>Samyak Pandey</name></author><content><![CDATA[ Agriculture, Energy Transition, Refined Products, Biofuels, Renewables, Jet Fuel June 05, 2026 Philippines adds SAF production to strategic investment priority plan By Samyak Pandey Editor: Karla Sanchez Getting your Trinity Audio player ready... HIGHLIGHTS Targets domestic output with incentive framework Tier II status grants tax incentives SAF prices rise $50/mt to $2,610/mt The Philippines has identified sustainable aviation fuel production as a strategic investment priority, positioning the biofuel sector to receive government incentives aimed at developing domestic manufacturing capacity and reducing reliance on imports. President Ferdinand Marcos Jr. approved the 2026 Strategic Investment Priority Plan on May 21, which places SAF production under Tier II priority activities alongside electric vehicle infrastructure and critical minerals processing, according to a memorandum order released June 3. The three-tier framework determines which industries qualify for tax incentives under the Corporate Recovery and Tax Incentives for Enterprises Act, with higher tiers receiving longer incentive periods ranging from 14 to 27 years, depending on location and priority classification, the Philippine Information Agency said on June 4. Strategic push The inclusion of SAF reflects the government's push to develop domestic biofuel production capabilities as the aviation sector faces mounting pressure to reduce carbon emissions. Tier II classification signals that SAF production addresses strategic industrial gaps and import substitution priorities, placing it alongside defense services, desalination plants and food security initiatives. "By listing activities eligible for incentives, the government is signaling where we want to attract high-value capital and translate these into new jobs, upskilling of workforce and improved lives for Filipinos," Trade Secretary Cristina Roque said in a statement. The 2026 plan replaces the 2022 framework and aligns with the administration's long-term economic transformation agenda through 2028. Qualified businesses under Tier II can access income tax holidays, special corporate income tax rates and enhanced deductions administered by investment promotion agencies including the Board of Investments. The Board of Investments will finalize general policies and specific guidelines for the 2026 plan by the third quarter, with existing 2022 guidelines remaining in effect until then, according to Sandra Recolizado, director of the BOI's Investment Policy and Planning Service. The memorandum order takes effect 15 days after publication in a newspaper of general circulation or the Official Gazette. The plan also prioritizes renewable energy projects, energy storage systems and green manufacturing under Tier I, while Tier III covers advanced technologies including hydrogen energy and modern biotechnology. All government agencies must coordinate implementation and cannot adopt policies inconsistent with the plan. Platts, part of S&amp;P Global Energy, assessed sustainable aviation fuel HEFA-SPK FOB Straits at $2,610/mt June 4, up $50/mt from June 3, and FOB China at $2,585/mt June 4, up $50/mt from June 3. The SAF FOB Straits premium was assessed at $1,463.75/mt over the Platts Jet Kero FOB Mean of Platts Singapore price, up $59.75/mt from June 3, while the FOB China premium was at $1,438.75/mt over the Platts Jet Kero FOB MOPS price. 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/060526-eu-carbon-prices-retreat-as-booster-funding-details-trigger-selloff</link><description>European carbon prices fell in the week ended June 5 after details emerged showing the EU will fund the Emissions Trading System Investment Booster from existing allowance reserves, triggering profit-taking following a rally above key technical levels. EU Allowances were trading at Eur77.29/metric ton of CO2 equivalent ($89.99/mtCO2e) at 1152 GMT June 5, according to the Intercontinental Exchange,</description><title>EU carbon prices retreat as booster funding details trigger selloff</title><pubDate>05 June 2026 13:02:26 GMT</pubDate><author><name>Irina Breilean</name><name>Eklavya Gupte</name></author><content><![CDATA[ Energy Transition, Carbon June 05, 2026 EU carbon prices retreat as booster funding details trigger selloff By Irina Breilean and Eklavya Gupte Editor: Gary Gentile Getting your Trinity Audio player ready... HIGHLIGHTS EU carbon prices fall 4% below Eur80/mt July 15 ETS review in focus EUA-UKA spread stays narrow at around Eur13/mtCO2e European carbon prices fell in the week ended June 5 after details emerged showing the EU will fund the Emissions Trading System Investment Booster from existing allowance reserves, triggering profit-taking following a rally above key technical levels. EU Allowances were trading at Eur77.29/metric ton of CO2 equivalent ($89.99/mtCO2e) at 1152 GMT June 5, according to the Intercontinental Exchange, down 4% from May 29. Platts, part of S&amp;P Global Energy, assessed EUAs for the December 2026 contract at Eur77.17/mtCO2e June 4, down 2% from the previous settlement. Prices fell steadily June 4 after media reported 400 million allowances earmarked for the Investment Booster will come from new entrant reserves and existing free permit buffers, citing EU officials. Analysts told Platts that this is effectively considered new supply, as the volumes were not expected to be used until a later phase of the EU ETS. "The correction was quite stark, particularly because it went through the 200-day moving averages, so it broke a couple of technical levels," said Jan Ahrens, co-founder at analytics firm Transition Metrics. "But the underlying justification is more a technical correction, rather than an underlying fundamental shift." There are still a lot of unknowns around the new entrants reserve, Ahrens said. "But in the longer term, it could be bearish because those 400 million would have entered the market anyway, so the bearish effect is negligible." But in the short term, it could be bullish for the market, Ahrens said. This would be the case if the EU decides to use allowances that would otherwise be released next year, bringing them to market this year instead, to fund the decarbonization booster as of 2028. The EUA drop comes after investment funds had increased positions when price levels surpassed Eur80/mtCO2e the week before. A UK-based carbon trader said that "everything that got added last week is now slowly coming out," and that Eur75/mtCO2e remains a key price level. "We are back below 200 DMA [daily moving average], which signals more ranging and more of the same market we had," the trader said. Investment funds increased net long bets to 51.3 million EUAs the week ending May 29, a 31.2% weekly rise equivalent to 12.2 million allowances. This came after weeks of reductions, as prices hovered around the Eur75/mtCO2e level. Demand weakens Physical demand from the power sector also weakened as cooler weather reduced air conditioning needs and boosted wind generation across Europe, traders said. CustomWeather forecasts expect northwest European temperatures to drop below seasonal average until June 17, while southern European temperatures are expected to remain below norm until June 11, before rising above or hovering around seasonal averages until June 17. Market participants are also awaiting clarity on the future of the EU ETS, with a review of the market planned to start on July 15. Brussels will look at multiple design options spanning sectoral expansions, free allowances and supply-demand balancing rules. The last review took 22 months to finalize, but officials have previously said they plan to complete the review's implementation by the first quarter of 2027, reducing the turnaround time. Many traders and analysts expect prices to hold in a Eur75-80/mtCO2e range until the ETS review delivers clarity or the Middle East conflict resolves, both seen as potential catalysts that could break the current stalemate amid concerns about demand destruction across Europe. Analysts at S&amp;P Global Energy CERA expect EUAs to average Eur75/mtCO2e through the second half of the year, as structurally tight supply balances against weakened industrial demand. UKAs track lower In the UK market, carbon prices dropped tracking the larger EU market. UK Allowances traded at GBP55.63/mtCO2e ($74.88/mtCO2e) at 1124 GMT, according to ICE data, down 5% from the settlement price on May 29. Platts, part of S&amp;P Global Energy, assessed the December 2026 contract at GBP55.41/mtCO2e June 4. The spread to EUAs closed at Eur13.13/mtCO2e June 4, largely unchanged from the previous week's close at Eur13.10/mtCO2e. The EUA-UKA spread narrowed last week on improved linking sentiment. The UK government recently confirmed that it is negotiating an emissions trading deal with the EU, which will be one of the key focus areas at the upcoming UK-EU summit, expected to be held in July, according to industry sources. Traders expect the price for UKAs to equal that of EUAs in the long term, should the two schemes link. But the process could be lengthy with no timeline currently confirmed. 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/060526-uks-cph2-abandons-electrolyzer-manufacturing-after-test-incident</link><description>UK-based Clean Power Hydrogen has abandoned plans to manufacture its membrane-free electrolyzers after an incident during testing led to substantial damage to the unit, it said in a statement June 5. The incident occurred during the third and final stage of factory acceptance testing of the company&amp;apos;s 1-MW MFE220 unit, which it reported on May 29. The electrolyzer was damaged during a standard</description><title>UK&amp;apos;s CPH2 abandons electrolyzer manufacturing after test incident</title><pubDate>05 June 2026 10:46:43 GMT</pubDate><author><name>James Burgess</name></author><content><![CDATA[ Energy Transition, Hydrogen June 05, 2026 UKâs CPH2 abandons electrolyzer manufacturing after test incident By James Burgess Editor: Jonathan Fox Getting your Trinity Audio player ready... HIGHLIGHTS CPH2 abandons electrolyzer production plans Testing incident causes substantial damage Company explores licensing amid funding woes UK-based Clean Power Hydrogen has abandoned plans to manufacture its membrane-free electrolyzers after an incident during testing led to substantial damage to the unit, it said in a statement June 5. The incident occurred during the third and final stage of factory acceptance testing of the company's 1-MW MFE220 unit, which it reported on May 29. The electrolyzer was damaged during a standard shutdown procedure, and the company suspended test operations. "A subsequent inspection at the test site and review of all available data indicate that the damage to the unit is significant and that it will not be possible to repair the system to allow the testing process to continue," CPH2 said in the June 5 statement. The cause of the incident remains under investigation. The company's chief technical officer and chief operations director said the unit would require "substantial redesign to ensure that the mixed gas system can be operated safely in all conditions." As a result, the company will not recommence testing activities and will switch focus to non-manufacturing, commercial strategies for development. "Whilst the board retains confidence in the potential of the technology, it has concluded that the company does not currently have the financial, engineering or technical resources" to carry out the redesign needed, CPH2 said. The company said its intellectual property has "significant commercial value," and is exploring options to maximize value for shareholders and stakeholders, including potential licensing options. CPH2 said its working capital remains constrained and there is "material uncertainty" over continuing operations. Discussions with capital providers are ongoing, it said. As a result, trading in the company's shares on the London Stock Exchange's AIM remains suspended. The company paused discussions with existing shareholders and prospective new investors on a potential equity capital raise following the incident, it said May 29. Completion of factory acceptance testing was originally expected in May. In March, the company signed a nonbinding memorandum of understanding with Siemens to scale up production of CPH2's technology. 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-shrinking-canopies-nature-loss-may-amplify-physical-risks-in-forestry-value-chains-s101666262</link><description>Sectors like bioenergy and paper production face potential financial and operational risks from their dependence on forest ecosystems. The likelihood of increasingly frequent and severe climate hazards exacerbates these risks (see &amp;quot; Risky Business: Companies&amp;apos; Progress On Adapting To Climate Change ,&amp;quot; April 3, 2024). Wildfires, for example, have burned millions of hectares of commercial forest globally (World Resources Institute 2025 Global Forest Review), leading to reduced production and asset </description><title>Sustainability Insights: Shrinking Canopies: Nature Loss May Amplify Physical Risks In Forestry Value Chains</title><pubDate>04 June 2026 07:20:39 GMT</pubDate></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/energy/en/news-research/latest-news/agriculture/060326-summits-jetbio-aims-for-a-2-billion-1-billion-liter-atj-saf-plant-in-brazil</link><description>US private equity company Summit Agricultural Group plans to invest about $2 billion to build a sustainable aviation fuel plant in Brazil, targeting a first production timeline of 2030, the company&amp;apos;s CEO Will Moore told Platts on June 3. The facility, to be operated through a new company called JetBio, will produce 1 billion liters (around 254 million gallons or 770,000 mt) of alcohol-to-jet SAF</description><title>Summit&amp;apos;s JetBio aims for a $2 billion, 1 billion-liter ATJ SAF plant in Brazil</title><pubDate>03 June 2026 18:27:27 GMT</pubDate><author><name>Samyak Pandey</name></author><content><![CDATA[ Agriculture, Energy Transition, Refined Products, Biofuels, Renewables, Jet Fuel June 03, 2026 Summit's JetBio aims for a $2 billion, 1 billion-liter ATJ SAF plant in Brazil By Samyak Pandey Editor: Juan Tolentino Getting your Trinity Audio player ready... HIGHLIGHTS Production aimed to start in 2030 Company to export 90% of production Facility will use 1.8 billion liters of low CI ethanol US private equity company Summit Agricultural Group plans to invest about $2 billion to build a sustainable aviation fuel plant in Brazil, targeting a first production timeline of 2030, the company's CEO Will Moore told Platts on June 3. The facility, to be operated through a new company called JetBio, will produce 1 billion liters (around 254 million gallons or 770,000 mt) of alcohol-to-jet SAF annually. To achieve these volumes, the plant will source 1.8 billion liters of low-carbon ethanol from a diverse group of Brazilian waste, second-crop corn, and sugarcane producers. "We will be targeting all low-carbon aviation markets and exporting 90% of our production," Moore said told Platts over email. "We are currently in discussions with international airlines, freight carriers, and fuel suppliers," Moore said, adding that the export framework will maintain a "particular focus on the EU, UK, and APAC markets" to capture surging compliance demand as international carriers race to meet global emission reduction mandates. JetBio is currently finalizing its location blueprints, with Paulinia in SÃ£o Paulo state emerging as the absolute front-runner due to its advanced industrial infrastructure and strategic highway and rail connectivity. "While we are still evaluating other potential options, Paulinia is the front-runner," Moore added. "We would expect to make an announcement on the site very soon." The projected 254 million-gallon annual capacity makes the JetBio asset roughly 25 times larger than LanzaJet's Freedom Pines Fuels facility in Georgia, US, the world's first commercial ethanol-to-SAF operation, according to JetBio. "Our scale is intentional to achieve the lowest production cost and lowest CI [carbon intensity] of any ATJ SAF in the world," Moore said. "This will also offer our customers supply diversity and security at meaningful volumes to their overall Jet-A supply portfolios." The feedstock edge The project leverages Brazil's lower-carbon-intensity ethanol footprint compared to domestic US alternatives. JetBio's hybrid feedstock sourcing strategy will utilize a mix of sugarcane and second-crop corn. The entity is expected to draw heavily from regional producers, including FS, Brazil's second-largest corn ethanol producer, in which JetBio's parent company, Summit Agricultural Group, already holds a significant equity stake. The massive supply requirements come amid fluctuating regional feedstock prices. Platts, part of S&amp;P Global Energy, last assessed the Brazilian corn FOB Santos price for August loading at $217.70/metric ton on June 2, $1.87/mt lower than the previous 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/052926-factbox-asia-pacific-bets-big-on-renewable-hydrogen-as-deals-infrastructure-prices-align</link><description>Asia-Pacific could become a key driver in commercializing low-carbon hydrogen and its derivatives, as firm supply agreements, emerging infrastructure buildouts, and low production costs signal the region&amp;apos;s ambition to anchor the future global clean fuel trade. The region hosts about 795 projects with a combined projected capacity of about 35.20 million metric tons/year, including renewable-derived</description><title>FACTBOX: Asia-Pacific bets big on renewable hydrogen as deals, infrastructure, prices align</title><pubDate>29 May 2026 13:58:39 GMT</pubDate><author><name>Ruchira Singh</name><name>Vipul Garg</name><name>Mark Astley</name></author><content><![CDATA[ Fertilizers, Chemicals, Energy Transition, Renewables, Hydrogen May 29, 2026 FACTBOX: Asia-Pacific bets big on renewable hydrogen as deals, infrastructure, prices align By Ruchira Singh, Vipul Garg, and Mark Astley Editor: Adithya Ram Getting your Trinity Audio player ready... HIGHLIGHTS Energy supply shocks push clean fuel shift Deals signal early hydrogen trade flows Costs start to drive market optimism Asia-Pacific could become a key driver in commercializing low-carbon hydrogen and its derivatives, as firm supply agreements, emerging infrastructure buildouts, and low production costs signal the region's ambition to anchor the future global clean fuel trade. The region hosts about 795 projects with a combined projected capacity of about 35.20 million metric tons/year, including renewable-derived and fossil fuel-based hydrogen with carbon capture, according to S&amp;P Global Energy's Hydrogen Production Assets database. The Middle East conflict could accelerate a structural shift, with the transport, power, and industrial sectors increasingly pivoting toward renewables and low-carbon hydrogen -- a transition already beginning to take shape across the region, Nobuo Tanaka, chair of the steering committee of the Innovation for Cool Earth Forum and former executive director of the International Energy Agency, has said. "The oil shock will certainly push Asian countries into the more energy-efficient model of economic growth," Tanaka said. Below are select facts on Asia-Pacific's emerging renewable hydrogen and ammonia infrastructure, trade flows, and prices. Infrastructure Chifeng, Inner Mongolia, an emerging hub of renewable hydrogen/ammonia projects, is expected to connect to northeast China, from which seaborne exports can be made to Asia and Europe, according to Frank Yu, Envision Energy's senior vice president, hydrogen marketing and sales product line president. India's Pudimadaka, a 60-acre renewable hydrogen hub in Andhra Pradesh led by NTPC Green Energy, expects to start the first plant by 2029, with 2.5 million mt/y of low-carbon fuels such as renewable ammonia, methanol, and e-SAF on the cards, targeting Europe and Asia. A 3,500 mt capacity gas carrier, An Shun Yuan, which called at Lianyungang Feb. 16-18 and Dalian Feb. 19-21, arrived at Ulsan in South Korea Feb. 26 to deliver renewable ammonia from Envision Energy to Lotte Fine Chemical, according to the companies and data from the S&amp;P Global Maritime platform. Japan's Kawasaki Heavy Industries and Japan Suiso Energy have signed a contract to build a 40,000 cubic meter liquid hydrogen carrier, marking a move toward establishing a commercial-scale hydrogen supply chain. Western Australia hosts InterContinental Energy's 1.6 million mt/y renewable hydrogen hub -- the Australian Renewable Energy Hub in the Pilbara -- and the 5 million mt/y Western Green Energy Hub in the Goldfields region. Trade flows L&amp;T Energy GreenTech has signed a long-term agreement with Japan's Itochu Corp. to supply 300,000 mt/y of renewable ammonia from Kandla, Gujarat, on a captive, take-or-pay basis, with the first output expected in 2029. India's Reliance Industries said in April that it is likely to have more renewable ammonia export deals following the 15-year supply agreement with South Korea's Samsung C&amp;T starting 2028-29. AM Green Ammonia has signed a binding deal with Germany's Uniper for up to 500,000 mt/y of renewable fuel of non-biological origin-certified renewable ammonia supply starting 2028 from a 1 million mt/y plant in Kakinada, Andhra Pradesh. Japan's Ministry of Economy, Trade and Industry said in December 2025 that it certified two ammonia projects developed by JERA and Mitsui as part of the country's ongoing Yen 3 trillion ($19.6 billion) hydrogen price-gap subsidy plan. China's Envision Energy signed a binding sales agreement to supply Japan's Marubeni with renewable ammonia from its Chifeng project, according to a May 2025 report by the renewable hydrogen developer. In 2024, Korea Power Exchange opened a 6,500-GWh, 15-year tender under its Clean Hydrogen Portfolio Standard for power production using low-carbon hydrogen, picking Korea Southern Power Co. as the preferred bidder, with a capacity of 750 GWh/y. A demonstration voyage by the world's first liquid hydrogen carrier, Suiso Frontier, in February 2022, from Hastings, Victoria, Australia, to Kobe, Japan, proved that an international liquid hydrogen supply chain could enable large-scale trade in the environmentally friendly fuel. Prices Platts, part of S&amp;P Global Energy, assessed the India renewable hydrogen term contract at $3.19/kg as of May 18, mostly unchanged from a month earlier. Platts assessed Australia renewable-derived ammonia delivered to Far East Asia, with high-capacity factors, at $761.71/mt on May 25, down 0.5% from a month earlier. India's government-conducted domestic renewable ammonia auctions, which concluded in August 2025 at a weighted-average price of around $604/mt, have set a new price point for global trade. India's renewable hydrogen prices reached a new low in February, as NeuEn Green Energy won Numaligarh Refinery Ltd.'s tender at Rupees 279/kg ($3.08/kg), excluding taxes. The FOB India renewable ammonia price has been mostly reported between $600/mt and $650/mt for Asian markets, while for the European market, the RFNBO-compliant price has been reported close to $700/mt, according to Platts heards data. The FOB China renewable ammonia price has been reported around $600/mt, Platts heards data showed. The gap between Platts' Japan AESI and the JKAP assessments illustrates the price support required to encourage uptake of low-carbon ammonia by power generation companies. The gap between Platts' renewable ammonia delivered to Japan and JKAP closed as a result of the gas price escalation due to the conflict in the Middle East. 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/secondary-markets-loan-prices-tick-up-as-new-issuance-rebounds-s101689330</link><description>This report does not constitute a rating action. While S&amp;amp;P Global Ratings thinks investors and borrowers will continue to be sensitive to potential risks in the market, for now the loan market is building on recent momentum after a slow start to the year. The secondary loan market continued to improve in May, building upon a strengthening trend that began in April following a turbulent start to the year. Despite an uncertain backdrop, risk assets last month generally performed well as strong cor</description><title>Secondary Markets: Loan Prices Tick Up As New Issuance Rebounds</title><pubDate>04 June 2026 17:50:04 GMT</pubDate></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/podcasts/private-markets-360/private-markets-360-episode-44-enduring-fundamentals-in-global-private-credit</link><description>In this episode of Private Markets 360Â°, we welcome Matt Harvey, Global Head of Middle Market Direct Lending at PGIM. Matt discusses the dynamic landscape of private credit, explaining PGIM&amp;apos;s core philosophy. </description><title>Private Markets 360 | Episode 44: Enduring Fundamentals in Global Private Credit</title><pubDate>28 May 2026 04:00:00 GMT</pubDate><author><name>Chris Sparenberg</name><name>Jocelyn Lewis</name></author><content><![CDATA[ Podcast â 28 May, 2026 Private Markets 360Â° | Episode 44: Enduring Fundamentals in Global Private Credit By Chris Sparenberg and Jocelyn Lewis In this episode of Private Markets 360Â°, we welcome Matt Harvey, Global Head of Middle Market Direct Lending at PGIM. Matt discusses the dynamic landscape of private credit, explaining PGIM's core philosophy. He highlighted the importance of their geographic allocation strategy, the evolving investor ecosystem and the necessity of educating increasingly sophisticated clients. More S&amp;P Global Content: 2026 Private Equity and Venture Capital Outlook Report S&amp;P Global, Cambridge Associates, Mercer Private Markets Performance Analytics Credits: Host/Author: Chris Sparenberg and Jocelyn Lewis Guests: Matt Harvey, PGIM Producer: Georgina Lee MAI Capital Management disclaimer: Any investment in private placed securities entails a high degree of risk, including the risk of loss, and they may not be suitable for all investors. Please consult your legal, tax and/or investment professional before making any investment decision. View Full Transcript Jocelyn Lewis [00:00:01]: Welcome to Private Markets 360, your insider's guide to the world of private investments. Today we're thrilled to have Matt Harvey, global head of middle market direct lending at PGIM, joining us. With 22 years of experience entirely in private credit and leading PGIM's middle market direct lending business, Matt has been instrumental in shaping PGIM's strategy in this critical sector. His deep expertise spans the evolution of private credit from its historical roots in investment grade lending to focus on sub investment grade opportunities. Matt, welcome to Private Markets360. It's a pleasure to have you with us today. How are you? Matt Harvey [00:00:44]: Very well, thank you. It's a pleasure to be here. Look forward to discussing the topic at hand today. Jocelyn Lewis [00:00:49]: Excellent. We are too. So to kick things off with your 22 years of experience entirely in private credit and lead PGIM's middle market direct lending business, could you describe PGIM's core investment philosophy in the space and what sets it apart? Matt Harvey [00:01:08]: Sure, happy to do that. The 22 years of history for myself is just a fraction of the decades of history PGIM and Prudential generally have in private credit, which really dates back to the 1940s in the United States, believe it or not. And that history is one of the things in effect that sets it apart. It sets it apart for two reasons. And generally you see this being more common among the most experienced managers. Number one is the reason of origination access in private credit. Generally what you're doing is you're financing companies that otherwise are not active participants in the capital markets. They don't have a listed or liquid Persona in that way. Matt Harvey [00:01:50]: And that means by definition they're difficult to find, they're difficult to understand, to underwrite, to develop relationships with. And all of that takes time, right, and decades of history and avails itself to the time it takes to go find all of these companies. So for us it starts with origination access. We can talk a little bit more how we go about that mechanically, but safe to say it takes a lot of time and a lot of effort to do properly at scale. The other thing that is a fundamental aspect of private credit that often and get sort of misplaced when people think about the asset class is that in many ways, fundamentally what we're doing is no different than what banks have always done. We are finding good companies with a capital need to lend to and to provide a capital solution to. And lending is the quite simple proposition of just simply getting your money back to finance a productive effort for the company. And over Time in terms of how we underwrite and identify those situations. Matt Harvey [00:02:54]: We've developed quite a bit of machine learning, I would call it internally, and how we identify to underwrite those risks, how those risks evolve in ways that could impact the investment strategy, could impact how we lend, how we price credit, how we structure credit, and so forth. But suffice to say that again is something that's honed over decades and also in many ways is fundamental. It evolves, but it's not radically different. And it's not as if the rise of the private credit asset class has necessarily changed those fundamentals at the basic lending level when we engage with the companies that we work with. So a lot of history and it's funny, when I started my career, private credit was very much a more obscure part of finance. Now it's very well publicized. But the point that I would leave the audience with is in many ways the fundamentals have not changed. We are lending to companies and seeking to get our capital back plus a small return for something that is a solution for the business that takes the capital. Chris Sparenberg [00:03:52]: And over PGIM's history, and indeed your history with the firm, we've seen a lot of evolution in strategy and focus. One really important point to call out is the shift from investment grade to now emphasizing sub investment grade credit. Could you take us through how that strategic shift occurred over the last two decades and what factors drove that change for pg? Matt Harvey [00:04:12]: Sure. Happy to. That's an accurate progression over time that you just outlined. We are one of the few, I would argue, larger firms, private credit, indirect lending anyway, that actually started as an investment grade credit investor. Many these days, some of the largest managers that are very well known started as private equity investors and moved up into private credit. We like to say we started as investment grade credit investors and moved down into a sub investment grade sphere as an addition to our platform, not a substitute for our platform. And that goes back to the history that I alluded to. But what drove that was essentially the opportunity set enlarging. Matt Harvey [00:04:54]: And although it did exist pre financial crisis in 2008, what really accelerated, obviously the ability and the demand for sub investment grade borrowers to access private credit away from the banks was of course the financial crisis and the regulation that tightened bank lending that ensued. And then you had a marketplace that developed very quickly. The adoption curve increased. Companies became aware of the benefits of using a non bank private credit solution to finance in particular events, which arguably is the best utility of a flexible non bank solution. Leveraged buyouts, acquisitions, recapitalizations, Et cetera. Of course, that started with private equity sponsors and again has more broadly penetrated the full issuer marketplace, which would include non sponsor privately held companies. And so for us, given our long term access point to these non sponsored privately held companies, starting with investment grade, we simply saw that market as an adjacency to our core market that shared many of the common fundamentals in terms of A origination access that I started with and B the fundamentals of underwriting credit. Whether you're underwriting a triple B investment grade credit that you would rate quality yourself, or you're underwriting a single B credit quality, many of the fundamentals are the same. Matt Harvey [00:06:22]: And for us that opportunity coincided with the adjacency of having access to these types of issuers over time. What has created a very symbiotic critical mass as we think about it, in the organization is frankly the ability to do both. The ability to finance both investment grade and non sponsored privately held companies alongside subinvestment grade, either private equity sponsored or non sponsored companies, creates an origination point that when we're in marketplace essentially just elevates our relevance to more issuers and allows us to repeat the process at scale. When you get down to it in private credit, again, if the idea is you're mining inefficiency to deliver value to both issuers and your investors at the same time, the more you can repeat that process at scale and increase the origination funnel as we call it, find more companies simply that are lending opportunities, which is then enabled and amplified by your ability to provide more capital solutions, then it creates what we think of as a beautiful cycle. It's scalable, it's repeatable, it's sustainable through cycles, and it allows us to increase selectivity and finance a broader part of the market. So sub investment grade credit has grown dramatically for us. Again, it's been an extension of our core offering, which is private credit, to companies that are seeking alternatives away from the banks for various reasons. Jocelyn Lewis [00:07:53]: Appreciate that perspective, Matt. And one of the things that is unique about what you're doing at PGIM is that, you know, you mentioned that you're really looking at fundamentals. You're looking at those fundamentals across a variety of investment opportunities and not only across those investment opportunities that you just mentioned, but also across geographies, so spanning North America, Europe and Australia, which are all creditor friendly jurisdictions and where you have to be familiar with not only the cultural norms, but some of the legal nuances that exist in those differing jurisdictions. So I'd love for you to elaborate a little bit on how the core principles of investing that you've developed over the years are applied in practice, especially when identifying value within the mid market Matt Harvey [00:08:57]: across these jurisdictions, sure, therein lies a scenario that creates opportunity again for the investor, but as well to provide a solution to the issuer. And you mentioned the key geographies that we participate in North America, Europe and Australia. Twenty years ago, direct lending and private credit was principally a US driven market. About 10 to 15 years ago, the UK market emerged post financial crisis as a model that sort of anglicized naturally the US model in terms of shift from bank to non bank credit investing and really sub investment grade event driven financing. And then of course over the last 10 to 15 years that trend has exp across all developed markets really. And so from our perspective, if we can find that commonality of strong private company that is growing and seeking financing options for event driven transactions, whether they sit in Nebraska, in the United States or the middle of Germany or Sydney, Australia, those commonalities exist in the same types of companies in various geographies. So what we then have to do is we have to determine a to your point, are these jurisdictions where the lending criteria and regulatory environment is creditor friendly. And clearly we tend to only lend in jurisdictions where that is the case. Matt Harvey [00:10:25]: But secondarily, given this is mid market, how do you develop the origination access? It comes back to that original point of you can find an asset attractive academically in one of these markets because the market opportunity is large. But if you don't have localized origination and you're essentially just a buyer of what that market produces, it is a lot harder to build and scale a properly disciplined, properly diversified credit portfolio. Especially as you get down into sub investment grade and you're clearly taking more credit risk at the individual loan level. So for us again, it comes back to that origination. We've got 15 offices around the world. We've always been very focused on starting in these markets with an investment investment grade credit approach, becoming very comfortable with the lending jurisdiction in the origination channels, understanding the opportunity set of the types of issuers that we see in those markets, honing the experience and the depth of our local investment teams. And then we simply start to go down balance sheet as I call it, in terms of risk. We find incrementally the next borrower that in this case may be sub investment grade, maybe financing an event that demands a non investment grade solution. Matt Harvey [00:11:40]: And we are able to access that. But again, many of the fundamentals are the Same we're focused on entry leverage, loan-to-enterprise value, cash flow coverage and having structures and documents where because we're trading liquidity in private credit, right. We don't have the ability to transact away from the issuer. Once we're in the deal, we have to work on a primary basis. We have to have strong covenants in terms protections and how you do that, that in any given market it is different in France than the United Kingdom, which is different than Germany and Australia. Right. That's where you have to have the localized presence, but the fundamentals of underwriting the credit first and then using the local jurisdiction to structure around it. That's where having the larger platform but with localized origination is very helpful. Chris Sparenberg [00:12:30]: It's very interesting you mentioned some of those jurisdictional nuances and it's an interesting way for us to pivot into a discussion around where these jurisdictions fit on the maturity continuum. You mentioned Europe is less mature in private capital compared to the US Australia is an emerging jurisdiction. How do you see these regional differences impacting your investment approach? And are there specific opportunities or challenges unique to these markets? Matt Harvey [00:12:54]: There certainly are and there are impacts. The first order impact, frankly, is aligning what we see as origination opportunity, investment opportunity with investor demand and investor capital. Because as you can imagine, if you're a US pension fund with a US dollar liability, you want to match that with the US dollar asset. And it's not the most natural thing to say, well, let's match that with an Australian dollar asset for a mid market direct lending loan in Australia. There are ways you can do that within portfolios. You can put on derivatives, you can hedge off the currency risk. You can do things that then we would argue, create good diversity for those investors in a suitable way to access those credits. But again, it's not a natural extension for the majority of capital. Matt Harvey [00:13:43]: So the first thing we have to do is identify the opportunity set, prove it out with enough investment capital that creates track record that's underwritable if you're an institutional investor and then go create the demand for it. Right. And that tends to be circular over time. But to your point, maturation is a key part of this because what's happened over the last 10 to 15 years is the U.S. in fact, especially for sponsored lending activities. So traditional direct lending is financing leveraged buyouts for private equity sponsors in the United States. Most managers would acknowledge that is a quite mature market. It is competitive whether you look at the lower end or the upper end. Matt Harvey [00:14:25]: Yet at the same time it's a deep market, there are many participants, there's a lot of transaction activity and many managers can carve out and create their own angles. If you go across that continuum, as you said in Europe, you really have to separate the UK from the continent. The UK was the first mover, it looks most like the US and it is reasonably mature, I would say in a pretty comparable way. Across the continent though, you see as you go from north to south and from west to east, you see less and less penetration. And I always take Germany as an example. Germany is the largest economy in Europe. Yet the reporting that I see would suggest it's the fourth largest issuer of direct lending among European countries. And that intuitively doesn't make a lot of sense. Matt Harvey [00:15:14]: Over time, the adoption curve in places like Germany and more broadly across the continent should be upward sloping. And that's what we see. Because what we see is the benefits of private credit being better understood and more available to European issuers, no different than they've been taking up by US and UK issuers over time. Australia is the, I would say the last port of call in the developed market. There are other markets that are of course changing when you look across Asia and so forth, but in the traditional developed market, and that's a market that's really grown over the last five or six years coming out of COVID principally where the dynamics of literally being an island economy but having a strong and thriving middle market again support a private credit alternative. If you can be local and compete alongside the Australian banks, putting investor capital around that again and how you do that in a global portfolio versus a dedicated geographic portfolio, that's really the trick. So what it will enable penetration in places like Australia and in fact across Europe, we'll be continuing to align investor capital and structures that can invest in those products with what we see as the origination opportunity. But we're quite bullish on that trend. Matt Harvey [00:16:29]: And the additional thing we haven't really talked about yet that sort of accelerates the market share penetration, if you will, of direct lending is again, we focus a lot on private equity sponsored activity generally for the direct lending asset class. But it's often reported that there are many multiples in terms of opportunity set of non sponsored issuers. And so again, if you can access these family owned privately held companies that are not entertaining private equity transactions, which is the majority of the issuer set, then that penetration curve only stands to increase over time. And that is fundamentally our strategy that we can access an increasing penetration curve in places like Europe and Australia. Continue to do that in the US because you can originate into both the sponsored and non sponsored markets. And again, that creates the symbiotic, beautiful cycle that I referenced of better selectivity, better underwriting, better information and all that ultimately in a more diversified portfolio that makes sense for investors. Jocelyn Lewis [00:17:32]: Appreciate that perspective, Matt. And as we think, think about how PGIM navigates regional nuances across Europe, the US and the emerging markets like Australia, it becomes clear that adapting to local market maturity is only one part of the equation. With another critical dimension being understanding how the investor base itself is changing. So shifting from geography to capital formation. And with the investor ecosystem evolving significantly, you have clients becoming more sophisticated and the growing inclusion of retail and private wealth channels. How is PGIM adapting its strategy to engage with these diverse investor groups? And what is the importance of investor education within this environment? Matt Harvey [00:18:34]: That's a great question. It underpins a lot of the thematic issues that surround direct lending and private credit today. I'll start with our perspective and really my perspective, I should say I've always felt we have great privilege at PGIM in that we are integrated fully into a permanent balance sheet, a very large life insurance company balance sheet that is a long term investor into assets that match their liabilities. And that gives you a perspective. In private credit that's really important. That starts with the idea of long term perspective. And in privates, finding relative value after illiquidity. It's a really simple but important concept. Matt Harvey [00:19:18]: And where I go to that very quickly then is as an investor, how do we find, manage structure, underwrite, et cetera, a asset that has illiquidity. And we are focused purely then first and foremost on the asset level return and dynamics. Right. If you have that as your sort of guiding principle, then what you have is you have the ability to produce scarce assets that produce interesting returns after illiquidity. And you should be able to avail that portfolio to other types of investors that may have similar objectives. And the objectives can come for different reasons. The average private wealth investor these days generally has the objective of I have a fixed income replacement opportunity in my portfolio. I'd like to seek higher dividend yields than is traditionally available in, let's say high yield or leverage loans or something like that. Matt Harvey [00:20:18]: And I can do that in a diversified pool of private credit assets. That's one opportunity. Another opportunity in investor segment is I may not want to be the equity owner of those returns, I. E. Make the whole loan myself. I may want bits and pieces of that. I may say I'm really comfortable with the top risk portion of that, I. E. Matt Harvey [00:20:39]: The safest piece of that loan. And increasingly in private credit like has been innovated many years ago in liquid credit, you can create structure out of these middle market CLOs, rated feeder notes, et cetera, et cetera, where certain investors can buy certain pieces of the risk reward of the underlying loan. As a pm, what it does is, and it's very welcome this way is it gives us more diversity and therefore with diversity in theory, more stability of capital to deploy. Because again, a lot of what we talked about in terms of the maturation opportunity to originate into comes from having the capital and aligning the capital to that opportunity. Right. So the more we can create diversity and stability and independence of capital to meet that origination opportunity, we see that as a win win for all parties, especially for the investors in the end. But secondarily, what you have to do to your point, and this is the risk in expanding this investment strategy outside of these traditional long term institutional allocators who buy the entirety of the loan, so to speak, it's the education. These are illiquid. Matt Harvey [00:21:51]: These assets will cycle similarly to any other asset. Just because it's private doesn't mean it doesn't have drawdown risk. It doesn't mean you have individual credit risk. You will have traditional asset class cycle risks. And investors need to really understand in the structure of these products, in our view, the best way to maximize that return opportunity, which we see again as relative value after illiquidity, is to understand the illiquidity dynamics, buy it for what it is and be able to hold that through a longer period of time. Right. And when you get into the various channels today, you know, the products are reasonably well structured. The tolerances of the investor really is what dictates the risk taking. Matt Harvey [00:22:41]: And that relies then on education on distribution teams that are in the marketplace speaking to the right investors and positioning the product the right way. And so that evolution is ongoing. But it's really important for the industry to get that right and to do it responsibly with a set of best practices that are suitable for the underlying investors, which the industry by and large is doing. And if you do that well, then what you're doing is you're delivering on this idea democratization of finance where all investors have access to the same types of products that traditionally were reserved for only the very large institutions. Chris Sparenberg [00:23:22]: I want to lead from that conversation on investors and their changing preferences and increasing sophistication into the market structure and what you might see is the enduring fundamentals in private credit. We're in a moment now where this asset class has experienced dramatic growth and with it very recently an increase in maybe the segmentation of specialized credit funds. How is PGIM navigating that complex and almost fragmented market structure to identify the most promising opportunities for clients? Matt Harvey [00:23:55]: Yep, it's, you know, it's a really important philosophical point for the managers to get right, ourselves included and by the way, in that there's no one size fits all. There's no single answer to this. But I'll explain how we approach it, which is a very productive approach for our investors because of that segmentation and the growth of the market over the last decade. Plus one of the biggest risks investors can take is strategy creep. Right? You start in an investment product that is meant to do one thing and because frankly the market evolves around it over time, it ends up doing something else. And that's where you see this classic segmentation opportunity. Again you take cash flow direct lending in sub investment grade. What started in a very constrained middle market format dealing with companies, you know, we use the same definition many do, under 50 million of EBITDA operating profit per year, under a billion dollars of revenue now has transferred across really the entire company set from public to private, up to, and in some cases actually now including large cap listed companies. Matt Harvey [00:25:05]: So it really is pervasive. But again, if your strategy as an investor, your idea of where you like value is to be in a quote unquote middle market direct lending strategy, you probably don't want to see your manager suddenly taking different forms of risk in a different part of that segment. Equally, cash flow lending is where private credit started. But now you have very large and prominent segments of the asset class that focus on things like infrastructure, credit, highways, toll roads, ports, et cetera, et cetera. You have of course this, this very large and growing, sometimes esoteric and hard to define asset based finance asset class ABF, where we're really first and foremost, you're financing pools of assets and you're again delivering ideally relative value to investors after illiquidity or with structuring capabilities and so forth. So, so those have all grown in popularity and they've grown in popularity because there is a market to originate those assets and provide value to the issuers away from the traditional capital markets or the banks. As a manager, again, the point is, and what we do that is we don't create all weather or all caps. We call it credit strategies generally, unless the investor really wants it in a very self Intentional way, self selecting way. Matt Harvey [00:26:30]: We can do that if that's what the investor wants. But when we organize the investment teams, we create teams that are very focused on one part of that segment and then can stand the best chance of delivering the best return and the best risk character in that single segment. And if investors want that single segment, they can, they can look at those segments as an investment opportunity on a standalone basis. And if rather they want to commingle or leverage the capabilities of the manager to do many different things within this broader private credit asset class, then those portfolios can be assembled. But again, it starts with the idea of underwriting relative value on at the specific part of the strategy that you focus on. In my case, that's middle market direct lending. And that gives us an area of an advantage, really of focus that allows us to do that very well. And the investors get to choose then where they want to place their exposure. Jocelyn Lewis [00:27:29]: Thank you for that, Matt. And as PGIM works through an increasingly segmented and specialized private credit landscape within the middle market, it raises an important point. So even as the market evolves and products become more complex, the foundational principles guiding sound underwriting haven't really changed. And you've noted that credit fundamentals remain the same despite assets being packaged differently today. And for those less familiar, could you explain, explain what these enduring credit fundamentals are indirect lending and why they remain so crucial to pre and why they remain so crucial to PGIM's approach? Matt Harvey [00:28:17]: Yeah, so this comes back to the segmentation. And so what I would argue are the crucial fundamentals of middle market cash flow. Direct lending may be a little bit different if you're running an ABS strategy or investing across different segments. But if we start with the idea of basic cash flow lending, which again, the banks have always done, and private credit provides an alternative to a bank structure for many different reasons, we really focus on the following. First and foremost, of course, you have to find companies that have reasons to exist, right? And not only reasons to exist, reasons to thrive over time. And as simple as that sounds, as you go down market in terms of risk and then you introduce balance sheet risk with, in the form of leverage, that is a more and more crucial thing to get right up front. You have to have a strong free cash flow profile and enough earnings visibility and revenue visibility and stability to service a more leveraged balance sheet. Right. Matt Harvey [00:29:22]: Very simply, sub investment grade, among other things, means you have higher leverage, you have higher debt service on these companies, there's a lot less room for error in terms of the operating model, year to year. So what does that mean? Well, first and foremost, we look at things like fixed charge coverage ratio. A company has to cover things like taxes, interest, expense, capital expenditures, et cetera, et cetera, every year, no matter what happens to their earnings generally. And so we want to make sure as we underwrite these credits that we're stress testing the ability for the company to service all those obligations without creating a default event on our loan or a liquidity event at the company level that compromises the value of the business and therefore the value of our asset, our loan. We also look, of course, to things like valuation and asset prices, but generally in cash flow direct lending, those are secondary and frankly, those can be illusory. And one recent example of that, of course, is there's a lot of well publicized stress or at the minimum, negative sentiment in software lending. Many years ago, software lending was done principally on the basis of recurring revenue multiples and very comforting levels of loan to enterprise value. Because the asset prices were inflating. Matt Harvey [00:30:47]: Software companies with SaaS models were viewed as very strong recurring earnings and revenue generators that could support high levels of leverage, even if in the short term the cash flow was not aligned with that. Well, companies cycle, all companies do, all sectors do. And over time you have to make sure you're not just relying on the asset price because the asset price can change. And that's just one recent example. So for us, it starts with cash flows. It starts with fundamentals of how the business evolves through stress cycles. You can't identify what those stress cycles always are, but you can stress test the operating models of the business in the event of cycles. And you want to make sure that in any case you have strong free cash flow coverage. Matt Harvey [00:31:34]: And in the case ultimately the event occurs at a given asset where that's broken or you have a default, that you have a strong ability to recover based on default. And that in large part then is dictated by the one thing we haven't talked a lot about today yet, which is covenants and terms. How quickly as a lender can you bring forward the event of default and the stress to allow you to exercise remedies and to protect the value of your loan before it's too late? And I would argue in middle market direct lending, the good managers and the good lender that rely on these fundamentals do a good job of structuring those protective mechanisms. So you have the chance, given default, of generating strong recoveries and eventually par back on the loans you've made. Even in the more stressed part of your portfolio. Chris Sparenberg [00:32:24]: So let's look through another lens at the market and that's the structured growth of middle market CLOs and the increased collaboration with banks. Against that backdrop, how does PGIM leverage these developments within the broader private credit ecosystem to enhance its investment strategies and even its sourcing capabilities? Matt Harvey [00:32:41]: That's a great question because I just want to say to start that oftentimes there's a little bit of a misplaced paranoia between banks and direct lenders on this sort of idea of an existential crisis almost and battle for superiority in these lending circles. And we simply do not see it that way. To your point, it is an ecosystem. We are very collaborative. We partner with banks all the time, we do it at the asset level and we're lending to companies. Oftentimes we provide long term capital, they provide short term capital. They have very attractive opportunities for agency and other service line of business that we do not pursue as an asset manager and vice versa. But to your point here, we also increasingly do it at the portfolio level when it comes to how we finance and service our own portfolio of credit and a big picture. Matt Harvey [00:33:34]: This idea of do you have more systemic risk in credit and the development of private credit comes back to the idea of what creates systemic risk and who are the natural owners of these assets. I would argue a bank lending to a diversified pool of direct lending leveraged loans, in effect at a loan, the value of those loans that is very well structured from a risk standpoint, let's say 50% loan to value of a pool of loans that for me as a manager I already think are well covered because they generally have 40 to 50% loan to value at the asset level. I would actually argue that's a deleveraging transaction for the banks and places those assets and those credit relationships into parts of the ecosystem the market more suited to own that risk. Just as an editorial to start noted the growth of middle market CLO and you could extend that to other forms of, I'll call it structured credit and financing around the direct lending market. It's the same case in the wealth market with BDCs and so forth. BDCs can be issuers of CLOs and fixed rate notes and so forth. And the banks are active in arranging those transactions. So it's a very attractive, growing and lucrative part of the investment banking model for many of those banks. Matt Harvey [00:34:55]: And depending on the lending dynamics and the structure, especially if you get to very high investment grade risk, as I said, if you can take the first out position against these diversified Pools of assets call that AAA or single a risk. Banks often own that risk. And it's very good spread lending for banks, right from a deposit standpoint and in how they manage their own lending books. So we see that as very collaborative, we see that as growing over time. And it's incumbent upon us then to work with banks that have the same perspective and view it as a partnership that we can again survey a growing need from the issuer market in alternative forms of capital and do it in a way that provides suitable leverage and efficient leverage into the system. It's the old idea of the money multiplier, right? If I raise a dollar of equity and I pair that with a dollar or two of bank debt, in this case, then I can provide $3 of solution to the issuer. And if you manage that risk properly, the equity owner of that risk, that is the long term institution, generates a very strong return on capital that they're comfortable with over time after illiquidity. And the lender to that risk, that is the bank in a diversified pool of loans gets very strong spread business that they can also generate fee business out of with the underlying managers. Matt Harvey [00:36:18]: That's a pretty symbiotic ecosystem and one that we continue to grow with our bank partners. Jocelyn Lewis [00:36:23]: It is important to understand that leverage plays a role and what role that plays. So appreciate you diving in a little bit there. And as PGIM taps into innovations like middle market CLOs and deepens your partnerships with banks to strengthen both sourcing and strategy, it naturally brings up another dimension of the firm's edge which is how the investment decisions get made themselves. And Matt, throughout your career you've chaired the investment committee at PGIM. And what are some of the key considerations or unique insights that guide your committee's decision making process, Especially given the nuances you mentioned within the mid market? Matt Harvey [00:37:16]: I would clarify. To start, I chair the Mid market direct lending investment committee. PGIM is a huge place with many great strategies and PMs and portfolios,. So I just wanted to clarify it said that there's no one IC. This gets back to the idea of investment committees that are assembled amongst professionals dedicated and experienced in their area of focus or asset class. And so using mid market direct lending as an example, it is a committee by definition. We have a global investment committee of nine individuals. These are all individuals that have 2030 years of private credit markets experience in the US and Europe and have a very well honed perspective on what it takes to produce attractive returns for our institutional investors and investors generally through Market cycles. Matt Harvey [00:38:06]: So in terms of the decision making process there, there's a lot to talk about here, but suffice to say the sort of starting point of the conversation around constant improvement, machine learning, et cetera, et cetera, I'm using those as euphemisms because the decision making process, if it's done well on the one hand, you balance consistency and discipline and you don't change that process just in reaction to a market development or a short term topic. That may be fleeting, but at the same time you have to evolve, of course, and you have to learn from opportunities, mistakes, experience, et cetera, et cetera, and apply that to your investment decisions. So what we do in private and in many ways this is fairly common across certainly the more experienced managers is on the front end of the origination model. One of the biggest risks we have is frankly opportunity costs. We have to talk to and consider many different transactions, meet many different companies to determine that reasonable cross section of it's an institutional investment grade worthy business with we can provide solution that actually that business also wants. Right? Because those two things have to happen together. We could love a company, but if they've got plenty of access to capital and we can't provide a solution that's unique in that way, it's going to be hard for us to transact and vice versa. Right. Matt Harvey [00:39:37]: So the first thing we do is we introduce mechanical process. We meet three times a week as an investment committee. We survey the origination pipelines that comes from our 50 deal teams around the world that are calling on companies and calling on sponsors every day. And the amount of data and information and the ability to triage that first stage of pipeline then becomes critical. We're trying to take 10 opportunities down to one or two very quickly and it's based on investment attractiveness crossed against our ability to provide a financing solution. If we can do that well then it's the classic 8020 rule. We could spend the vast majority of our time underwriting and focusing on and structuring the fundamentals of that particular transaction and ensuring then that we harmonize that with our investment strategy. And that's where it's really important. Matt Harvey [00:40:26]: In mid market credit we actually take an approach where investment committee sponsors we call it. And the reason why we have nine get assigned to the individual deal teams and they work with those deal teams to help underwrite, structure and manage the loan transactions. And it's not because our deal teams are not experienced and they need that level of management. It's actually the opposite. They are very Experienced, they're expert in their local markets at identifying an underwriting credit. But what we have to do then is we have to make sure the sort of conveyance of information and decision making between the portfolio decisions and what our investors want aligns then with that underlying transaction. And to do it competitively in marketplace to lend these scarce assets, we have to do that relatively efficiently. Right. Matt Harvey [00:41:17]: We can't dither, we can't take time and say, well, I'm not quite sure or you know, the loan market spreads are out 50 basis points today, so we're out of the market. Come back to me in two weeks. These are things that are not suitable answers to the types of businesses we finance, which are attractive businesses and have alternative capital sources. Right. So the idea is we spend all of our time on those handful of transactions that we think are relevant and are attractive and then we throw the full cavalry at it. It's the investment committee sponsor all the way down to the deal team. And it's the idea of both underwriting and really trying to create what we call information advantage and making that evident in the transaction that we structure with frankly the deal capture side of it. It is a competitive market and we've got to convince these companies that our capital solution and working with us as an institution is advantageous. Matt Harvey [00:42:11]: But again, a lot of it comes back to that initial mechanical process of surveying your origination opportunity set and very quickly honing in on those things that meet the fundamentals we talked about earlier and produce the types of returns that we think our investors are after. Chris Sparenberg [00:42:28]: That brings us to our last question we've covered market structure, PGIM's evolution, your view on the market and how you're executing this middle market strategy. I want to turn to the look ahead. So what do you see as the most significant trends or potential disruptions that'll shape private credit markets in the coming years? And how is PGIM and really how are you preparing to capitalize on or mitigate some of those factors? Matt Harvey [00:42:53]: I'm a big believer in the long term idea of adoption curve and more and more companies very simply having access to and understanding the benefits of non bank private credit or direct lending capital in this case. And that is a very simple idea and very simple trend. But we talked about that earlier in the call. Whether you take the U.S. europe or Australia, there are parts that are mature, but there are many parts that are still increasing penetration. Whether it's non sponsored lending or it's continental Europe, access to companies that otherwise wouldn't have considered private credit options in long term, that adoption curve will continue to slope up and to the right. And it's driven principally by the fundamentals of who and what types of institutions are best placed to own these assets versus not. We talked about the collaboration with the banks and where we have natural ability to provide a solution that banks tend to not whether it's regulatory or commercially and vice versa. Matt Harvey [00:43:57]: They're good at doing certain things that we're not and we can compel that into good solutions for companies. That's number one. Number two, the biggest trend will continue to frankly be despite the current scrutiny on this, the access and development of the private wealth in the retail market into private credit. There are many different forums and segments that go well beyond what we talked about today, investment grade credit, infrastructure credit, abf, that are also very suitable for that discussion. And I continue to think sub investment grade credit, no different than the reasons why individual investors have allocated to things like high yield and leverage loans in their portfolios over time, will continue to play a prominent role. The industry's got to get that right. And there are things that are very specific to that market in terms of daily valuations, regulatory and sort of good principles of transparency and portfolio construction, et cetera, et cetera, that are really important and those have to be then well understood by the buyer. But when you consider the size of the defined contribution market and generally the retail investment marketplace, that is a megatrend that will continue in a manager's who have the ability to navigate that in a way that is responsible, but at the same time deals with the other side of it, which is potentially more capital against a supply base that isn't in any one day always available. Matt Harvey [00:45:24]: Right. That's really the trick and that's going to continue to drive the dynamics of private credit for some time, irrespective of any one short term market cycle. Chris Sparenberg [00:45:33]: Thank you for joining us for this episode of Private Markets360. We were delighted to have Matt Harvey, global head of middle market direct lending at PGIM share his expertise with us. Matt provided valuable insights into the dynamic landscape of private credit, explaining PGIM's core philosophy and its evolution towards emphasizing sub investment grade opportunities. He highlighted the importance of their geographic allocation strategy, recognizing cultural nuances and the significance of a local approach in regions ranging from North America to emerging markets like Australia. Matt also shed light on the evolving investor ecosystem and the necessity of educating increasingly sophisticated clients, including those in the retail and private wealth channels. He underscored that while the market structure has grown and specialized credit fundamentals remain enduring. We hope you found this conversation as informative and engaging as we did. Be sure to subscribe to Private Markets360 for more expert insights and the latest trends in private investments. Chris Sparenberg [00:46:32]: Until next time, ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/blog/crude-oil/060426-maintaining-momentum-permian-methane-emissions-intensity-contracts-23-in-2025</link><description>Methane emissions intensity in the Permian Basin fell 23% in 2025 to 0.34% per barrel of oil equivalent produced from 0.44% in 2024, according to S&amp;amp;P Global Energy CERA analysis and Insight M data. Upstream methane intensity in the basin has sustained a downward trend since the inception of this dataset in 2022. </description><title>Maintaining momentum: Permian methane emissions intensity contracts 23% in 2025</title><pubDate>04 June 2026 16:01:16 GMT</pubDate><author><name>Solicia Xu</name></author><content><![CDATA[ Energy Transition, Natural Gas, Emissions June 04, 2026 Maintaining momentum: Permian methane emissions intensity contracts 23% in 2025 Solicia Xu Editor: Roma Arora Getting your Trinity Audio player ready... HIGHLIGHTS Permian methane intensity drops 23% to 0.34% Texas emissions exceed New Mexico by 56% Monthly flight coverage jumps to 22% in 2025 Methane emissions intensity in the Permian Basin fell 23% in 2025 to 0.34% per barrel of oil equivalent produced from 0.44% in 2024, according to S&amp;P Global Energy CERA analysis and Insight M data. Upstream methane intensity in the basin has sustained a downward trend since the inception of this dataset in 2022. From 2022 to 2025, basin-wide methane intensity declined by nearly two-thirds, reflecting continued improvement in upstream emissions performance. Four key trends emerged from the 2025 CERA analysis and Insight M data: Sustained intensity decline: Methane intensity continues a multiyear downward trajectory, with 2025 marking another step-change lower in basin-wide performance, consistent with CERA analysis. Stable activity context: The reduction occurred within a largely stable production environment and alongside expanded monitoring frequency, suggesting that the observed decline is not driven by reduced activity levels. Methodological evolution: Increased flight frequency and refined event duration assumptions have improved the temporal resolution and overall reliability of the 2025 dataset. Regional divergence: A persistent performance gap remains between states, with methane intensity in Texas (0.39%) materially higher than in New Mexico (0.25%), according to the latest Insight M data. Between 2024 and 2025, upstream methane emissions in the Permian fell from 38.9 million metric tons of COâ equivalent to 32.1 million mt -- a decline of about 6.8 million mt, according to CERA estimates. This corresponds to roughly 0.27 million mt of CH4, assuming a global warming potential of 25. For context, a 6.8 million mt reduction is comparable to about half the annual emissions of all data centers in Virginia, the country's largest data center hub, or to the annual emissions of roughly 1.5 million passenger vehicles. These estimates are focused exclusively on upstream operations. Methane emissions also occur across midstream, gathering and processing systems, but those emissions fall outside this assessment's scope. While this benchmark is primarily based on aerial survey data from CERA's partnership with Insight M, now part of Zietview, satellite-based observations from Sentinel 5P, ingested by CERA, provide an additional, independent view of methane emissions across the basin. Differences in detection thresholds, spatial coverage and temporal frequency across measurement technologies can result in variation between datasets. Those variations highlight both the progress being made and the measurement uncertainties that persist when quantifying methane emissions at scale. Improving accuracy with frequency While the 2025 headline numbers highlight continued reductions in methane emissions, substantial improvements in the dataset and notable methodological evolution are raising the reliability of the CERA Permian Upstream methane intensity estimate. Every methane detection technology has its advantages and drawbacks. The technology CERA used for the Permian benchmark -- aerial surveys -- benefits from a low detection threshold and sufficiently high resolution to attribute emissions to upstream, midstream or other sources. The Permian benchmark has consistently covered 88%+ of assets and production. In 2025, there was a significant increase in the frequency of overflights by Insight M, which underpins the CERA Permian benchmark. In 2023, only 0.62% of Permian production received monthly flyover observations. By 2025, this figure had risen to 22% of basin production. Furthermore, over two-thirds of assets were observed at least once per quarter. This means the assets producing more than 55% of total basin oil and gas production were observed at least quarterly, representing a marked improvement. Higher observation frequency also improves duration calculations, allowing for greater precision in timing both leak repairs and long-duration emitters. Insight M refined the event-duration methodology to improve temporal accuracy. In 2025, the default duration for detected leaks was halved from 14 to seven days, reflecting faster data processing and reporting cycles. After detection during a flight, operators are now notified within 24 hours, rather than the previous seven days, enabling more rapid repair responses. Furthermore, maintenance-related events are now assigned a fixed one-day duration, rather than being modeled as fugitive leaks, ensuring these short-lived, episodic activities are not overstated in annualized emissions estimates. Together, these updates improve temporal reliability and reduce the potential for duration-based error. As a result, the 2025 dataset represents a significant improvement and CERA's best available estimate of methane performance in the Permian to date. Dissecting the Texas-New Mexico methane performance gap A state-level comparison within the Permian Basin highlights a clear divergence in methane performance. Texas accounts for roughly 70% of total basin production and, therefore, most absolute methane emissions, based on S&amp;P Global Energy impact production data. However, the difference is not purely a matter of scale. In 2025, methane intensity in Texas was 0.39%, compared with 0.25% in New Mexico, indicating materially higher emissions per unit of output in Texas. Based on a review of regulatory frameworks, one potential driver of this divergence may be differences in regulatory structure. New Mexico has implemented more stringent methane controls in recent years, including tight restrictions on routine venting and flaring. In contrast, Texas maintains a comparatively flexible regulatory framework. Differences in enforcement, infrastructure alignment, and asset maturity may also contribute to the variation in intensity outcomes. For operators and investors, these results highlight the importance of state-level comparisons. Basin-wide averages can obscure jurisdictional differences that materially affect emissions performance. As regulatory and disclosure pressures evolve, understanding these structural differences will remain critical for asset evaluation and methane management strategies. Why these shifts matter The 2025 numbers tell a clear story -- when operators detect leaks sooner and fix them faster, emissions fall even when production stays flat. But the bigger shift is happening underneath the headline figure. Two years ago, less than 1% of Permian production was getting monthly aerial coverage. In 2025, that coverage has risen to 22%. This is not a minor adjustment -- it reflects a fundamentally different picture of basin-wide activity. The Texas-New Mexico gap drives this home. Two jurisdictions, same basin, same geology, yet methane intensity in Texas runs materially higher than in New Mexico. This difference is not about what's in the ground -- it points to regulatory choices and the degree to which operators are held accountable. As disclosure requirements tighten and investors increasingly scrutinize asset-level emissions, this is a signal that deserves close attention. Ultimately, better data is not just a technical gain. It's what makes the headline reductions credible --and what will sustain momentum toward further cuts. Further reading: Cleaning Up: Overflight data show Permian methane emissions intensity down further 28% in 2024 Turning the tide: Upstream Permian methane emissions drop 26% in 2023 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/energycents/060426-talking-trash-neogenyx-fuels-and-the-opportunity-to-scale-landfill-rng</link><description>Neogenyx Fuels launched in May 2026 as a 70/30 joint-venture project between Ameresco and HASI. The spin-off company is built with Ameresco&amp;apos;s legacy biofuels business and a $400 million capital commitment from HASI. Neogenyx CEO Mike Bakas joins hosts Hill Vaden and Sam Humphreys to discuss the evolution of Ameresco&amp;apos;s RNG business and how its partnership with HASI will help scale increased</description><title>Talking trash: Neogenyx Fuels and the opportunity to scale landfill RNG</title><pubDate>04 June 2026 11:21:51 GMT</pubDate><author><name>Samantha Humphreys</name><name>Hill Vaden</name></author><content><![CDATA[ Agriculture, Energy Transition, Natural Gas, Biofuels, Renewables June 04, 2026 Talking trash: Neogenyx Fuels and the opportunity to scale landfill RNG Featuring Samantha Humphreys and Hill Vaden HIGHLIGHTS Neogenyx launches as RNG joint venture Ameresco, HASI commit $400M to biofuels CEO discusses scaling green molecule output Neogenyx Fuels launched in May 2026 as a 70/30 joint-venture project between Ameresco and HASI. The spin-off company is built with Ameresco's legacy biofuels business and a $400 million capital commitment from HASI. Neogenyx CEO Mike Bakas joins hosts Hill Vaden and Sam Humphreys to discuss the evolution of Ameresco's RNG business and how its partnership with HASI will help scale increased production of green molecules. Learn more about Neogenyx Fuels at: https://neogenyxfuels.com Learn more about S&amp;P Global Energy coverage at: https://www.spglobal.com/energy/en Also on Apple Podcasts | Spotify 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/energycents/060426-talking-emissions-accounting-with-carbon-measures</link><description>Carbon Measures represents a coalition of businesses working to reduce emissions by establishing a more accurate carbon accounting framework. Carbon Measures CEO Amy Brachio joins hosts Hill Vaden and Sam Humphreys from the sidelines of CERAWeek to discuss how applying financial accounting principles to emissions measurement can help align performance standards and help businesses differentiate</description><title>Talking emissions accounting with Carbon Measures</title><pubDate>04 June 2026 11:06:54 GMT</pubDate><author><name>Samantha Humphreys</name><name>Hill Vaden</name></author><content><![CDATA[ Energy Transition, Carbon, Emissions June 04, 2026 Talking emissions accounting with Carbon Measures Featuring Samantha Humphreys and Hill Vaden HIGHLIGHTS Coalition works to improve carbon accounting Financial principles applied to emissions Businesses differentiate via performance data Carbon Measures represents a coalition of businesses working to reduce emissions by establishing a more accurate carbon accounting framework. Carbon Measures CEO Amy Brachio joins hosts Hill Vaden and Sam Humphreys from the sidelines of CERAWeek to discuss how applying financial accounting principles to emissions measurement can help align performance standards and help businesses differentiate their products. Learn more about Carbon Measures at: https://www.carbonmeasures.org/ Learn more about S&amp;P Global Energy coverage at: https://www.spglobal.com/energy/en Also on Apple Podcasts | Spotify 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-sustainable-finance-faq-how-transition-labels-can-help-reduce-emissions-in-hard-to-abate-sectors-s101689306</link><description>This report does not constitute a rating action. To evaluate decarbonization efforts beyond the green spectrum, S&amp;amp;P Global Ratings considers transition finance frameworks in its &amp;quot;Analytical Approach: Second Party Opinions,&amp;quot; which we revised on Jan. 29, 2026. The Loan Market Association&amp;apos;s (LMA&amp;apos;s), Asia Pacific Loan Market Association&amp;apos;s, and Loan Syndications and Trading Association&amp;apos;s joint Transition Loan Principles (TLPs) and the International Capital Market Association&amp;apos;s (ICMA&amp;apos;s) Climate Transi</description><title>Sustainability Insights: Sustainable Finance FAQ: How Transition Labels Can Help Reduce Emissions In Hard-To-Abate Sectors</title><pubDate>04 June 2026 07:47:14 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/shipping/060326-interview-trafigura-expands-owned-vlcc-fleet-for-less-exposure-to-time-charters</link><description>Trafigura is set to operate more VLCCs under its ownership in bids to meet growing transport demand while reducing exposure to period charter markets, where rates could stay elevated amid consolidation and evolving geopolitics, according to the trading house&amp;apos;s top shipping executive. Andrea Olivi, global head of shipping at Trafigura, told Platts, part of S&amp;amp;P Global Energy, that owning a certain</description><title>INTERVIEW: Trafigura expands owned VLCC fleet for less exposure to time charters</title><pubDate>03 June 2026 15:49:35 GMT</pubDate><author><name>Max Lin</name></author><content><![CDATA[ Crude Oil, Maritime &amp; Shipping, Refined Products, Fertilizers, Chemicals, Energy Transition, Wet Freight, Fuel Oil, Bunker Fuel, Renewables June 03, 2026 INTERVIEW: Trafigura expands owned VLCC fleet for less exposure to time charters By Max Lin Editor: Karla Sanchez Getting your Trinity Audio player ready... HIGHLIGHTS Trading house sees more third-party freight volumes High charter rates on consolidation, geopolitics Decarbonization needs to be 'financially viable': shipping head Trafigura is set to operate more VLCCs under its ownership in bids to meet growing transport demand while reducing exposure to period charter markets, where rates could stay elevated amid consolidation and evolving geopolitics, according to the trading house's top shipping executive. Andrea Olivi, global head of shipping at Trafigura, told Platts, part of S&amp;P Global Energy, that owning a certain portion of the company's fleet -- which grew to a record size of 500 ships recently -- would allow it to meet internal and external shipping requirements more cost-efficiently. "Trafigura's shipping volumes are increasing, but we're also noticing an even bigger increase in cargoes and contracts from third-party companies -- who realize that, thanks to our scale, we can offer unique advantages and economies of scale when it comes to freight," Olivi said in a recent interview. "This applies not only to oil but also dry, gas and, in a not-too-distant future, container freight forwarding." "We want to ensure that, going forward, we can continue to maintain a scale that allows us to service internal trading activity, alongside a growing number of external counterparties." The trader, one of the world's largest, reported a crude trade volume of 177.8 million metric tons in its fiscal year 2025 (October 2024-September 2025), up from 156.4 million mt in the prior year. A significant proportion of Trafigura's fleet transports are third-party cargoes, according to Olivi. The company operates a mix of deep-sea oil tankers, small tankers, LPG/LNG and dry bulk carriers. With more refineries, oil suppliers and receivers dredging ports worldwide to expand their berths to accommodate VLCCs, the shipping executive said this class of ships would be most capable of optimizing Trafigura's trade operations and reducing unit transport costs and emissions. "But we need to manage them, and we need to be able to optimize costs," Olivi said. "And the best way for us to ensure that is by owning our own tonnage." Trafigura refrained from detailing the size of its owned fleet. Information collected by Platts from industry sources -- including S&amp;P Global Maritime Intelligence Risk Suite -- suggests Trafigura might own over two dozens of ships of various types on the waters and order, and that its owned VLCCs in operation could grow from four to more than 10 later this decade if some optional newbuild orders are exercised. Segment dynamics Traditionally, Trafigura has been building its fleet by time-chartering vessels from shipowners. But term rates for tankers have been rising as many market participants expect spot earnings to remain high amid consolidation and geopolitics-led disruptions. Figures from shipbroker Banchero Costa show the one-year charter rate for a VLCC reached $100,000/d in April, up 134.2% year over year. Brokers have attributed strong term rates to defensive chartering by traders and oil majors, who seek guaranteed vessel supply amid high spot freight rates. The Platts VLCC index for non-scrubber-fitted, non-eco ships was $267,653/d on June 2, having stayed below $50,000/d for much of 2025 before recent spikes. In a research note published in May, S&amp;P Global Energy CERA said Sinokor has established a rate level of $50,000-$80,000/d for VLCC trades after taking control of roughly 30% of the non-sanctioned spot fleet. The South Korean carrier, which had jointly marketed VLCCs with Trafigura, has partnered with Mediterranean Shipping Co. and spent $3 billion acquiring mid-aged ships since 2025 to grow its operated VLCC fleet size to 100 ships based on CERA research. Many shipping professionals said VLCC consolidation could tighten vessel availability if a large share of the open fleet is controlled by a single owner, potentially driving up spot tanker rates for a sustained period. Market development Despite high secondhand prices, Trafigura could achieve healthy investment returns and enjoy strong cash flows for the coming years by owning VLCCs, as market participants expect more demand for non-sanctioned ships amid volatile geopolitics. In the past few years, mainstream tanker owners have been selling their aged ships to shadow fleet operators that use the shipping capacity to transport sanctioned barrels. But Venezuela has been exporting its oil on non-sanctioned ships following the US ouster of its former president, Nicolas Maduro, in January. Iran has taken control of the Strait of Hormuz -- which handles 20% of global oil and LNG trades in normal times -- since its war with Israel and the US broke out Feb. 28, limiting ship crossings via the choke point to 90% below the pre-war level. Tehran has been seeking to lift US sanctions on Iran's oil exports during its peace talks with Washington. Trafigura currently has seven chartered tankers stranded in the Persian Gulf. While the Strait of Hormuz crisis led to tanker rate spikes due to longer shipping distances as Asian importers sought Atlantic barrels, the executive warned a prolonged disruption could create "real problems" as reduced oil supplies could result in higher prices and lower consumption. Maritime decarbonization Among other shipping initiatives, Trafigura reduced the greenhouse gas emission intensity of its shipping operations by 25% from 2019 to the full year 2025, ahead of its target year of FY2030. The company is due to take delivery of four ammonia-fueled mid-sized carriers in 2028, while CMB.TECH -- which has ammonia-capable ships coming online -- recently expanded its bunker procurement deal with Trafigura subsidiary TFG Marine to cover its whole fleet. "We hope that ammonia as a green fuel can develop worldwide," Olivi said. "And then when we see the right demand signals from shipowners, we will want to increase our ammonia bunkering capacity." But Olivi said Trafigura's plan to decarbonize its bunker mix would be influenced by regulatory developments. The International Maritime Organization's Net-Zero Framework, originally designed to place a GHG cost on ship emissions from 2028, was not adopted last October as scheduled, and some member states are backing an alternative without a pricing mechanism. "It's important for us to decarbonize, but we have to do it in a way that is financially viable," Olivi 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/blog/energy-transition/060326-et-highlights-asia-pacific-hydrogen-carbon-prices-does-rector-uk-eu-ets</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: Asia-Pacific hydrogen hopes, US DOE negotiating with reactor developers, UK carbon prices rally</title><pubDate>02 June 2026 20:05:00 GMT</pubDate><author><name>Staff </name></author><content><![CDATA[ Energy Transition, Renewables, Emissions, Carbon June 3, 2026 ET Highlights: Asia-Pacific hydrogen hopes, US DOE negotiating with reactor developers, UK carbon prices rally 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 Asia-Pacific bets big on renewable hydrogen as deals, infrastructure, prices align Asia-Pacific could become a key driver in commercializing low-carbon hydrogen and its derivatives, as firm supply agreements, emerging infrastructure buildouts, and low production costs signal the regionâs ambition to anchor the future global clean fuel trade. The region hosts about 795 projects with a combined projected capacity of about 35.20 million metric tons/year, including renewable-derived and fossil fuel-based hydrogen with carbon capture, according to S&amp;P Global Energyâs Hydrogen Production Assets database. The Middle East conflict could accelerate a structural shift, with the transport, power, and industrial sectors increasingly pivoting toward renewables and low-carbon hydrogen -- a transition already beginning to take shape across the region, Nobuo Tanaka, chair of the steering committee of the Innovation for Cool Earth Forum and former executive director of the International Energy Agency, has said. âThe oil shock will certainly push Asian countries into the more energy-efficient model of economic growth,â Tanaka said. Benchmark of the Week GBP58.44/mtCO2e Platts UK carbon prices reached their highest since early February on May 29, on expectations of progress towards linking to the EU Emissions Trading System. Explore Platts Energy Transition Price Assessments Editor's Picks: Free and premium content SPGlobal.com Stockholm emerges as key buyer of removal credits with bioenergy carbon capture deal The city of Stockholm has emerged as the world's fifth-largest buyer of permanent carbon removal credits after signing a 15-year agreement with Stockholm Exergi for 50,000 mt/year, marking a significant expansion of the Swedish capital's climate strategy as it races to meet ambitious 2030 targets. The deal, signed through the city's group company, Stockholm Stadshus AB, will help offset hard-to-abate emissions from construction materials and wastewater treatment as Stockholm pursues its goal of becoming climate-positive by 2030 and fossil-fuel-free by 2040, the companies said May 26. US DOE negotiating with reactor developers to use surplus plutonium for fuel The US Department of Energy is engaged in negotiations with five advanced reactor developers for the possible provision of surplus plutonium from the country's weapons program, a spokesperson from the department's Office of Nuclear Energy said May 27. In April, the DOE "competitively selected five companies for advanced negotiations regarding the potential allocation of surplus plutonium materials," the spokesperson said. S&amp;P Global Energy Core UK carbon prices rally as EU ETS linkage hopes grow ahead of summer summit UK carbon prices climbed to three-and-a-half-month highs as market participants anticipate a UK-EU July summit that could yield an agreement to link their emissions trading systems, according to industry sources and government officials. The UK government confirmed it is negotiating an emissions trading deal with the EU, which will be one of the key focus areas at the upcoming UK-EU summit. Keppel starts hydrogen-compatible CCGT power plant in Singapore Keppel has started commercial operations at the 600-MW hydrogen-compatible combined cycle Keppel Sakra Cogen Plant, expanding Singapore's scope for using low-carbon fuels to generate power, the company said. KSC increases Keppelâs power capacity by about 45% amid growing demand for reliable, future-ready power infrastructure, as the focus shifts to energy security and resilience, it said. New York budget legislation delays climate deadlines, shifts emissions reporting After several delays, New York lawmakers advanced a budget bill for fiscal year 2026-27 that rolls back several provisions of the state's landmark 2019 climate law. Under the new regulations, the state will have until Dec. 31, 2028, to implement necessary policies and regulations, such as a cap-and-invest program. ]]></content></item><item><link>https://www.spglobal.com/en/research-insights/podcasts/leaders/how-private-credit-took-over-wall-street</link><description>This episode features Blair Jacobson, Co-President of Ares Management Corporation, discussing private credit investment strategies, risk management, and firm growth. He shares insights on how Ares maintains a conservative approach to avoid losses, the importance of relationships and reputation in deal origination, and the firmâ&amp;#x80;&amp;#x99;s expanding areas like asset-backed credit and wealth management. Blair also touches on the evolving role of credit ratings in private markets, the firmâ&amp;#x80;&amp;#x99;s involvement </description><title>How Private Credit Took Over Wall Street</title><pubDate>02 June 2026 13:30:00 GMT</pubDate><author><name>Joseph Cass</name></author><content><![CDATA[ Leaders 2 June 2026 How Private Credit Took Over Wall Street By Joseph Cass This episode features Blair Jacobson, Co-President of Ares Management Corporation, discussing private credit investment strategies, risk management, and firm growth. He shares insights on how Ares maintains a conservative approach to avoid losses, the importance of relationships and reputation in deal origination, and the firmâs expanding areas like asset-backed credit and wealth management. Blair also touches on the evolving role of credit ratings in private markets, the firmâs involvement in sports investments, and offers advice for young professionals entering finance amidst technological disruption. Chapters 00:00 What could go wrong in private credit 1:34 How prepared is Ares for a downturn 6:55 Football &amp; sports investment â Chelsea &amp; Athletico Madrid 10:17 Finding sports investment opportunities 10:58 How does Ares find new business 14:57 Finding lucrative deals 16:07 Private credit ratings 18:56 Big insurers moving into private credit 20:13 Building a career in the AI era 22:13 âRelationship trainingâ 24:00 Why is Ares Co-Founder Michael Arougheti so successful Subscribe On: Apple | Spotify | YouTube View Full Transcript Blair Jacobson: [00:00:00] When people ask me what the goal is of a firm like Ares in private credit, it's a very simple sentence: don't lose money. To go back to football, it's a very, very powerful business model. I grew up on Wall Street 30-some-odd years ago, but I have some unique insight into this. We have the CEO and CFOs of our companies on speed dial. How did we do it? Joe Cass: If something goes badly wrong in private credit over the next, say, twelve months, what do you think could be the trigger? Blair Jacobson: We don't see any signs today in the portfolios of issues. Uh, a couple weeks ago, we reported publicly that our BDC in the US, which has over six hundred companies in it, was doing quite well. Companies are growing their profits in the double digits. Credit statistics are trending the right way. So I think we're starting from a good place. The second thing would be that remember, for [00:01:00] something to happen to credit or private credits, certainly equity is the first loss. So a lot's gotta go wrong before private credit gets impacted. I think the third thing would be last year we had Liberation Day, which wasn't fully anticipated in advance. We, we got through that, uh, okay. So I'd say a lot would actually have to go wrong before private credit is massively impacted. Joe Cass: Financial crashes or, you know, recession, they are inevitable. They come, they're cyclical. At some point, it's gonna happen. How well prepared do you think Ares is, and how well are you prepared your portfolios to withstand something like this? Blair Jacobson: It's, it's a great question. When people ask me what the goal is of a firm like Ares in private credit, it's a very simple sentence: don't lose money. And that needs to be battle tested over time through a very, very specific investment strategy. So the way we do it actually starts even before we have a deal. [00:02:00] Um, we have something like a hundred people in Europe, just to give an, an example, seven offices. We talk to one thousand five hundred companies in Europe every year, and we make new loans and investments into thirty, forty, fifty of those. So we're very, very selective in terms of what we do, and we say, "Oh, you're selective, but why? What are you looking for?" Well, we're looking for companies that are leaders in their niche, that are growing well, but importantly, we have seen before through the GFC, through COVID, through shocks like Brexit or high interest rates, inflation, all these things, what companies did well. Uh, so we can actually look at their track record to make that determination. That tends to guide us to certain industries, business services, healthcare, telecommunications, et cetera. So I'd say we have a pretty good filter that helps us stay out of trouble even before things start. Then when you look at the types of loans we make, 80, [00:03:00] 90% plus first lien senior secured. So if anything goes wrong, we're first in line to get our capital back. Again, it's sensible loan to value. You know, the long-term loan to value in our space going back ten, 20 years is probably 50%, maybe even higher. However, we're currently in a space where we're more like forty or forty-five percent. So again, a lot of equity underneath our loans. Aries has a team of twenty-five people in Europe and fifty in the US that monitor our companies very closely. It's their sole job. And one of the great things about private credit is we get numbers from our companies on a monthly basis. So it's, you know, in the public markets, it's maybe every three or six months, and there's a delay. We have the CEO and CFOs of our companies on speed dial because we tend to be either the only lender to the business or a meaningful lender. And again, time is a real advantage if you can spot issues early and get out ahead of them. And I think the last thing I would [00:04:00] say is we have dedicated restructuring experts, you know, people who've spent their lives in this space getting our money back. And what that means, again, if, if a company's bought for, say, Â£100, and that would mean that our loan would be, say, forty-five, that means the value of the business has to deteriorate by 55% and stay there for us to lose Â£1. Not to say it never happens, but the math is a challenge. So our view, by the way, is if there's an issue, we don't have to get the company back to Â£100 of value. We just have to cover our loan. If you look at our long-term track record in Europe, twenty years, US even longer, twenty-five plus years, our loss rates are like either negligible, one or two, three, four basis points. And I think a lot of that is based on this model that I've just described to you Joe Cass: How big is the Aries business today, and what areas of the business do you think will grow the fastest over the next few years? Blair Jacobson: So we just announced a few weeks ago that we're now roughly six hundred and twenty-five billion [00:05:00] dollars of assets under management. The growth, you're right, thanks for noting it, has been significant over the past few years. As you'll know, we're organized around credit. That's probably sixty, seventy percent of what we do. We also have real assets. That's real estate, infrastructure, and digital. Uh, we have a secondaries business. We have private equity business. So we do a bunch of different things. Well, one area within our credit department that's growing meaningfully is our asset-backed business, which we call alternative credits. The TAM for what they address is massive, and what we're now seeing is that companies are very comfortable using private credit and private lenders. That has now developed into an asset-backed opportunity. So that's everything from consumer mortgage loan books. It can be healthcare receivables. It can be music royalties. It can be NAV loans. Just so many different underlying areas to target. That is growing massive. About a fifty billion business for us.[00:06:00] That's also where we house our investment-grade origination business, which is serving insurance clients. So again, lots of growth levers even within our credit business. And the last thing is wealth We were not in wealth, again, four or five years ago. We're now a top three player in the US. We think we're the largest, uh, here in Europe as well. We really believe in the democratization of our assets. Frankly, m-many own these assets through defined contribution, uh, pension plans anyway, so for them to be able to access it on a high net worth basis or ultimately in the US, for example, through 401, that provides a real growth path. And again, just to frame it for you, um, wealth is now a $66 billion business for us. We're raising four to five billion a quarter. We're seeing that expand now globally, started in the US, then Europe, then Asia. So I'd say those are a couple of growth levers, uh, for the firm. Joe Cass: Anyone who visits this podcast will know that I support West Ham. Blair Jacobson: Interesting. Joe Cass: Th- through, through, for [00:07:00] better or worse at the moment. But I'm interested to know around kind of the sports sector- Blair Jacobson: Bowen's a great striker, you know, Joe Cass: He is. That's, that's probably all we can say. But like, in terms of, you know, football or soccer- Sure ... specifically, I know Aries have been involved with, you know, really, you know, Atletico Madrid- Mm Chelsea. What's the appeal there? Blair Jacobson: Sure. Joe Cass: Um, and, and what really is interesting for you? Blair Jacobson: Sure. Well, let me, let me take a step back and just give you the origin story a little bit. This started for the firm as a bit of a passion project in that many of us, similar to you, we are sports enthusiasts. Sometimes we'll have investments in sports businesses, et cetera, but sort of part of the ethos and DNA of the firm and, and we've done things periodically, you know, going back, you know, sometimes over, over a decade in the space. But what changed was around COVID. What you saw was these wonderful sports teams, and I'll talk to you in a little bit, uh, about what we like. Um, the live ticket attendance revenue [00:08:00] literally fell to zero, and our view was a lot of them needed help to survive what we believe was going to be a temporary cash issue. And due to our personal relationships, again, this is a relationship business at the end of the day, um, we were first call for a lot of these really exciting, whether it's teams, leagues, et cetera, that needed some, some support. So that's actually how this turned into, uh, a business for Ares. We now have multiple funds and products. We have a large investment team. Again, it's not only teams and leagues, it's data, it's ticketing. We also do, uh, media and entertainment, uh, associates. So it's actually quite a broad, uh, mandate for us as a firm. But to go back to football, and again, I've lived in the UK for 21 years, so for me, football is soccer, not American football, uh, at this point. Um, it's a very, very powerful business model. When you look at the revenue that's generated through long-term sticky media [00:09:00] contracts, it's meaningful. And in particular, if you're looking at the Premier League and you're not a team that has a, a chance of being relegated towards the bottom, you have consistency, you have Champions League revenue. It's powerful. You've got, uh, ticketing revenue, which I've mentioned before. You've got, you know, merchandise and branding and all these things. It's, it's a very, very powerful business model where you also have fans like yourself who've been following these teams and are very loyal through thick and thin. Uh, I'm an Arsenal fan, and it's been a, a challenging 20 years for me. Maybe this is our, our year at the end of the day. But overall, we think that these are quite good businesses. And again, our strategy at Ares has been more around flexible capital. And, you know, overall it's, it's worked out very, very well. I also sit on that investment committee, so it's always fun to double-click, uh, on the documents when they come across 'cause you never know what logo, uh, you're going to see. But again, overall, these are quite valuable assets, which historically had really been the grounds for wealthy [00:10:00] individuals or maybe benefits of league securitizations. But now that's really opened up, and, you know, there, there are a couple players that do it, but there are real entry barriers, I think, in particular due to relationships and experience in the space where Ares is a, is a leader. Joe Cass: It's interesting you say it's kind of a relationship business, and I guess in the COVID times, were you receiving calls from clubs or leagues kind of inbounds? Blair Jacobson: It was both. Okay. Um, and again, both in the US, um, and in, in Europe. But again, their, uh, P&amp;Ls or cash flow statements, you know, were, were quite stressed- Yeah ... when they just couldn't hold these, hold these matches. Even sometimes they did, there weren't people in the, in the stands, you'll remember. Um, so we actually generated, um, our own loyalty through supporting them through tough times, and I think Ares also developed a reputation as a value-added partner, which serves us today, you know, many years later. Joe Cass: If I think [00:11:00] about the Ares business kind of at high level. Obviously you need to, you need to kind of en- ensure that there's investment return for your clients. That's number one, I guess. But a big part of the business must be the origination, kind of new business coming in the door. So- Well, how do these deals kind of end up on your desk? You mentioned you've got kind of an origination team who are obviously going out there. Are they kind of just developing these relationships so that at some point through the year they'll have a tap on the shoulder? Is it-- How, how does that work? Blair Jacobson: In particular, Ares has invested a lot in what we call origination. And for the listeners, origination is a fancy name for finding deals. Joe Cass: Yeah. Blair Jacobson: It's sort of that simple. Um, in Europe, we have over a hundred people in seven offices. Uh, in the US, we have over two hundred people. So again, that enables us to talk to thousands and thousands of companies every year. But if I had to, um, you know, pin it down in a couple of key takeaways, I think the [00:12:00] first is reputation. We've been doing this for twenty years in Europe. We've been doing it for even longer in the US. You know, we are known as a well-capitalized good partner for companies and their stakeholders to help them grow and reach their ambitions. So when you, when you have that market reputation, sometimes things find you. But that's nothing to rest on your laurels, 'cause the second piece, this is where you were going, is people. And it actually goes to even before they joined Ares. Let me give you an example. Um, when we entered the European market in two thousand and seven, how did we do it? We lifted a team out of Barclays Bank, which was the number one mid-market commercial bank in the UK. So with that team, essentially what they said was, "Hi, company or owner of company, you've been dealing with me for a decade or two at Barclays. Now I'm at Ares. Same guy, different business card, [00:13:00] but the product offer that I can bring you is so much broader. The hold size is more. The process is gonna be much more transparent to you and quicker. We can offer all of these advantages." So actually it starts with hiring people who've been doing leverage finance their entire careers and have really good reputations in markets. That's also how we entered the French market, the German market, the Nordics, um, then Benelux, then Spain, now Italy, uh, just last year. And the third thing is after you have those relationships, you start building up a real track record. And again, we've probably transacted with four hundred plus companies, uh, in Europe, by the way, with a hundred plus different owners that we've done multiple things with. But the really powerful part of our business is what we call incumbency. What incumbency is, again, that's another fancy name, but what it means is we have an installed base today of hundreds of companies that are growing. I mentioned earlier when we talk about screening [00:14:00] businesses, we want businesses with real organic growth potential. And when we find these companies, we wanna continue to lend to them for as long as possible. What that means is in the UK, for example, we have a veterinary care business. We found it when it had like three, four, five million pounds of profit or EBITDA. Now it's like a hundred and fifty, two hundred million. So we've backed it the whole time. Again, our companies are always growing. They want growth capital, they want acquisition capital, they want capital to refinance, or maybe they're being acquired by a new owner, and we want the management team to say, "I've had a great experience with Ares. I wanna continue with them." So incumbency is, again, another really powerful entry barrier because we know the companies the best. By the way, it's once we decide we wanna keep backing, sometimes you know it and you don't wanna continue backing it too. Uh, but by and large, again, staying with our businesses through incumbency is probably the third most important part about that origination effort. Joe Cass: And in the origination kind of process, just [00:15:00] interested personally, are you, are you going direct to companies? Are you being handed deals from kind of intermediaries? How does that split kind of usually look? Do you work direct- Sure ... or do you do both? Blair Jacobson: So honest answer is both. The, the core of direct lending is just that. Joe Cass: Yeah. Blair Jacobson: It's direct. Um, we are capable, uh, of doing diligence, underwriting, legal doc, all, all these things ourselves. So again, you know, we, we, we cut out the middleman, so to speak. That being said, you know, companies often have advisors, which is fine, so that they can make the right decisions for themselves. So it is also important for us to have relationships with legal advisors, accounting advisors, deal advisors, M&amp;A advisors, again, to make sure that we're maximizing our deal flow and opportunities. I'd say we're like a little bit agnostic. We do go both ways, but what we don't do is have a situation where a deal is, say, underwritten by a bank, they're long some [00:16:00] exposure, then they wanna sell it off. That we, we don't do because again, it is our goal to do all of that directly as much as possible. Joe Cass: Yeah. Makes sense. Rating agencies within kind of private market space, they've been in the press over the past year. So what's your view of credit ratings in the private markets and particularly in private credit? Blair Jacobson: I love doing this on an S&amp;P- ... uh, podcast, so, um, uh, I appreciate the question- ... put it, put it that way. Um, here's how I frame it. There, there certainly is a role. When you think about the origin of rating agencies and what they're meant to do, you know, they are meant to look at a company's r- return characteristics and risk characteristics, and tends to be for larger companies that are liquid to give underlying investors some sense and comfort around what they're buying, in particular in areas where, again, they don't wanna make mistakes, whether it's IG or high yield or, or loans. Now, the [00:17:00] private universe is a little bit different from that. Um, and going back to what I was maybe saying a little bit earlier, um, we find our own loans, we do our own due diligence, um, we tend to be the largest owner of our loans, and they're certainly illiquid. So again, in a way, we sort of do a lot of that work up front, and also that's what our investors expect us to do. That being said, I would say in the last few years, we have seen ratings become relevant, in particular to our clients. So for example, what I said earlier on insurance companies. Obviously, insurance companies face rating agencies, um, because again, they have significant fiduciary responsibilities to their policyholders. So when we book investments on either insurance company client balance sheets or for their benefit, there are often ratings associated, uh, with those investments that need to be looked at. Second area are banking partners. Um, as you may know, we, we [00:18:00] tend to use credit facilities, uh, for our funds. Again, investors can choose whether they'd like to take advantage of that or not. And those banks often want some kind of rating to make themselves, um, very confident, uh, in what they're taking risk exposures on. Again, that's also required from a banking perspective. The third thing, and this is a little bit newer, um, rating agencies have long been affiliated with the CLO industry that backs liquid credits. We've now seen, and we think we've been a leader in this, uh, private CLO markets develop, again, first in the U.S., now in Europe. And again, when you start creating a mid-market CLO and you think about tranching it up, having rating agencies involved there is obviously quite useful to the end buyers, uh, of those securities. So overall, I think that there, there is a role, but it might be a little bit different than what is traditionally thought of, uh, as rating agency roles in, in the broader credit space. Joe Cass: Do you think those guys, the, you know, the asset owners, the insurers [00:19:00] particularly, do you think they're kind of culturally a bit more open to, to dealing with someone like Aries than maybe they were in the past? Blair Jacobson: I think they absolutely are. Again, when they look at, um, how the liabilities are forming and then what assets they need to hold against it to meet their own return on equity objectives, I would say that the alternatives portion of their balance sheet, 5 or 10% maybe, 'cause again, they do have to run relatively conservative investment books. But we're also able to do is create investment grade, uh, investment opportunities for them that work for the rest of their book. And I think this is what's really exciting for them, 'cause again, what we're able to do is create IG-rated investment opportunities that tend to have a slight return premium to what might be available in the liquid IG universe. Because again, we're self-originating these investments, we're structuring them [00:20:00] ourselves to sort of create a little bit of premium and alpha versus what they might like to buy. So to answer your question, yes. Um, I've, I had a conversation yesterday with an insurance company CIO. It's a big part of what we're focused on as a firm. Joe Cass: There's a bunch of young people who watch. You know, when I say young, I mean kind of, you know, graduates- Blair Jacobson: Right ... Joe Cass: who, who watch and listen to, to the show. If you were a young person coming into the world of work right now, with the disruption we have with potential AI, GenAI, LLMs, et cetera, and this is, you know, only the beginning, what kind of advice would you give them- Blair Jacobson: Sure Joe Cass: to kind of carve their way and, and create a career? Blair Jacobson: I'm still optimistic about young talent entering our industry and having very, very productive careers. Their day-to-day jobs might be a little bit different, but, you know, what we're looking for are people who, um, you know, are quite bright and creative and are systematic thinkers. They can form relationships with people and counterparties. That's one thing that I think will never be, uh, disintermediated. [00:21:00] Now, I grew up on Wall Street 30-some odd years ago punching in numbers. Maybe those days are a little bit, uh, behind us. So I think, I think the key question that we need to figure out is what is the best way to train the next generation So that they can come and do Blair Jacobson's job, uh, someday in the future when we do know that the time they'll be spending slaving over models and the like, um, might be a little bit less than what's happened, uh, historically. I think that's kind of the key question to figure out. That being said, you know, when I was young on Wall Street, we used to print out public filings and circle numbers and put them into spreadsheets, but that's been done by, say, FactSet or other providers for a long time. And, and despite that, we still have incredibly smart financial analysts on the team. So I do feel like we will find ways to continue to adapt. However, some of these real analytical skills and soft skills will become even more important. And [00:22:00] again, if you're young in the industry, maybe your, your days will be more efficient, but you need to make sure that you are having the right takeaways, the right analytics to make the right investment recommendations, uh, within your firm. Joe Cass: It's interesting. I always think about this kind of-- I've been thinking about this recently around, you know, historically, if you go, you're edu- you get some form of education, it's typically around, you know, a body of work or a content that you're studying- Mm ... whether that's, you know, politics or classics, whatever it might be, or maths. So if you, uh, commoditize that to some extent, let's say. I mean, personally, when I was, you know, coming through the industry, there wasn't that much relationship training. Blair Jacobson: Sure. Joe Cass: There was maybe something on the side about building relationships. You need to make-- Also, by the way, you need to make sure you build relationships. But I do wonder if the future will be more kind of relationship, relationship training driven, especially for these young graduates. Blair Jacobson: Yeah, I'd make two comments. So, uh, similarly, uh, I'm still a big believer in education liberal arts. Um, I double majored in political science, economics. I minored [00:23:00] actually in art history, and here I am, uh, with an investment job. Um, but I think what that enabled me to do was to think more broadly, more critically, um, and really, really adapt. So I think being taught how to think as opposed to what to think will become even more important. And the second piece where you were going is the EQ side of that equation, the soft skills side, I think has to become more important. And in some ways, you know, is that born or taught? It's probably a bit, uh, a mixture of both. But what we found is it's not easy. So as we have staff that sort of migrate from junior level to mid-level to more senior level, your job changes. At a junior level, you're really crunching, you know, you're analyzing. At a mid-level, it's more process management, whereas at a senior level, it is more external, and not everyone [00:24:00] is, is capable of making those jumps. So do I foresee more, uh, training in that regard over time as that becomes even more important? Yeah, I do. I would agree with you there. Joe Cass: So I think it was about two years ago, I had Mike Arougheti, the co-founder of Ares. He joined the podcast virtually, um, which was great. It was great. You know, it was a very good conversation. You know, you've worked with Mike for many years. Blair Jacobson: Mm. Joe Cass: Why do you think he's been so successful? Blair Jacobson: Um, so Joe, you may know I have some unique insight into this because not only have I worked with Mike for nearly 15 years at Ares, I first met Mike 32 years ago, uh, in my first job out of undergraduate. And actually, let me, let me pick up on a theme we were just talking about. When I joined, um, and again, maybe this makes some of the younger listeners feel better, I didn't know that much about finance, and I think at that time, Wall Street was taking more of a three, four, five-year bet on graduates like myself, less, you know, what we would do in the first year or [00:25:00] two. And Mike was in my merger and acquisition team. He was a year ahead of me, sort of spotted me. Uh, he became a mentor early on and really helped me scale that very steep curve, uh, at the beginning of my career. And what I would tell you is even then you could tell he was, uh, a special guy. And I think Mike, and you know, maybe he'll, he'll listen to this, I think he embodies four really important characteristics that are rare, that you find all in one person, which are, number one, his IQ off the charts, incredibly bright individual. And again, we spend our days with top decile people. He's like top decile of top decile. The second thing is his EQ. His ability to relate to people on a human level, uh, is incredibly strong. The third thing is his bandwidth. Obviously very hardworking, but he can dive deep into an individual investment, zoom out, talk about things going on at our company and everything in the middle. And the fourth thing, he's just a, [00:26:00] a good guy. Um, and it is, it is rare, I think, in our business for me to be able to call my boss one of my really good friends in life. And I think culturally at Ares, one of the things we've done well is have people who have known each other a long time get along because again, maintaining culture in a company that now is over four thousand two hundred people in fifty-five offices, it's gotta come from the top. So I think it's a really special advantage that we have that really benefits the entire business. Joe Cass: Blair, it's been a pleasure. Thank you so much for joining me today. Blair Jacobson: Thanks for having me, Joe. Uh, it was great fun. ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/credit-trends-african-corporates-rating-evolution-diverse-drivers-s101673349</link><description>This report does not constitute a rating action. Rated African corporate issuers span diverse economic sectors, jurisdictional exposures, and rating levels. For analytical purposes, S&amp;amp;P Global Ratings considers issuers to be African if they are either headquartered in an African country, or if they source at least 50% of their earnings from operations in Africa. This definition captures issuers whose credit profiles are subject to African economic, regulatory, and sovereign risk dynamics, regard</description><title>Credit Trends: African Corporates&amp;apos; Rating Evolution: Diverse Drivers</title><pubDate>01 June 2026 14:01:52 GMT</pubDate></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/sector-review-defense-sector-outlook-revisions-reflect-improved-prospects-s101688425</link><description>This report does not constitute a rating action. S&amp;amp;P Global Ratings recently revised the outlooks on four large investment-grade U.S. defense companies to positive from stable. The actions reflect our view of strength in broader defense and commercial aerospace industry demand as well as company-specific factors that we believe could support sustained improvement in credit measures. Defense contractor rating actions Company Previous Current General Dynamics Corp. A/Stable/A-1 A/Positive/A-1 Lock</description><title>Sector Review: Defense Sector Outlook Revisions Reflect Improved Prospects</title><pubDate>29 May 2026 13:45:49 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/refined-products/052926-interview-idemitsu-to-bolster-refining-pursue-lng-commits-to-hydrogen-saf-president</link><description>Japan&amp;apos;s Idemitsu Kosan aims to rebalance its business portfolio over the next five years, bolstering its foundation refining business and pursuing new LNG and North American gas trading businesses, while remaining committed to shaping its hydrogen, ammonia and SAF businesses, President Noriaki Sakai told Platts, part of S&amp;amp;P Global Energy, May 29. &amp;quot;Various initiatives are underway, but to put it</description><title>INTERVIEW: Idemitsu to bolster refining, pursue LNG; commits to hydrogen, SAF: president</title><pubDate>29 May 2026 12:59:20 GMT</pubDate><author><name>Takeo Kumagai</name><name>Akihiro Gotoda</name></author><content><![CDATA[ Fertilizers, Chemicals, Energy Transition, LNG, Natural Gas, Crude Oil, Refined Products, Renewables, Hydrogen, Fuel Oil, Jet Fuel May 29, 2026 INTERVIEW: Idemitsu to bolster refining, pursue LNG; commits to hydrogen, SAF: president By Takeo Kumagai and Akihiro Gotoda Editor: James Leech Getting your Trinity Audio player ready... HIGHLIGHTS Company to mull whether to renew refining units Secures year-ago level alternative crude for June Looks to build SAF plants, ammonia terminal Japan's Idemitsu Kosan aims to rebalance its business portfolio over the next five years, bolstering its foundation refining business and pursuing new LNG and North American gas trading businesses, while remaining committed to shaping its hydrogen, ammonia and SAF businesses, President Noriaki Sakai told Platts, part of S&amp;P Global Energy, May 29. "Various initiatives are underway, but to put it simply, the most important aspect for us is that we are in the equipment industry. We have multiple production sites, each with equipment that needs to operate stably," Sakai said in an interview at the company's head office in Tokyo. The plan for the period through to the end of fiscal year 2030-31 (April-March) follows a series of unplanned outages at Idemitsu's refining units in FY 2023-24 and FY 2024-25, resulting in significant losses, he said. "This depends on how the numbers are interpreted, but I personally recognize this very strongly and am returning to the basics: that stable operation of equipment is crucial for reliably increasing profits," Sakai said, adding that the company -- Japan's second-largest refiner -- has earmarked Yen 1.8 trillion ($11.3 billion) investment, the bulk of which is to be spent on ensuring stable operations in the next five years. Asked about types of investment, Sakai said: "There are a variety of them. One is investment related to maintenance -- ordinary, routine maintenance, for example. Then, beyond maintenance itself, if necessary, we would also renew equipment or replace existing units with new ones." To ensure stable operations, Sakai said the company also needs to introduce digital transformation initiatives and new technologies, including AI, amid a serious labor shortage. Through its efforts to ensure stable operations, Idemitsu aims to improve its average refining operation rates to 90% by the end of FY 2030-31 from an average of 86% in the last three years to FY 2025-26, he said. In the face of the Strait of Hormuz disruptions amid the Middle East conflict, Idemitsu recognizes the need to consider whether to require investment in its refineries -- which are configured to process Middle Eastern crude oil -- to install new units, or make modifications to existing units to process different types of crude oil other than Middle Eastern barrels in the mid-to-long term, Sakai said. Asked whether Idemitsu sees the need of reducing Middle East crude dependency, Sakai said: "Yes, I think that's the general direction of the discussion. The fact is, the Strait of Hormuz being effectively blocked is a real issue." "If the crude oil procurement situation changes from what it is now, then we will need to review our refining environment, including equipment and operational aspects. We need to make comprehensive judgments from various angles, and this will require collaboration between the government and private companies," he added. Demand seasons In the short term, Sakai said that Idemitsu has managed to secure a year-ago level of crude procurement volume for June as it stepped up alternative crude sourcing from the Americas after plummeting crude imports from the Middle East in recent months. "In our view, for example, in June, the refinery operation can be almost the same as in June of the previous year. Demand has not drastically decreased or increased in recent years, so whether we can maintain roughly the same level of operation as last year is a major benchmark. That's the kind of image we have for June," Sakai said. Asked about the crude procurement outlook for the rest of year, Sakai said: "Given the current situation, including negotiations with Middle Eastern suppliers and our purchasing contracts, if this situation continues steadily, we can expect stable procurement going forward as well." "Right now, we, like other companies, are preparing for the summer and winter seasons. We need to start preparations for winter now, including stockpiling kerosene and fuel oil to meet increased demand. During this period, we typically increase operations slightly to build inventory for the peak winter demand," he said. "If, for any reason, stable procurement is disrupted during this critical time, it would be very problematic. Therefore, we are proceeding with procurement very cautiously, understanding how important this period is," he added. Japan's crude oil imports plummeted 65.7% year over year to 4.07 million kl or 853,329 b/d in April due mainly to reduced imports from the Middle East, according to preliminary data released May 29 by the Ministry of Economy, Trade and Industry. The April crude imports were the lowest in the available data since 1989, according to METI. "April was indeed extremely low. Looking at our company's situation, April was also quite low. Early in March, the government decided to release oil reserves, and we managed our operations by making use of those reserves in April," Sakai said. "Additionally, the situation in the first half of this month was also quite supported by stockpiled crude oil, which helped us significantly in handling the necessary processing. It left a positive impression that we were quite helped by these stockpiles during this period." Growth strategy Over the next five years, Idemitsu plans to invest a total of Yen 350 billion in expanding its global fuels businesses, including trading, and making forays into the LNG business and North American gas trading. "Currently, one of the characteristics of our group's fuel business is that we have been putting considerable effort into fuel oil trading not only domestically but also overseas over the past few years," Sakai said. "While I cannot specify exact figures, the market is quite volatile year by year, with frequent fluctuations in overseas markets. Therefore, it's not simply about exporting and selling from Tokyo; since it's trading, we aim to procure efficiently and sell at good margins, capturing arbitrage opportunities." "We believe there is still room to grow further... We want to put more effort into this as part of our global expansion strategy," he added. Asked to elaborate on its forays into LNG and North American gas trading businesses, Sakai said: "The reason is that, historically, we did not have LNG, which was a gap in our energy portfolio. We see LNG as a very useful energy source, especially as the world's reliance on fossil fuels like oil and coal continues longer than initially expected, supporting industries and daily life." Idemitsu said March 17 that it had made a move to enter the LNG business by investing $500 million in MidOcean Energy, marking its first step toward a full-scale entry into the sector. "It was a fortunate coincidence, and we see this as an opportunity to finally join the LNG business," Sakai said. "Our policy is to not just invest for dividends or hold rights; we prefer to be involved as an active participant in the business itself." As for its entry into North American gas trading, Sakai said that the company is "planning to supply gas via pipelines to data centers and other facilities being planned in North America." Hydrogen, SAF Meanwhile, Idemitsu remains committed to shaping its hydrogen, ammonia and SAF projects by around FY 2030-31, Sakai said. "Although efforts toward carbon neutrality have slowed somewhat worldwide, hydrogen is one area where we are continuing discussions with companies such as Hokkaido Electric in Hokkaido," he said. "We want to produce green hydrogen, and simply from the standpoint of green hydrogen production itself, Idemitsu Kosan has a business site in Hokkaido, so we want to make effective use of those assets. This is something we want to move ahead with quickly. We also want to bring this into shape by around 2030." While Idemitsu sees SAF still involves many areas that require consultation with airlines and other parties, Sakai said: "We likewise want to get that up and running properly by around 2030, with a proper SAF production facility in place. "We are still examining various aspects, and it is not yet the right timing to make a final decision. We cannot make that kind of major decision unless there is a reasonably clear path toward social implementation -- that is, a situation where users will actually be able to use it properly." Idemitsu is now looking to build a 100,000 kiloliters/year alcohol-to-jet SAF production plant at its Chiba complex in Tokyo Bay and a hydroprocessed esters and fatty acids, or HEFA-based 200,000-250,000 kl/year SAF plant in Tokuyama, Sakai said. "As for blue ammonia, we still maintain the concept of procuring it from places such as the US and building an ammonia supply base in Yamaguchi Prefecture," he added. "Our intention to send ammonia to the Shunan industrial complex as a co-firing fuel has not changed. If the environment is properly put in place, then of course we will accelerate our efforts again." 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/052926-latvia-saf-plant-to-use-kbr-tech-target-2030-start-up</link><description>NorSAF will use KBR&amp;apos;s proprietary PureSAF technology at what is planned to become Northern Europe&amp;apos;s largest sustainable aviation fuel production facility, amid escalating EU mandates requiring a minimum 6% SAF blend at airports by 2030, according to a statement released May 28. NorSAF, a leading SAF producer in the Baltics, has licensed the technology for a new plant in Latvia expected to produce</description><title>Latvia SAF plant to use KBR tech, target 2030 start-up</title><pubDate>29 May 2026 11:37:26 GMT</pubDate><author><name>Thomas Washington</name></author><content><![CDATA[ Agriculture, Energy Transition, Refined Products, Biofuels, Renewables, Jet Fuel May 29, 2026 Latvia SAF plant to use KBR tech, target 2030 start-up By Thomas Washington Editor: Pollock Mondal Getting your Trinity Audio player ready... HIGHLIGHTS Facility targets 100,000 mt/year by 2030 EU mandates 6% SAF blend at airports by 2030 NorSAF will use KBR's proprietary PureSAF technology at what is planned to become Northern Europe's largest sustainable aviation fuel production facility, amid escalating EU mandates requiring a minimum 6% SAF blend at airports by 2030, according to a statement released May 28. NorSAF, a leading SAF producer in the Baltics, has licensed the technology for a new plant in Latvia expected to produce 100,000 metric tons/year of SAF and e-SAF, with production targeted to begin in 2030. The project, backed by Avia Solutions Group, will supply aviation companies across the Baltics, Northern Europe and other European markets. The project addresses both climate goals and energy security concerns by producing drop-in jet fuel at scale using European-sourced feedstocks, JÄnis Kisiels, board member of NorSAF, said in the statement. "By producing sustainable, 100% drop-in jet fuel at scale using local, European-sourced feedstocks, we are building a resilient, self-sufficient energy ecosystem that reduces our dependence on external fossil fuel markets and strengthens Europe's industrial backbone," he said. SAF supplies for Europe are also exposed to overseas production and, therefore, extended supply lines. Global production of SAF will be 64,000 b/d in 2026, of which Europe will account for 54%. It will only account for 18% of production, according to data from S&amp;P Global Horizons. The EU's ReFuelEU Aviation regulation mandates progressive increases in SAF blending at EU airports, reaching 6% by 2030 and 70% by 2050. A sub-mandate requires e-SAF to comprise 1.2% of the fuel mix by 2030, rising to 35% by 2050. SAF comes at a considerable premium to conventional jet fuel. Platts, part of S&amp;P Global Energy, assessed SAF, produced via the HEFA pathway, on a CIF basis in Northwest Europe at $2,894.25/metric ton May 28, compared with $1,124/mt for jet fuel cargoes on an equivalent basis. KBR's PureSAF process, invented and developed by Swedish Biofuels, produces fungible jet fuel ready for immediate use without requiring blending with conventional jet fuel, KBR said. The technology also enables co-processing of carbon dioxide and syngas within the same facility. 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/052926-ohmium-insolare-to-deliver-4-mw-green-hydrogen-project-for-nlc-india</link><description>Ohmium International and InSolare Energy will collaborate for a 4-megawatt renewable hydrogen project for NLC India, for use in power generation, industries and mobility, Ohmium said in a statement late May 28. The plant, situated in Neyveli, Tamil Nadu, with an estimated renewable hydrogen production capacity of up to 700 metric tons/year, aligns with the country&amp;apos;s carbon-neutrality and energy</description><title>Ohmium, InSolare to deliver 4 MW green hydrogen project for NLC India</title><pubDate>29 May 2026 10:52:31 GMT</pubDate><author><name>Ruchira Singh</name></author><content><![CDATA[ Energy Transition, Hydrogen May 29, 2026 Ohmium, InSolare to deliver 4 MW green hydrogen project for NLC India By Ruchira Singh Editor: Vaibhavi Ranjan Getting your Trinity Audio player ready... HIGHLIGHTS NLC India expands renewable energy portfolio Renewable hydrogen output seen at 700 mt/y Govt targets 5 mil mt/y renewable hydrogen by 2030 Ohmium International and InSolare Energy will collaborate for a 4-megawatt renewable hydrogen project for NLC India, for use in power generation, industries and mobility, Ohmium said in a statement late May 28. The plant, situated in Neyveli, Tamil Nadu, with an estimated renewable hydrogen production capacity of up to 700 metric tons/year, aligns with the country's carbon-neutrality and energy transition goals, Ohmium said. NLC India is a government-owned power and coal mining company with a total generating capacity of 7.74-gigawatts, including 1.78 GW of renewable energy, according to its website. Ohmium, which manufactures modular proton exchange membrane electrolyzers, has a global renewable hydrogen project pipeline exceeding 2 GW across three continents, the company previously said in June 2025. India has a target of producing 5 million mt/y of renewable hydrogen by 2030 and commanding a 10% share of the global trade around the same time, as stated in the country's National Green Hydrogen Mission. Platts, part of S&amp;P Global Energy, assessed the India renewable hydrogen term contract at $3.19/kg as of May 18 (weekly price), largely unchanged from a month ago. 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/blog/energy-transition/052526-indias-renewable-energy-tender-market-5-key-trends-in-fy-2025-26</link><description>India achieved its target of having non-fossil fuel sources account for 50% of its total installed power generation capacity in fiscal year 2025-26 (April-March), ahead of its FY 2030-31 schedule. This target was announced by the Indian government at the 26th UN Climate Change Conference (COP26) in 2021. However, there is still a long way to go to achieve its target of having 500 gigawatts of</description><title>India&amp;apos;s renewable energy tender market: 5 key trends in FY 2025-26</title><pubDate>25 May 2026 11:25:10 GMT</pubDate><author><name>Abhyuday Tewari</name></author><content><![CDATA[ Electric Power, Energy Transition, Renewables May 25, 2026 India's renewable energy tender market: 5 key trends in FY 2025-26 Abhyuday Tewari Editor: Roma Arora Getting your Trinity Audio player ready... India achieved its target of having non-fossil fuel sources account for 50% of its total installed power generation capacity in fiscal year 2025-26 (April-March), ahead of its FY 2030-31 schedule. This target was announced by the Indian government at the 26th UN Climate Change Conference (COP26) in 2021. However, there is still a long way to go to achieve its target of having 500 gigawatts of non-fossil fuel capacity, also scheduled for 2030. As of March, India's non-fossil fuel (excluding nuclear) capacity stood at 275 GW, and 223 GW excluding large hydro assets, according to the Ministry of New and Renewable Energy. Most capacity additions stem from renewable energy tenders floated by various state and central implementing agencies. The tender market, therefore, is a key indicator of the trajectory of capacity additions. 1. Tender activity slows down Tendered capacity floated for renewable energy declined 16% in FY 2025-26 compared to FY 2024-25, with a cumulative 65 GW tendered. Similarly, tendered capacity awarded shrank by 45%, with about 24 GW awarded by various state and central implementing agencies and power utilities, according to S&amp;P Global Energy CERA data. 2. Tariff trends diverge across technology segments The demand for stand-alone solar and wind tenders has fallen by almost 75% cumulatively in FY 2024-25, as managing their generation profiles and grid integration has been challenging, according to CERA data. Tariffs for the same have stabilized over the past year as the market has matured and moved to higher use of domestically manufactured capital inputs. In contrast, demand for tenders for renewable energy coupled with storage nearly quadrupled in FY 2024-25 and FY 2025-26, compared with FY 2023-24 levels, according to CERA data. Tenders for round-the-clock renewable energy have gained importance as offtakers demand a firm renewable energy supply. As a result, with rising energy storage and higher peak power demand, tariffs for round-the-clock renewable energy have increased marginally over time. 3. Pivot toward stand-alone storage Of the capacity requested in FY 2025-26, almost 40% pertained to stand-alone energy storage tenders, up from 9% in FY 2024-25, according to CERA data. Most of the storage pertains to two-hour dispatch, followed by four-hour dispatch, and falls under the purview of viability gap funding, which provides developers with financial assistance as a proportion of their capital costs for project setup. Capacity charges for stand-alone storage tenders have dropped substantially over the past three years. 4. Regulatory consolidation to counter challenges In November 2025, the Ministry of Power said that, among the tenders awarded by central renewable energy implementing agencies over April 2023-September 2025, about 44 GW of renewable capacity remained without signed power sale agreements. Consequently, actual project development has been delayed. PSAs are contracts between implementing agencies and distribution utilities. These agencies, known as REIAs, act as intermediaries by using tenders to gather renewable energy capacity from various developers. The distribution utilities then purchase the electricity generated by these projects. Much of this capacity risks being canceled if buyers are not identified. As a result, actual project developments on the ground are also stalled. If these challenges persist, India's pace in achieving its renewable energy targets may be impeded. In April, the Ministry of New and Renewable Energy notified that, going forward, only the Solar Energy Corp. of India will be responsible for issuing renewable energy tenders across technologies at the central level. Previously, this responsibility was held by SECI, NTPC, National Hydroelectric Power Corp. and SJVN. The shift to an SECI-only REIA model addresses a market failure arising from a misalignment between distribution companies' dispatch expectations and the generation profile of tendered renewable capacity, according to CERA analysis. By centralizing tendering authority, the reform aims to strengthen execution certainty and reduce the risk of stranded capacity, albeit at the cost of inter-intermediary competition, according to CERA. This centralization should be a transitional arrangement rather than a permanent change to market architecture. As offtake risks moderate, preserving a pathway back to a multi-REIA framework would be important to reintroduce competitiveness at the procurement layer, sustain innovation in tender design and avoid entrenching monopolistic intermediation, according to CERA analysis. 5. Muted outlook for FY 2026-27 Tender capacity requested and awarded is expected to remain low compared to the highs of FY 2023-24 and FY 2024-25, according to CERA analysts. As of January, there will no longer be an annual tender auction target, according to the Ministry of Power. This is because significant tender capacity remains under execution with implementing agencies and developers. Moreover, demand for stand-alone solar and wind capacity has shrunk, with distribution utilities being wary of generation dispatch volatility. The focus on energy storage and storage-inclusive tenders will remain, as distribution utilities look to firm up renewable supply to lower procurement costs and meet their renewable consumption obligations. Additionally, solar and wind assets have increasingly had to grapple with curtailment, as demand and transmission infrastructure are unable to keep up with generation. India's renewable energy tender data: Assets and Projects - Asia Pacific Further reading: India Power and Renewables Market Briefing â Q2 2026 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/052826-beyond-molecules-the-rise-of-environmental-commodities</link><description>In this episode, host Eklavya Gupte sits down with Marijn van Diessen, CEO of STX Group, one of the world&amp;apos;s leading environmental commodity traders. The conversation explores Europe&amp;apos;s strategic pivot toward domestic energy sources, the explosive growth potential of biomethane as a gas substitute, and the surge in demand for renewable certificates driven by AI data centers -- alongside the</description><title>Beyond molecules: The rise of environmental commodities</title><pubDate>28 May 2026 17:01:29 GMT</pubDate><author><name>Eklavya Gupte</name></author><content><![CDATA[ Energy Transition, Carbon, Emissions May 28, 2026 Beyond molecules: The rise of environmental commodities Featuring Eklavya Gupte HIGHLIGHTS Europe pivots to domestic energy sources Biomethane emerges as key gas substitute AI data centers drive renewable certificate demand In this episode, host Eklavya Gupte sits down with Marijn van Diessen, CEO of STX Group, one of the world's leading environmental commodity traders. The conversation explores Europe's strategic pivot toward domestic energy sources, the explosive growth potential of biomethane as a gas substitute, and the surge in demand for renewable certificates driven by AI data centers -- alongside the challenge of creating liquid markets for products that exist only as digital attestations. Van Diessen explains both the parallels and distinctions between environmental and traditional energy trading. Like oil and gas, environmental commodities require logistics, storage and physical infrastructure. But unlike fossil fuels, they're far more sensitive to regulatory shifts -- where a single policy change can trigger volatility as dramatic as any geopolitical shock. 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-another-month-of-stable-performance-software-declines-as-a-proportion-of-new-credit-estimates-s101687729</link><description>This report does not constitute a rating action. U.S. private credit remains in focus as headlines questioning software sector concentrations, rising default risks, and the broader resilience of middle market lending have underscored the need to look beyond the noise and into the data. 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 indicato</description><title>SF Credit Brief: U.S. Private Credit CLO Insights 2026: Another Month Of Stable Performance; Software Declines As A Proportion Of New Credit Estimates</title><pubDate>27 May 2026 19:07:55 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/agriculture/052626-interview-vema-targets-sub-6-saf-offtake-in-2029-using-geological-hydrogen-ceo-says</link><description>Geologic hydrogen produced by stimulating naturally occurring underground reactions rather than electrolysis could deliver sustainable aviation fuel at prices well below the current $6-$8/gallon market range and green methanol competitive with the $1,200-$1,500/metric ton decarbonized methanol market, Pierre Levin, CEO and co-founder of Canada-based Vema Hydrogen, told Platts in an interview. The</description><title>INTERVIEW: Vema targets sub-$6 SAF offtake in 2029 using geological hydrogen, CEO says</title><pubDate>26 May 2026 20:01:17 GMT</pubDate><author><name>Samyak Pandey</name></author><content><![CDATA[ Agriculture, Energy Transition, Refined Products, Chemicals, Biofuels, Renewables, Jet Fuel, Hydrogen May 26, 2026 INTERVIEW: Vema targets sub-$6 SAF offtake in 2029 using geological hydrogen, CEO says By Samyak Pandey Editor: Karla Sanchez Getting your Trinity Audio player ready... HIGHLIGHTS Quebec offtake deal signed for 2030 delivery Geologic hydrogen priced at $2.50/kg target Geologic hydrogen produced by stimulating naturally occurring underground reactions rather than electrolysis could deliver sustainable aviation fuel at prices well below the current $6-$8/gallon market range and green methanol competitive with the $1,200-$1,500/metric ton decarbonized methanol market, Pierre Levin, CEO and co-founder of Canada-based Vema Hydrogen, told Platts in an interview. The company, which accelerates subsurface serpentinization reactions to produce what it describes as ultra-low-carbon hydrogen at 0.4 kilogram of CO2 equivalent/kilogram of hydrogen, has already signed an offtake-linked agreement with an undisclosed SAF producer to develop production facilities on Vema's Quebec territory, with first SAF volumes targeted for 2030. A separate agreement is in place with an undisclosed green methanol producer for marine applications, with the first methanol molecules targeted for 2029. "Once you have hydrogen at a reasonable price, you can basically have SAF at an acceptable price. SAF is typically priced at $6 to $8 per gallon right now. We would be able to produce below that. Quite below that," Levin said. Vema's hydrogen cost target of about $2.50/kg, enabled by avoiding the electricity-intensive electrolysis process, is the commercial foundation for both the SAF and methanol plays. Levin said that the business model does not depend on subsidies or policy mandates. "I don't believe you can make money based on either government money or on the belief that people will become virtuous and be willing to overpay to decarbonize. This never happened in history. If you want to sell, you need to be in the market," he said. The position puts Vema's proposed SAF directly into competition with established hydroprocessed esters and fatty acids-based routes and emerging alcohol-to-jet pathways. The Power-to-Liquid or e-fuel SAF route that Vema's hydrogen would feed has historically been the most cost-challenged SAF pathway, with high green hydrogen input costs making it uncompetitive against HEFA or ATJ without significant subsidy support. Levin said that geologic hydrogen, which avoids the capital and electricity costs of the electrolyzer stack entirely, fundamentally changes that calculus. The methanol-to-SAF pathway is well-established technically, and Vema's 0.4 kg CO2e/kilogram hydrogen intensity would, Levin said, produce methanol and downstream SAF with a significantly better carbon footprint than biofuel-based methanol alternatives, including Chinese biomass-based methanol currently being offered into the shipping market at about $900/mt. Marine biobunker: methanol first, ammonia later The shipping decarbonization market is Vema's primary near-term revenue target, with methanol positioned as the first product to reach commercial scale, ahead of ammonia, which Levin said carries a four-to-five-year plant lead time versus one-to-two years for methanol or SAF. Levin said Vema is in discussions with a major shipping company, which he declined to name, for over 250,000 tons of decarbonized methanol per year from its Quebec operations, equivalent to about 45,000-46,000 mt of hydrogen. The logistics are already partly de-risked: Vema's Quebec sites have a direct rail connection to the Port of Quebec City, which is ice-free year-round and has bunkering infrastructure for methanol. On the International Maritime Organization's recent failure to advance a binding levy framework, which has rattled parts of the green shipping investment community, Levin said shipping majors he has spoken with are treating it as a temporary setback rather than a structural reversal. "After the IMO failed meeting, I had discussions with high-up executives in a bunch of those large shipping companies. They said, 'This is a blip on the road. That's not changing our roadmap. That's not changing our appetite. We already have dozens of methanol-powered vessels'." Ammonia remains a longer-horizon play. Levin noted that commercially viable ammonia plants require at least 700 mt/day of feedstock and a significant hydrogen commitment. He said that while Vema has a potential partner exploring on-site ammonia production, the timeline is substantially longer than for methanol or SAF. The shipping market's internal split between methanol-fuel advocates and ammonia-fuel advocates does not concern Vema. "As long as we sell our hydrogen, we are very happy," Levin said. Regulatory hurdle is the critical bottleneck Despite the commercial logic, Levin identified regulatory permitting, not technology or economics, as the single biggest obstacle to Vema's timeline. The company requires regulatory frameworks that allow hydrogen production from subsurface stimulation, a category for which most jurisdictions have not yet established permitting pathways. Canada, particularly Quebec and Newfoundland, is the most advanced market, with Vema actively working with federal and provincial authorities to improve regulations. In the US, Oregon and California are operable, while Minnesota, which Levin described as having "fabulous resources," currently blocks operations at the regulatory level. Brazil has a partial legal framework in place, but has not fully implemented it. Australia is favorably disposed but remains at an early stage. Japan is in active discussions, with Vema evaluating local partners as a prerequisite for any development plan. "We don't want the money from the government. We want the option to operate without a two- to three-year lead time before we can even start drilling a well. We need a permit for a pilot well in six months and a permit for a production well in less than 12," Levin said. Why geologic hydrogen, not green or blue Levin was dismissive of both green and blue hydrogen as commercially viable routes to the SAF and decarbonized marine fuel market at scale. On blue hydrogen, Levin noted that the best achievable carbon intensity is 5 kg CO2e/kg of hydrogen and that most US carbon capture, utilization and storage projects store CO2 in sedimentary formations rather than mineralizing it, which he described as a long-term liability rather than a genuine decarbonization solution. On green hydrogen, the arithmetic is stark: producing the 90 million mt of hydrogen already consumed globally per day would require 20% of global electricity production. At a baseload electricity cost floor of 5 cents/kilowatt-hour, the physics require 55-60 kWh to produce 1 kg of hydrogen, creating an irreducible cost floor of about $3/kg before any other costs, making a sub-$4/kg delivered price, the market viability threshold, essentially impossible without heavy subsidy. "The maths don't work. Green hydrogen doesn't work without government," Levin said. Vema, by contrast, targets a $2-$2.50/kg cost by accelerating subsurface reactions between water and iron-rich rocks, a process that occurs naturally over geological timescales but can be engineered. The company describes its technology as "accelerating a natural reaction instead of breaking the water molecule at brute force with expensive electricity." Platts, part of S&amp;P Global Energy, assessed CFR China methanol at $399/mt on May 26, up $2/mt day over day. 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/blog/energy-transition/052726-et-highlights-us-lithium-ion-battery-norway-eu-methane-australia-data-center-power-demand</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: US lithium-ion battery imports fall, Norway warns on EU methane regulations, Australia to double power demand</title><pubDate>26 May 2026 20:05:00 GMT</pubDate><author><name>Staff </name></author><content><![CDATA[ Energy Transition, Renewables, Emissions, Carbon May 27, 2026 ET Highlights: US lithium-ion battery imports fall, Norway warns on EU methane regulations, Australia to double power demand 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 US lithium-ion battery imports fall in Q1 US lithium-ion battery imports tumbled in the first quarter of 2026 as new supply chain restrictions and tariffs took effect, slowing shipments especially from China -- the world's largest battery maker, according to the S&amp;P Global Market Intelligence Global Trade Analytics Suite. The US imported 171,023 metric tons of batteries for electric vehicles, energy storage and other uses in the first quarter, falling 46.5% from a year ago and 40.5% from the fourth quarter of 2025. That marked the lowest level of quarterly lithium-ion battery imports in over two years, the trade data shows. The first-quarter slowdown coincided with the implementation of strict new US foreign entity of concern rules for renewable energy and energy storage projects to claim federal tax credits, an increase in the Section 301 tariff rate on Chinese batteries for stationary storage -- to 25% from 7.5% -- and a significant expansion of US battery manufacturing. Battery imports for energy storage and other non-EV uses reached 150,150 mt in the first quarter of 2026, falling more than 47% from a year ago and 44% from the final quarter of 2025. EV battery imports totaled 20,873 mt in the first quarter, down nearly 33% from 31,082 mt a year earlier. But first-quarter EV battery imports rose 9.3% from 19,091 mt in the fourth quarter of 2025. Benchmark of the Week $22,700/mt Platts, part of S&amp;P Global Energy, assessed battery-grade lithium carbonate DDP US at $22,700/mt on May 22. China accounted for 60.3% of US lithium-ion battery imports in the first quarter, down from 84.8% in the first quarter of 2025 and 80.2% in Q4 2025, according to the Global Trade Analytics Suite, which relies on US Census Bureau data. Explore Platts Energy Transition Price Assessments Editor's Picks: Free and premium content SPGlobal.com ECOSPERITY WEEK: Asia-Pacific carbon market optimism contrasts with EU caution: VCMI Asia-Pacific views climate action and carbon markets as an economic opportunity despite regulatory costs, contrary to the EU seeking delays in emissions regulations and being wary of aggression toward climate action amid competitiveness concerns, Mark Kenber, executive director of the Voluntary Carbon Markets Integrity Initiative, told Platts, part of S&amp;P Global Energy, during Ecosperity Week 2026 in Singapore. Kenber said he saw genuine belief that addressing climate change and a green economy really is an opportunity in almost every country in Asia-Pacific. In contrast, concerns about competitiveness and economic sluggishness have led some companies in Europe to seek delays in emissions regulations or additional allocations, amid the Middle East crisis and elevated energy costs, he said. Norway warned EC in 2025 methane law risks hindering oil, gas output The Norwegian government warned the European Commission in a memo sent in 2025 and seen by Platts that the EU's methane emissions regulation could lower Norway's oil and natural gas exports to the EU and, ironically, increase Norwegian producers' total upstream greenhouse gas emissions. The government noted that frequent offshore site inspections could lead to higher emissions from maritime activities than would be saved from fixing leaks. Increased flaring is another concern, since shutting down plants to fix minor leaks would require flaring that would otherwise be unnecessary without the regulation, it said. ECOSPERITY WEEK: Carbon markets face governance risks seen in financial markets Carbon markets are now grappling with the same governance, legal, and financial risks that have long challenged global financial markets, industry experts at Innovate4Climate during Ecosperity Week in Singapore said during a May 22 panel, raising questions about market integrity and long-term viability. One of the prominent themes throughout the discussion was that integrity now sits at the center of the carbon market, as the market attracts more compliance buyers and institutional capital, with confidence in the credibility of carbon credits becoming essential. S&amp;P Global Energy Core Fragmented approach hampering hydrogen transition: Oman energy minister A lack of coordination and fragmented, shifting regulations are hampering efforts to deliver a global renewable hydrogen economy, Omanâs energy minister said at the World Hydrogen Summit in Rotterdam, the Netherlands, on May 19. Minister of Energy and Minerals Salim al-Aufi said there was a need for partnership, where it sometimes felt like countries were working alone. âWe all believe we're going in the same direction, but we're not, unfortunately,â Aufi said. Australia data centers set to double power demand by 2030: S&amp;P Global report Australia's data centers are reshaping electricity demand in ways that challenge traditional planning, with consumption expected to more than double this decade, according to an S&amp;P Global Energy report, 'Australiaâs data centers and the emerging power system bottleneck'. Data center electricity consumption is forecast to reach 16 terawatt-hours by 2030, with New South Wales' share of power demand rising from 3% in 2025 to 10% by 2030, Logan Reese, director, lead OECD Asia Power and Renewables at S&amp;P Global Energy, said in the report. Data centers have become a large, fast-growing load, with development anchored in metropolitan areas and driven by time-to-market, he said. UK's Yamna secures approval for renewable ammonia project in India UK-based renewable hydrogen producer YamnaCo secured approval from the Andhra Pradesh state government for the first phase of its proposed large-scale renewable ammonia project in India, the company said. The project will be developed in two phases, with a total targeted production capacity of 1 million metric tons/year of renewable ammonia, it said. The approval of the Andhra Pradesh green ammonia project represents an important step for Yamna to build a globally diversified portfolio of clean energy assets, Abdelaziz Yatribi, CEO at Yamna, said. The state cabinet approved the first phase, comprising 500,000 mt/year of production capacity, according to Yamna. ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/podcasts/commodities-focus/052726-indias-renewable-hydrogen-projects-face-cost-delay-risks-from-global-conflicts</link><description>India has established a strong foothold in the emerging clean fuels industry, leveraging its low-cost renewable energy resources to position itself as a competitively priced producer of renewable hydrogen and ammonia for both domestic industrial use and large-scale exports to buyers seeking to secure future supplies of low-carbon fuels. However, recent geopolitical tensions, particularly in the</description><title>India&amp;apos;s renewable hydrogen projects face cost, delay risks from global conflicts</title><pubDate>27 May 2026 08:06:19 GMT</pubDate><author><name>Vipul Garg</name><name>Ruchira Singh</name></author><content><![CDATA[ Energy Transition, Electric Power, Hydrogen, Renewables May 27, 2026 Indiaâs renewable hydrogen projects face cost, delay risks from global conflicts Featuring Vipul Garg and Ruchira Singh HIGHLIGHTS Geopolitical tensions disrupt supply chains Long-term outlook remains robust despite risks India has established a strong foothold in the emerging clean fuels industry, leveraging its low-cost renewable energy resources to position itself as a competitively priced producer of renewable hydrogen and ammonia for both domestic industrial use and large-scale exports to buyers seeking to secure future supplies of low-carbon fuels. However, recent geopolitical tensions, particularly in the Middle East, have disrupted supply chains and pushed up costs, posing risks to project timelines and cost estimates. Despite these near-term challenges, India's long-term outlook remains robust, supported by the global shift from conventional fuels, an emphasis on energy security, and net-zero targets across major economies, which are expected to drive future trade in renewable fuels. Ruchira Singh, editor, energy transition at S&amp;P Global Energy, joins Nishaanth Balashanmugam, CEO and director of GH2 India--a trade body focused on accelerating renewable hydrogen in the country--and Vipul Garg, senior hydrogen price reporter at S&amp;P Global Energy, to discuss the factors shaping the sector, including the evolving business environment, regulatory landscape, and emerging markets for renewable hydrogen. Related content: India may delay renewable hydrogen tenders until existing projects progress: official (Subscriber content) India Renewable Hydrogen Term Contract $/kg Weekly - NWERG04 Australia Renewable-derived Ammonia delivered into Far East Asia - GADAB04 Spotify | Apple Podcasts 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/052526-acelen-secures-15-billion-for-brazil-saf-biorefinery-project</link><description>Acelen Renewables secured $1.5 billion in financing to begin construction of a renewable fuel biorefinery in Bahia, Brazil, marking one of Latin America&amp;apos;s largest sustainable aviation fuel projects as the country positions itself as a key supplier in global biofuels markets. The financing was arranged by a consortium supported and led by HSBC and the International Finance Corp., which includes ten</description><title>Acelen secures $1.5 billion for Brazil SAF biorefinery project</title><pubDate>25 May 2026 09:29:07 GMT</pubDate><author><name>Samyak Pandey</name></author><content><![CDATA[ Agriculture, Energy Transition, Refined Products, Biofuels, Renewables, Jet Fuel May 25, 2026 Acelen secures $1.5 billion for Brazil SAF biorefinery project By Samyak Pandey Editor: Anoop Menon Getting your Trinity Audio player ready... HIGHLIGHTS Acelen secures $1.5 bil for Brazil biorefinery Facility to produce 1 bil liters SAF annually Operations begin in 2029 in Bahia, Brazil Acelen Renewables secured $1.5 billion in financing to begin construction of a renewable fuel biorefinery in Bahia, Brazil, marking one of Latin America's largest sustainable aviation fuel projects as the country positions itself as a key supplier in global biofuels markets. The financing was arranged by a consortium supported and led by HSBC and the International Finance Corp., which includes ten national and international financial institutions: First Abu Dhabi Bank, Abu Dhabi Commercial Bank, IDB Invest, BNDES, Asian Infrastructure Investment Bank, Development Finance Institute Canada, KfW IPEX-Bank, Bradesco, BBVA, and Bank of China, Acelen said in a statement May 22. The biorefinery, scheduled to begin operations in 2029, will have the capacity to produce 1 billion liters annually of SAF and renewable diesel using hydroprocessed esters and fatty acids technology, one of the leading global technologies for producing renewable fuels. The project will position Brazil among the leading global hubs for sustainable aviation and heavy transport fuels, enhancing the country's energy security, Acelen said. "Brazil has unique conditions to lead the global energy transition: combining agricultural scale, industrial excellence, and one of the cleanest energy matrices in the world," Leonardo Yamamoto, partner at Mubadala Capital, said. "With a consolidated presence in the country, Mubadala Capital believes in Brazil's potential to develop renewable fuels on a large scale." Project structure This stage marks the project's advancement and consolidates international market confidence in the country's competitive advantages for developing a new low-carbon industrial platform. In total, the company's first integrated unit will involve an investment of over $3 billion and includes agro-industrial development encompassing the planting, extraction, and processing of macauba byproducts, Acelen said. The IFC, a World Bank Group institution focused on private sector development, acted as the general coordinator and lead arranger, in conjunction with HSBC, to ensure the financial structuring following extensive technical, environmental, and social due diligence. The financial structure reinforces the technical and commercial maturity of the project, which has already completed integrated engineering, negotiated strategic contracts and has about 90% of the SAF and renewable diesel commercialization structured and signed. The project also has partners of national and global relevance, such as Honeywell UOP, Alfa Laval and Construcap, in addition to commercial agreements with companies such as Trafigura, Moeve, Bunge and BGN, Acelen said. The biorefinery will be built in an existing industrial area in SÃ£o Francisco do Conde, Bahia, the company said. Feedstock strategy The project integrates agricultural production, industrial development and technology to produce advanced renewable fuels from traditional raw materials (soybean oil and used cooking oil) and macauba, a native Brazilian crop with high potential for advanced biofuels. Acelen Renewables plans cultivation on 144,000 hectares in degraded areas, considering productivity gains already incorporated into the project, with 20% set aside for partnerships with family farmers and small producers. Acelen is developing an integrated biofuels platform in Brazil based on macauba, a non-food oilseed, with planned production capacity of 1 billion liters/year of renewable fuels. The US and Europe are targeted as key export markets. In March 2026, Acelen Renewables and Finboot signed a partnership to develop digital traceability infrastructure for biofuel production, targeting SAF and renewable diesel supply chains. The 12-month agreement deployed Finboot's blockchain-based "Marco Track &amp; Trace" platform to monitor the full life cycle of biofuel production, including feedstock origin, farm-level output, emissions and sustainability compliance. Brazil's National Agency for Petroleum, Natural Gas and Biofuels plans to publish a regulation for the production and marketing of SAF in the second half of 2026. According to the Fuel of the Future Law, enacted in October 2024, airlines operating domestic flights must reduce their emissions by 1% through the use of SAF starting in 2027. The blending mandate will gradually increase to 10% by 2037. Platts, part of S&amp;P Global Energy, assessed SAF California at 994.49 cents/gallon and SAF (H-S) CA (credits det) at 603.45 cents/gal on May 22, based on a spread of neat SAF to Jet Kero LA CA pipeline of 217.67 cents/gal. 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/052626-stockholm-emerges-as-key-buyer-of-removal-credits-with-bioenergy-carbon-capture-deal</link><description>The city of Stockholm has emerged as the world&amp;apos;s fifth-largest buyer of permanent carbon removal credits after signing a 15-year agreement with Stockholm Exergi for 50,000 mt/year, marking a significant expansion of the Swedish capital&amp;apos;s climate strategy as it races to meet ambitious 2030 targets. The deal, signed through the city&amp;apos;s group company, Stockholm Stadshus AB, will help offset</description><title>Stockholm emerges as key buyer of removal credits with bioenergy carbon capture deal</title><pubDate>26 May 2026 10:14:19 GMT</pubDate><author><name>Eklavya Gupte</name></author><content><![CDATA[ Energy Transition, Agriculture, Carbon, Biofuels, Renewables May 26, 2026 Stockholm emerges as key buyer of removal credits with bioenergy carbon capture deal By Eklavya Gupte Editor: Alisdair Bowles Getting your Trinity Audio player ready... HIGHLIGHTS Includes a 15-year deal for 50,000 mt/year Stockholm BECCS plant will capture 800,000 mt/year of CO2 The city of Stockholm has emerged as the world's fifth-largest buyer of permanent carbon removal credits after signing a 15-year agreement with Stockholm Exergi for 50,000 mt/year, marking a significant expansion of the Swedish capital's climate strategy as it races to meet ambitious 2030 targets. The deal, signed through the city's group company, Stockholm Stadshus AB, will help offset hard-to-abate emissions from construction materials and wastewater treatment as Stockholm pursues its goal of becoming climate-positive by 2030 and fossil-fuel-free by 2040, the companies said May 26. The agreement builds momentum for Stockholm Exergi's 800,000 mt/year bioenergy with carbon capture and storage, or BECCS, facility in Stockholm, which took a final investment decision in March last year and is scheduled to begin operations in 2028. BECCS involves capturing and permanently storing CO2 from processes where biomass is converted into fuels or directly burned to generate energy. The plant will capture CO2 from biomass combustion, with the emissions transported by ship to Bergen, Norway, for permanent storage in subsea bedrock. The project is being funded through government support and the sale of carbon removal credits. Stockholm Exergi has already secured multiple long-term offtake agreements for removal credits from the facility in recent years, including an expanded deal with Microsoft covering 5.08 million mt over 10 years. BECCS is increasingly recognized as an effective technological solution for reducing CO2 emissions, particularly within the pulp and paper, power generation, waste management, ethanol and cement sectors. Several BECCS projects are underway in countries including the US, the UK, Sweden, Denmark, France, Switzerland and Canada. Carbon removal refers to climate mitigation strategies that extract CO2 from the atmosphere, in contrast to approaches that aim to avoid such emissions. Carbon removal credits from carbon capture projects are traded on voluntary carbon markets. Platts, part of S&amp;P Global Energy, assessed biochar carbon credits in the US at $144/mtCO2e on May 22. 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/051826-ecosperity-week-iea-urges-balanced-transition-credits-for-early-southeast-asia-coal-exits</link><description>Transition credits must strike a balance between power system reliability and carbon credit integrity to enable early coal plant retirements in Southeast Asia, where relatively young coal fleets are crucial for energy security, the International Energy Agency said in a report released May 15 at GenZero&amp;apos;s Climate Summit, during the Ecosperity Week 2026 event in Singapore. The report, &amp;quot;Financing the</description><title>ECOSPERITY WEEK: IEA urges balanced transition credits for early Southeast Asia coal exits</title><pubDate>18 May 2026 14:57:54 GMT</pubDate><author><name>Himanshu Chauhan</name></author><content><![CDATA[ Energy Transition, Carbon, Renewables May 18, 2026 ECOSPERITY WEEK: IEA urges balanced transition credits for early Southeast Asia coal exits By Himanshu Chauhan Editor: Arushi Jain Getting your Trinity Audio player ready... HIGHLIGHTS Demand limited; compliance markets seen as strongest anchor Philippines projects priced at $35-$50/mtCO2e, aligning with Singapore ICCs Policy reversal risk cited as key concern for buyers Transition credits must strike a balance between power system reliability and carbon credit integrity to enable early coal plant retirements in Southeast Asia, where relatively young coal fleets are crucial for energy security, the International Energy Agency said in a report released May 15 at GenZero's Climate Summit, during the Ecosperity Week 2026 event in Singapore. The report, "Financing the Modernization of Power Systems Beyond Coal: The role of transition credits in Southeast Asia," emphasizes that transition credits should only be issued where carbon revenues demonstrably bring forward retirement or emissions reductions that would not otherwise have occurred on the same timeline. The report noted that it's a critical consideration in Southeast Asia, where phasedown commitments are emerging, but early retirement is not mandated. "Transition credits may support modernizing power systems and accelerating coal transitions, but only under the right policy, planning and market conditions," Sue-Ern Tan, Head of the International Energy Agency Regional Co-operation Centre. Transition credits are a type of carbon credit issued from verified emissions reductions achieved by accelerating the early retirement of coal-fired power plants and replacing their generation with cleaner energy sources. Singapore allows entities covered by its carbon tax to offset up to 5% of their emissions using eligible international carbon credits, creating compliance demand for high-integrity credits, including those generated under Article 6.2 bilateral agreements. Platts, part of S&amp;P Global Energy, assessed Singapore's eligible ICCs at S$31/mtCO2e on May 14. Platts reported that Singapore and the Philippines signed their Article 6 implementation agreement on April 30, establishing a framework for generating and transferring carbon credits from mitigation projects. Among published methodologies, Verra's VM0052 is being piloted at the South Luzon Thermal Energy Corporation plant in the Philippines, the IEA report noted. The methodology includes requirements for just transition plans, grid stability assessments, and system operator involvement to ensure energy security is maintained during the transition. "When we look at VM0052 in particular, all the stuff around integrity is part and parcel of the methodology. But very much in particular when it comes to coal shutdown, there are huge questions around what happens to the community," Mandy Rambharos, Chief Strategy Officer at Verra, said. Philippines projects priced around Singapore ICCs The Philippines transition credit pilot project is currently priced at indicative levels of Singapore-eligible International Carbon Credits, aligning with Singapore's carbon tax range, the panel said. The Transition Credits are priced there, not only because current demand is limited to Singapore, but the price per credit turned out to be around $35-$50/mtCO2e, Eric Francia, President and CEO of ACEN, told Platts. So it suits the range of Singapore ICCs, he added. During the panel discussion, he noted that while variables such as coal prices, interest rates, foreign exchange rates, and solar and battery prices continue to fluctuate, current modeling suggests that transition credits remain within the range of Singapore's carbon tax trajectory. Demand remains limited; offtakers critical Transition credit demand remains modest, with compliance carbon markets offering the strongest potential anchor for future demand, the IEA report noted. "Weak demand signals today mean there may not be sufficient clear price signals for commitments to early retirement investments in the near term," the report said. Francia emphasized that offtakers are essential to make transition credit projects financially viable, noting that ACEN is looking to Singapore and Japan for support, with hopes that Europe might offer opportunities when it allows limited use of international credits starting in 2036. At the same time, Frederick Teo, CEO of GenZero, cautioned against over-reliance on Singapore's carbon tax as a demand anchor, noting that if the tax rises to S$100/mtCO2e, buyers will seek to average down their effective price rather than pay the maximum rate. Nat Keohane, President at the Center for Climate and Energy Solutions, noted that the Philippines transaction presents an opportunity to demonstrate how disparate demand sources, including voluntary corporate commitments, Singapore's carbon tax compliance, and Article 6 sovereign demand, can be combined for a single project. Transition credits may also help address supply-demand gaps in the Carbon Offsetting and Reduction Scheme for International Aviation (CORSIA), where airlines can use eligible credits to offset compliance obligations, the panel suggested. However, the report noted that the risk of policy reversal remains a key concern, as changes in domestic priorities could weaken integrity requirements and reduce buyer confidence. 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/strategic-imperatives</link><description>India is set to become the worldâ&amp;#x80;&amp;#x99;s third-largest economy by 2031, and global uncertainty is necessitating a recalibration of the countryâ&amp;#x80;&amp;#x99;s strategic options. It must straddle the line between self-sufficiency and diversification.</description><title>India Forward: Strategic Imperatives</title><pubDate>26 May 2026 09:00:00 GMT</pubDate><content><![CDATA[ Volume 4 â 26 May 2026 India Forward: Strategic Imperatives Welcome to the fourth edition of India Forward: Strategic Imperatives. We share this report with our customers and key stakeholders at a defining moment in time: India is set to become the worldâs third-largest economy by 2031, and global uncertainty is necessitating a recalibration of the countryâs strategic options. It must straddle the line between self-sufficiency and diversification. Todayâs global economies must balance their macroeconomic, geopolitical, trade and energy options, aligning supply and demand dynamics with their immediate needs and long-term ambitions. India enters this volatile period backed by strong domestic fundamentals; the country is well positioned to harness these economic shifts and accelerate toward its goal of becoming an advanced economy by 2047. The knock-on effect of this uncertainty is already evident across crude oil benchmarks, currency volatility and shifting investor sentiment. While robust corporate and banking sectors provide a vital cushion against immediate shocks, maintaining Indiaâs upward trajectory will require deft management of energy security, fiscal resilience, regulatory interventions and trade diversification. Strategic Imperatives brings together thought leaders from S&amp;P Global and Crisil to decode these complex dynamics and map the risks and opportunities ahead. India Forward underscores the continued commitment that S&amp;P Global and Crisil share to follow Indiaâs growth story as global volatility heightens. I am confident that our data, insights and perspectives will empower our stakeholders to make informed, strategic decisions at this critical time. S&amp;P Global Head of India Leadership Council Abhishek Tomar Head of Data, Enterprise Data Organization In this role, he leads essential functions such as data operations, business partnerships, stewardship, and quality assurance, while also focusing on customer success, data performance optimization, and site operations management. Additionally, Abhishek is a strategic advisor to the leadership teams in India, Pakistan and the Philippines. He spearheads the India Leadership Council, comprising S&amp;P Global and Crisil, aiming to identify new strategies and business development opportunities across the region. With 22 years of experience, Abhishek has held various roles in data analytics and operations management, including senior management and leadership positions in the financial industry. Previously, Abhishek was Chief Data Officer for S&amp;P Global Market Intelligence and Managing Director - India Operations at S&amp;P Global where he was responsible for over 8,000 employees with a focus on delivering strong business results. Abhishek is an active member of the National Executive Board of American Chamber of Commerce (AMCHAM) in India. He holds a bachelorâs degree in Commerce from Delhi University and an MBA from NIILM - Centre for Management Studies. In this edition Sponsors and Leads of the India Research Chapter S&amp;P Global Head of India Leadership Council Abhishek Tomar Head of Data, Enterprise Data Organization In this role, he leads essential functions such as data operations, business partnerships, stewardship, and quality assurance, while also focusing on customer success, data performance optimization, and site operations management. Additionally, Abhishek is a strategic advisor to the leadership teams in India, Pakistan and the Philippines. He spearheads the India Leadership Council, comprising S&amp;P Global and Crisil, aiming to identify new strategies and business development opportunities across the region. With 22 years of experience, Abhishek has held various roles in data analytics and operations management, including senior management and leadership positions in the financial industry. Previously, Abhishek was Chief Data Officer for S&amp;P Global Market Intelligence and Managing Director - India Operations at S&amp;P Global where he was responsible for over 8,000 employees with a focus on delivering strong business results. Abhishek is an active member of the National Executive Board of American Chamber of Commerce (AMCHAM) in India. He holds a bachelorâ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 Look Forward Council, Co-Chair 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 Farhan Husain Global Head of Communications Farhan Husain is the Global Head of Communications for S&amp;P Global, serves as a member of the Operating Committee, and oversees strategic communications for S&amp;P Globalâs South Asia operations across India and Pakistan. Most recently, Farhan was also Global Head of ESG Communications for S&amp;P Global where he established a global team and communication strategy for S&amp;P Globalâs first ESG commercial business, S&amp;P Global Horizons. Farhan is an established global communications leader who has extensive experience partnering with C-Suite executives to provide strategic counsel and execution across public relations, executive communications, change management, M&amp;A and strategy communication, internal communication strategy, and investor relations. Farhan joined S&amp;P Global in 2016 where he managed the external communications strategy for the US, Canada and Latin America before being promoted to Global Head of External Communications for Market Intelligence in 2017. Farhan also held communications positions in S&amp;P Global Ratings overseeing the successful communications strategy for the Ratingsâ ESG Evaluation launch, and spearheaded the internal and external visibility strategy for S&amp;Pâs Chief Economists. Prior to joining S&amp;P Global, Farhan held several communications and marketing roles in the financial services industry across companies including Ernst and Young (EY), International Securities Exchange/NASDAQ and the New York Stock Exchange. Farhan was the founder of Baruch College Campus High Schoolâs Alumni Association and currently sits on the Board of Reach out and Read - Greater New York chapter. He has a 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 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 Executive Director, Global Energy Transitions and Clean Tech Consulting 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 Pulkit Agarwal Head of India Content Pulkit Agarwal is Hrad of India Content S&amp;P Global Energy Look Forward Council, Co-Chair 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 Market Intelligence Mai Barakat Data Center Services and Infrastructure Analyst Mai Barakat is an analyst on the 451 Research Datacenter Services &amp; Infrastructure team at S&amp;P Global Market Intelligence. Her research focuses on datacenter market activity across Europe, the Middle East and Africa. Her key research areas include emerging datacenter markets; retail, wholesale and cloud provider activity; industry growth projections; market share analysis; government incentives and regulations; and pricing dynamics. Before joining the Datacenter Services &amp; Infrastructure team in 2020, her focus was on mobile telecommunications and 5G in Europe. Prior to that she spent more than 10 years at Omdia covering mobile/fixed telecommunications and TV in the Middle East and Africa, with a special focus on mobile banking and fintech initiatives in emerging markets. Mai holds a Bachelor of Science in international management and French from the University of Bath, UK and an MSc in marketing. She is fluent in Arabic and French. S&amp;P Global Energy Gauri Jauhar Executive Director, Global Energy Transitions and Clean Tech Consulting 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 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 Soon Chen Kang Senior Research Analyst Soon Chen Kang is a research analyst in the 451 Research technology research group within S&amp;P Global Market Intelligence covering datacenter activities in Asia-Pacific for the Datacenter Services and Infrastructure channel. Soon Chenâs research area includes expansion activities, customer verticals, industry growth projections and pricing dynamics of the datacenter colocation market. Her most recent work focuses on go-to-market analysis of the emerging datacenter markets in Southeast Asia. Prior to this role, Soon Chen was a journalist covering the consumer sector at S&amp;P Global Market Intelligence. She wrote extensively on the evolving e-commerce landscape in the region. Soon Chen holds a Bachelor of Education in Teaching English as a Second Language degree from University Malaya. She is fluent in Chinese and Bahasa Malaysia. S&amp;P Global Market Intelligence Deepa Kumar 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 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 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 Key support and contributions by: Brianne Paschen, Claire Wilson, Ellen White, Mary Brown, Benjamin Yang, Shipra Singh, Pooja Nair, Rajat Juneja, 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/latest-news/energy-transition/052526-ecosperity-week-carbon-markets-face-governance-risks-seen-in-financial-markets</link><description>Carbon markets are now grappling with the same governance, legal, and financial risks that have long challenged global financial markets, industry experts at Innovate4Climate during Ecosperity Week in Singapore said during a May 22 panel, raising questions about market integrity and long-term viability. One of the prominent themes throughout the discussion was that integrity now sits at the center</description><title>ECOSPERITY WEEK: Carbon markets face governance risks seen in financial markets</title><pubDate>25 May 2026 10:37:54 GMT</pubDate><author><name>Donavan Lim</name></author><content><![CDATA[ Energy Transition, Carbon, Emissions May 25, 2026 ECOSPERITY WEEK: Carbon markets face governance risks seen in financial markets By Donavan Lim Editor: Anoop Menon Getting your Trinity Audio player ready... HIGHLIGHTS Concerns raised around risks related to corresponding adjustment Permanence, delivery risks attached to projects Need to manage disputes, accountability as carbon markets scale Carbon markets are now grappling with the same governance, legal, and financial risks that have long challenged global financial markets, industry experts at Innovate4Climate during Ecosperity Week in Singapore said during a May 22 panel, raising questions about market integrity and long-term viability. One of the prominent themes throughout the discussion was that integrity now sits at the center of the carbon market, as the market attracts more compliance buyers and institutional capital, with confidence in the credibility of carbon credits becoming essential. Juan Carlos Arredondo, director of knowledge and policy at Abatable, a member of the Technical Advisory Body for the CORSIA carbon-cutting scheme, explained that within such systems, liability revolves around two fundamental questions: whether credits genuinely represent real emissions reductions, and whether host countries correctly account for those transfers under the Paris Agreement framework. "These concerns are especially important for airlines and compliance buyers that must rely on credits remaining valid over long periods of time," said Arredondo. "If a host country later revokes authorization or fails to properly apply corresponding adjustments, uncertainty quickly emerges regarding who bears responsibility and how replacement obligations should be handled." Platts, part of S&amp;P Global Energy, assessed the CEC price that represents fully eligible Phase 1 CORSIA credits at $12/mtCO2e on May 22, the lowest level since Jun 18 2024 on muted demand as end-buyers (airlines) stay largely absent from the market. Arredondo emphasized that integrity cannot be resolved solely through financial compensation, and in many cases, invalid credits must be replaced with new units. Weighing permanence, delivery risks In addition, buyers are increasingly differentiating between projects based on permanence, delivery certainty, governance quality, and long-term credibility. "For years, the voluntary carbon market often assumed that one metric ton of carbon reduction was effectively equal to another, regardless of differences in project quality or execution risk, " said Sebastian Cross, co-founder and chief innovation officer at BeZero Carbon. "That assumption contributed significantly to credibility concerns across the sector." Higher-quality projects are increasingly able to command better prices, encouraging developers to prioritize integrity and transparency over simply maximizing issuance volumes. Platts assessed Indonesia's Katingan Mentaya project at $11.50/mtCO2e, at a premium to other REDD+ projects in Southeast Asia. The premium is primarily driven by the project's strong third-party ratings profile, as market participants weigh in factors such as co-benefits, permanence, and additionality. Katingan Mentaya has been described in project-linked reporting as carrying AA ratings from major third-party ratings agencies. Indonesia's Rimba Raya Biodiversity Reserve, which carries a lower rating, was priced at $4.70/mtCO2e. However, comparable projects such as Malaysia's IFM Kuamut Rainforest Conservation Project were assessed at about $26/mtCO2e for removals and $16.50/mtCO2e for avoidance credits. That transition is being accelerated by the growing influence of ratings agencies, according to Cross, who are evaluating delivery risk, permanence risk, project execution, and the probability that emissions reductions will actually materialize. Cross observed that the market is gradually beginning to resemble more mature financial systems where risk pricing and quality differentiation are standard components of investment decisions. Building institutional structures A second major theme of the discussion focused on governance and the institutional structures needed to manage disputes and accountability as carbon markets scale internationally. Judy Ndichu, carbon market lead representing Kenya's Office of the Special Envoy for Climate Change, argued that the goal is not to eliminate conflict entirely but to create systems capable of managing disputes transparently. Drawing on Kenya's experience with both the Clean Development Mechanism and voluntary carbon markets, Ndichu explained that conflicts can emerge between project developers and local communities, between governments and private actors, or between countries over accounting obligations and corresponding adjustments. "Rather than waiting for disputes to arise, Kenya has focused on building governance systems designed to reduce uncertainty before conflicts emerge," said Ndichu. "These include carbon market regulations, stakeholder consultation requirements, grievance procedures, and the development of a national carbon registry to improve transparency around projects and transactions." The need for institutional certainty was similarly echoed by Chris Canavan, CEO of the Global Carbon Market Utility, who compared carbon markets to sovereign bond markets. "In sovereign debt markets, investors operate within clearly defined legal frameworks that establish ownership rights, dispute procedures, and applicable jurisdictions in advance," said Canavan. "Risk still exists, but participants understand how those risks will be handled if disputes occur." Carbon markets, he argued, increasingly require similar legal infrastructure to attract long-term institutional investment. Overall, the panelists agreed that mature markets are not defined by the absence of risk; rather, they are defined by the presence of institutions capable of managing those risks effectively. The growing focus on insurance structures, arbitration frameworks, registry infrastructure, credit ratings, and governance systems is a sign that carbon markets are beginning to function like the global financial 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/agriculture/052526-animal-protein-trade-realigns-amid-china-quotas-asf-and-tariff-shifts</link><description>The animal protein trade is realigning in 2026 due to import restrictions, disease outbreaks, rising demand and supplier shifts.&amp;#xd;&amp;#xa;Brazil expects increased demand for poultry from China as it reopens its market.&amp;#xd;&amp;#xa;The beef trade focuses on China, which imposes import quotas for 2026 and a 55% tariff on any excess.&amp;#xd;&amp;#xa;African swine fever in Europe is impacting pork supply, with the EU being the worldâ&amp;#x80;&amp;#x99;s second-largest pork exporter.&amp;#xd;&amp;#xa;After the US Supreme Court struck down country-specific tariffs, I</description><title>INTERACTIVE: Animal protein trade realigns amid China quotas, ASF and tariff shifts</title><pubDate>24 May 2026 18:30:00 GMT</pubDate><author><name>Sampad Nandy</name></author><content><![CDATA[ May 25, 2026 INTERACTIVE: Animal protein trade realigns amid China quotas, ASF and tariff shifts By Sampad Nandy Getting your Trinity Audio player ready... The animal protein trade is realigning in 2026 due to import restrictions, disease outbreaks, rising demand and supplier shifts. Brazil expects increased demand for poultry from China as it reopens its market. The beef trade focuses on China, which imposes import quotas for 2026 and a 55% tariff on any excess. African swine fever in Europe is impacting pork supply, with the EU being the worldâs second-largest pork exporter. After the US Supreme Court struck down country-specific tariffs, India and Ecuador compete to expand their shrimp exports to the US, the second-largest importer. Animal protein trade realigns amid China quotas, ASF and tariff shifts Related content: Animal disease outbreaks threaten protein supply chains as global investment gap widens, industry warns Australian beef exporters adapt as China caps imports, shifts global trade flows ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/052226-dutch-draft-blending-obligations-to-allow-biomethane-imports-from-eu-countries</link><description>The long-awaited Green Gas Blending Obligation Act has been submitted to the lower house of the Dutch parliament, Tweede Kamer, for official reading on May 26. The new bill, signed by Climate and Green Growth Minister Stientje van Veldhoven, was submitted May 21 and outlines the renewable gas blending obligations that Dutch suppliers must comply with. The rules require annual reductions in</description><title>Dutch draft blending obligations to allow biomethane imports from EU countries</title><pubDate>22 May 2026 14:58:54 GMT</pubDate><author><name>Irina Breilean</name></author><content><![CDATA[ Natural Gas, Agriculture, Energy Transition, Electric Power, Biofuels, Renewables May 22, 2026 Dutch draft blending obligations to allow biomethane imports from EU countries By Irina Breilean Editor: Rizwan Choudhury Getting your Trinity Audio player ready... HIGHLIGHTS New Dutch law introduces tradable GGE certificates EU biomethane imports meeting standards allowed Calculation method favors manure feedstocks The long-awaited Green Gas Blending Obligation Act has been submitted to the lower house of the Dutch parliament, Tweede Kamer, for official reading on May 26. The new bill, signed by Climate and Green Growth Minister Stientje van Veldhoven, was submitted May 21 and outlines the renewable gas blending obligations that Dutch suppliers must comply with. 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, before 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 Eur450/metric tons of CO2 equivalent. The GGE is derived from the already existing Guarantee of Origin. It represents a certain amount of CO2 equivalent reductions in chain emissions. Suppliers can create, buy, sell, save and surrender GGEs to meet their annual obligation. The Dutch Emission Authority, or Nederlandse Emissieautoriteit (NEa), the proposed implementing and supervisory body, will inform energy suppliers annually of the number of GGEs required to comply with the obligation. The draft law also allows imports of green gas from other EU member states, provided the imported green gas meets the same sustainability and verification requirements as domestic green gas. "In the longer term, it is clear that the Netherlands will not be able to produce enough green gas to meet its own needs," the legislative proposal said. "It is therefore also necessary to work on robust import chains, whereby green gas from other European countries, together with the scaling up of green gas production in the Netherlands, can contribute to the transition of the Dutch economy." This comes following earlier pushback from the European Commission in 2024. In a detailed, reasoned opinion, the Commission held that an earlier draft of the law, which prioritized domestic Dutch production, was contrary to Article 34 of the Treaty on the Functioning of the European Union (TFEU). Article 34 prohibits quantitative import restrictions and all measures having an equivalent effect to ensure the free movement of goods within the bloc. Compliance The government also proposed annual reporting timelines to be submitted to the NEa starting in 2027. The obligation must be calculated and submitted to the NEa no later than June 1; by July 1 at the latest, the parties must indicate whether they wish to exercise the buyout option. By Aug. 1, the NEa will write off the number of GGEs required to meet the blending obligation of the preceding calendar year. Following this process, by April 30, 2028, reports must be submitted to the NEa outlining the total amount of gas delivered and supplied in 2027. By June 1, 2028, the NEa will then inform suppliers about the market share and obligations for the previous year. "The amount of gas from renewable sources that must be supplied will be determined based on the energy supplier's market share," the Dutch government said. The legislation will also allow suppliers to carry over up to 10% of the total obligation into the next calendar year after this has been written off, promoting stable price formation. Avoided methane emissions are included in the calculation rules, in line with the Renewable Energy Directive. This would particularly favor manure feedstocks, as they can potentially lead to a significant reduction in methane and ammonia emissions. "Because the focus is on CO2 chain emission reduction rather than on the volume of green gas, it is expected that manure digestion will be used more frequently," the government said in its proposed legislation. Platts, part of S&amp;P Global Energy, last assessed spot Dutch unsubsidized, certified manure Guarantees of Origin at Eur135.925/megawatt-hour on May 21. Following official reading in parliament on May 26, the bill will be debated in a formal open session during a procedural meeting on June 2. 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/051226-heidelberg-to-supply-green-cement-for-major-wind-farm-project-in-bulgaria</link><description>Renewable energy developer CWP Europe has signed a preliminary agreement with Heidelberg Materials Devnya for carbon-neutral cement to construct a wind farm in Bulgaria, the companies said. The wind project represents an investment of over Eur300 million ($352 million) and is projected to be Bulgaria&amp;apos;s largest wind farm, according to CWP. Heidelberg Materials Devnya, the Bulgarian business unit of</description><title>Heidelberg to supply green cement for major wind farm project in Bulgaria</title><pubDate>12 May 2026 18:08:58 GMT</pubDate><author><name>Anthony Rizkala</name></author><content><![CDATA[ Electric Power, Energy Transition, Renewables May 12, 2026 Heidelberg to supply green cement for major wind farm project in Bulgaria By Anthony Rizkala Editor: Bill Montgomery Getting your Trinity Audio player ready... HIGHLIGHTS Eur300 mil project to use carbon-neutral cement for foundation structures Wind farm to supply clean power to Heidelberg's Bulgarian cement plant Renewable energy developer CWP Europe has signed a preliminary agreement with Heidelberg Materials Devnya for carbon-neutral cement to construct a wind farm in Bulgaria, the companies said. The wind project represents an investment of over Eur300 million ($352 million) and is projected to be Bulgaria's largest wind farm, according to CWP. Heidelberg Materials Devnya, the Bulgarian business unit of German-based Heidelberg Materials, will supply its carbon-neutral cement, known as EvoZero, for the project's foundation structures. "The partnership between CWP and Heidelberg Materials Devnya demonstrates how collaboration between the energy and industrial sectors can accelerate Bulgaria's decarbonisation and create additional jobs," CWP said in a statement May 11. EvoZero is the world's first carbon-neutral cement, according to Heidelberg. Once the wind farm is operational, it will supply a portion of its electricity output to Heidelberg's Devnya cement plant in Bulgaria, the companies said. "The partnership has the potential to create an effective circular economy model in which Heidelberg Materials' carbon-neutral cement is used to build the foundations of CWP's wind farm, the wind farm produces green electricity for the needs of the plant, and the plant in turn produces materials with an even lower carbon footprint," CWP said. Platts, part of S&amp;P Global Energy, assessed Platts CEMDEX at $55.50/mt FOB Turkey May 7, up 0.9% year over year. 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/051326-german-cabinet-approves-gas-plant-tender-heating-reform-draft-laws</link><description>Germany&amp;apos;s coalition government on May 13 approved a reform of the heating law as well as the new Electricity Supply Security and Capacity Act (StromVKG), paving the way to tender support for 9 GW of new gas-fired power plants this autumn. Approval of the two draft laws is a major step forward for energy minister Katherina Reiche, one year after taking over from Robert Habeck. The focus of the</description><title>German cabinet approves gas plant tender, heating reform draft laws</title><pubDate>13 May 2026 13:36:46 GMT</pubDate><author><name>Andreas Franke</name></author><content><![CDATA[ Natural Gas, Energy Transition, Electric Power, Hydrogen May 13, 2026 German cabinet approves gas plant tender, heating reform draft laws By Andreas Franke Editor: Jonathan Fox Getting your Trinity Audio player ready... HIGHLIGHTS StromVKG paves way for 9 GW gas plant tenders Capacity must be online by 2031 to replace coal Heating reform scraps 65% renewables quota Germany's coalition government on May 13 approved a reform of the heating law as well as the new Electricity Supply Security and Capacity Act (StromVKG), paving the way to tender support for 9 GW of new gas-fired power plants this autumn. Approval of the two draft laws is a major step forward for energy minister Katherina Reiche, one year after taking over from Robert Habeck. The focus of the heating law reform, now called the Building Modernization Act (GModG), is more pragmatism for gas-fired boilers that supply heat to about 56% of German flats, in addition to heating oil systems. "We are replacing a law that has unsettled many people with one that is based on trust, technological openness, and feasibility," Reiche said in a statement. "We are also abolishing the 65% renewables quota, mandatory consultations, and heating bans with bespoke solutions for homeowners and their heating choices." Germany's gas and hydrogen association said the reform paves the way for the use of green gases such as biomethane and hydrogen in the heat transition, emphasizing that the draft law creates additional options, particularly in existing buildings. However, it remains unclear how the green gas quota and the so-called bio-step model are intended to interact in practice from 2029, it said in a statement. Overall, it estimates that primarily due to building modernization, gas consumption in the building sector will be reduced by half by 2045, modeling remaining gas demand of about 120 TWh/year for the sector. Initial volume requirements from the green gas quota and the bio-step model can be met with current production capacities, while increases from 2030 will require investment to expand these capacities. "Meeting the further volume requirements at affordable prices is considered realistic," the association said. Gas plant tenders The Cabinet also approved the so-called gas plant tender law, which has been debated for years. A slightly different approach by the new coalition received preliminary state-aid approval from the European Commission in January, which had previously been seen as the main hurdle. The draft law, which requires parliamentary approval and final EU state aid approval, establishes two auctions for 4.5 GW of hydrogen-ready gas-fired plants this September and December. New plants have to be online by November 2031 to help with dispatchable generation capacity following coal and lignite plant closures around 2030, while grid operators already secured a so-called grid reserve of older hard-coal plants until winter 2031. Energy sector association BDEW called for final state aid approval from the European Commission to be secured before tenders launch. "If auctions proceed without EU clearance, bidders must be allowed to withdraw awarded contracts without financial penalties," it said in a statement. "New secured capacity is central so that our electricity supply remains reliable even in times of low feed-in from wind and solar," said BDEW chairwoman Kerstin Andreae. "For this capacity to be available in 2031, the schedule must be adhered to." Beyond the initial auctions, the draft law's long-term capacity auctions represent the first step toward making new secured capacity available on time, BDEW said. The group urged retention of the duration criterion, requiring facilities to be capable of feeding electricity into the grid for at least 10 consecutive hours after a maximum one-hour startup. BDEW warned that subsequent burdens from the grid fee reform process (AgNes) must not undermine the economics of already-awarded projects. The association said collateral requirements and penalties must be proportionate and not effectively exclude small and medium-sized market participants. "The StromVKG can become a central building block for security of supply," Andreae said. "For this, it must actually enable investments, limit costs and maintain a diversity of actors. Some of Germany's biggest power generators -- RWE, Uniper and EnBW, during this week's first-quarter calls called for a swift final approval of the StromVKG to allow the tenders to go ahead as planned. The three companies alone proposed more than 5 GW of projects linked to coal or lignite site closing over the coming years, with other generators like Leag, Steag and Onyx Power proposing similar projects at their former coal sites. Gas plant developers require state aid or similar guarantees as Berlin aims for a 80% share of renewables by 2030, with gas plants often only needed as backup. The so-called clean spark spread for an average 50% efficient gas unit for 2027 was pegged May 12 at minus Eur11.52/MWh, according to assessments by 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/ratings/en/regulatory/article/private-credit-fundamentals-remain-resilient-s101685515</link><description>This report does not constitute a rating action. Since the beginning of 2026, challenges facing borrowers in the direct lending market have grown. These include a wave of investor redemption requests for nontraded business development companies (BDCs), concerns for the software sector as investors continue to assess the impacts of potential AI disruption, and the war in the Middle East. These add to the macro and trade-policy uncertainties already confronting the market heading into 2026. These </description><title>Private Credit Fundamentals Remain Resilient</title><pubDate>21 May 2026 15:27:06 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/052126-ecosperity-week-asia-pacific-carbon-market-optimism-contrasts-with-eu-caution-vcmi</link><description>Asia-Pacific views climate action and carbon markets as an economic opportunity despite regulatory costs, contrary to the EU seeking delays in emissions regulations and being wary of aggression toward climate action amid competitiveness concerns, Mark Kenber, executive director of the Voluntary Carbon Markets Integrity Initiative, told Platts, part of S&amp;amp;P Global Energy, in an exclusive interview</description><title>ECOSPERITY WEEK: Asia-Pacific carbon market optimism contrasts with EU caution: VCMI</title><pubDate>21 May 2026 13:47:51 GMT</pubDate><author><name>Himanshu Chauhan</name></author><content><![CDATA[ Energy Transition, Carbon May 21, 2026 ECOSPERITY WEEK: Asia-Pacific carbon market optimism contrasts with EU caution: VCMI By Himanshu Chauhan Editor: Juan Tolentino Getting your Trinity Audio player ready... HIGHLIGHTS Asia-Pacific views climate action as opportunity despite regulatory costs VCMI's Scope 3 guidance complements SBTi Companies await government carbon guidance amid voluntary initiatives Asia-Pacific views climate action and carbon markets as an economic opportunity despite regulatory costs, contrary to the EU seeking delays in emissions regulations and being wary of aggression toward climate action amid competitiveness concerns, Mark Kenber, executive director of the Voluntary Carbon Markets Integrity Initiative, told Platts, part of S&amp;P Global Energy, in an exclusive interview during Ecosperity Week 2026 in Singapore. "It is quite astonishing to hear the level of energy and the genuine belief that addressing climate change and a green economy really is an opportunity. And almost every country (in Asia-Pacific) sees that in one way or another," Kenber said. In contrast, concerns about competitiveness and economic sluggishness have led some companies in Europe to seek delays in emissions regulations or additional allocations, amid the Middle East crisis and elevated energy costs, he said. Regional momentum in carbon markets The Coalition to Grow Carbon Markets, a government-led initiative co-chaired by Singapore, Kenya, and the UK, recently added Indonesia as a member. The coalition aims to provide guidance, regulation, incentives and consistency across countries on how companies should use, report and disclose carbon credits within their broader decarbonization strategies. "Indonesia was the most recent to join. Other countries in the region are talking about joining. They see an opportunity, whether it's in carbon markets, but more importantly, in clean energy and clean technology," Kenber said. He noted that China is one of the world's leaders in clean technology development, with significant technological advances across the Asia-Pacific region, alongside a real understanding of the impacts of climate change. VCMI complements SBTi's gap VCMI published Scope 3 action guidance in 2025, recognizing that many companies struggle to meet Scope 3 emissions reduction targets. "The gap between Scope 3 emissions and targets are roughly equivalent to Japan's 2022 emissions and is expected to grow fivefold, reaching twice the emissions of the EU by 2030," Kenber said. VCMI's approach complements SBTi by providing a pathway for companies that cannot meet their targets to use high-integrity carbon credits to bridge the gap while investing in future emissions reductions, rather than hoping for the best and missing targets in 2030, he added. Local standards ownership emerges An important shift occurring in the last few years is the development of carbon standards, rules and claims frameworks in countries through consultation with businesses and NGOs in the public domain, rather than being set primarily by NGOs based in Europe and North America, Kenber said. This local ownership makes standards much more palatable for companies and allows them to respond to local circumstances, he added. Singapore is developing a tiered claims framework that builds on VCMI's guidance but recognizes that VCMI's carbon-integrity claims might be achievable only by a small number of companies, Kenber said. Kenber added that VCMI is working with the Singapore Sustainable Finance Association to develop guidance for companies. Government clarity remains key Despite regional differences in attitudes, companies across all markets are waiting for government-led guidance on how to use carbon credits rather than relying solely on voluntary standards, as regulatory clarity remains the key barrier to unlocking corporate demand, Kenber said. VCMI conducted market research with companies in 20 countries last year and found that while companies still see carbon credit as an important part of their climate strategies, they want clear, consistent and stable guidance from governments. "Companies say, what we really want is for the government to tell us. At the end of the day, for all the voluntary initiatives like VCMI or SBTi, when governments say this is how it works, that's how it works," Kenber said. The Coalition to Grow Carbon Markets is a direct response to companies seeking clarity and certainty, aiming to provide consistent guidance across member countries. Kenber said VCMI works closely with the Integrity Council for the Voluntary Carbon Market, which focuses on supply-side integrity and VCMI covers demand-side integrity. VCMI's guidance explicitly recommends that companies use CCP-labeled credits from ICVCM. "We are very closely linked. We work very closely together and our guidance is supposed to be mutually supportive," Kenber said. While only a few have made public-facing carbon-integrity claims under VCMI's Claims Code, consulting firms report that several companies are following the guidance privately but view public claims as risky amid ongoing reputational concerns about carbon markets, Kenber said. According to Kenber, VCMI's basic guidance follows four steps: demonstrate good corporate climate citizenship with targets and inventory; show meaningful progress toward targets; buy high-integrity carbon credits; and disclose transparently. 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/051426-hormuz-crisis-exposes-structural-energy-flaw-pushes-electrification-case-etc</link><description>The closure of the Strait of Hormuz triggered a historic disruption to fossil fuel supplies, and should accelerate clean energy deployment, with governments and markets responding to disrupted oil and liquefied natural gas flows by fast-tracking renewable electricity, electric vehicles and heat pumps rather than locking in new fossil fuel infrastructure, the Energy Transitions Commission said in a</description><title>Hormuz crisis exposes structural energy flaw, pushes electrification case: ETC</title><pubDate>14 May 2026 23:10:12 GMT</pubDate><author><name>James Burgess</name></author><content><![CDATA[ Natural Gas, LNG, Crude Oil, Energy Transition, Renewables May 14, 2026 Hormuz crisis exposes structural energy flaw, pushes electrification case: ETC By James Burgess Editor: Giselle Rodriguez Getting your Trinity Audio player ready... HIGHLIGHTS ETC urges renewables over fossil lock-in Hormuz closure disrupts 18 million b/d oil flows 'Readily deployable' alternatives are key difference The closure of the Strait of Hormuz triggered a historic disruption to fossil fuel supplies, and should accelerate clean energy deployment, with governments and markets responding to disrupted oil and liquefied natural gas flows by fast-tracking renewable electricity, electric vehicles and heat pumps rather than locking in new fossil fuel infrastructure, the Energy Transitions Commission said in a report published May 15. The crisis has disrupted around 18 million b/d of oil supply and 20% of global LNG trade, or more than 110 Bcm/year, with 75% of the world's population living in fossil fuel-importing countries, the report said. If sustained, elevated prices could add $1 trillion-$2 trillion in annual energy costs globally, it said. "This is a reminder to governments -- both in Asia and in Europe -- that as long as we have fossil fuel-based economies, we are vulnerable to another political event," ETC co-chair Adair Turner told Platts, part of S&amp;P Global Energy, in an interview on May 15. "Four years ago, it was Russia-Ukraine. Now it's the Gulf. Who knows what the next one is." The ETC, a global coalition of leaders from across the energy landscape committed to achieving net-zero emissions by mid-century, said fossil fuel systems were "structurally vulnerable" because of their dependency on continuous extraction, trade and transport. "Supply is geographically concentrated and relies on a small number of critical transit routes, meaning that relatively localized disruptions can rapidly propagate into global economic shocks," it said. Renewable energy is inherently more secure, Turner said. "Clean energy systems are more distributed, more efficient and less exposed to the price shocks created by continuous dependence on traded fuels," he said. The ETS said stocks provided only a temporary buffer, were unevenly distributed and did not remove exposure to higher prices. As a result, governments should focus their efforts on boosting renewable deployment. "Accelerating the deployment of these technologies can reduce global oil demand by 20% and gas demand by more than 30% by 2035, insulating economies from the next shock," the report said. "Clean energy systems are more resilient because they change the physical and economic structure of energy supply," the report said, adding that decentralized energy supply alternatives were already available. "The key difference between this crisis and previous crises is the availability of readily deployable alternatives," the ETC said, contrasting the current price shock with the oil crisis of the 1970s. Chinese solar photovoltaic exports doubled in March 2026 compared with February, while 50 countries recorded all-time high solar import records, the report said. Electric vehicle registrations in the EU rose nearly 50% year over year in March, while EV searches in Australia surged 75%-80% in a single week and heat pump sales hit records in the UK, the ETC said. Around 70%-90% of clean energy costs are upfront capital, rather than fuel costs, it said. As such, while geopolitical disruptions can temporarily affect new projects, but not current energy consumption, it noted. "Faced with the latest fossil fuel supply crisis, governments, policymakers and businesses should accelerate the shift towards the more resilient and secure energy systems that clean technologies can deliver, while managing short-term distributional impacts and supply risks," it said. "The market is already signaling the answer," the ETC said. "Policy must not contradict it." Policy priorities Policy priorities should include accelerating renewable power deployment, electrifying road transport, heating and cooking, developing green fuels and fertilizers and improving energy efficiency across all sectors, it said. The group said oil and gas fields typically take 5-10 years to reach production. By contrast, rooftop solar and heat pumps can scale within months, while electric vehicles were already structurally reducing oil demand, it said. Alongside these measures, the ETC recommended the careful management of targeted fossil fuel subsidies, acknowledging that there could be a short-term increase in fuels such as coal to bridge the supply crunch, particularly in Asia. Such use should be time-limited and not come from new capacity, it said. New LNG commitments should be made only with robust methane standards and short-term contracts. In the EU, it said the Emissions Trading System structure should be reformed but not weakened, to preserve carbon pricing credibility. Platts, part of S&amp;P Global Energy, assessed nearest December EU ETS carbon allowances at Eur75.04/mt ($87.23/mt) on May 14. Meanwhile, the ETC warned against blanket fossil fuel subsidies, large-scale new upstream oil and gas or the weakening of 2030 and 2050 climate targets. "New fossil infrastructure now would lock in the next shock," the ETC said in a statement accompanying the report. Previous crises offered a stark warning that short-term fossil fuel subsidies were a "sticking plaster" rather than a long-term solution. "The 2026 Iran crisis is not an isolated event, but a clear manifestation of a structural vulnerability in the global energy system," it said. 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/2026/05/eroding-connections-expose-canada-ports-shippers-central-bank</link><description>Canadaâ&amp;#x80;&amp;#x99;s ports are less connected globally than a decade ago, exposing the countryâ&amp;#x80;&amp;#x99;s shippers to more supply chain risk, its central bank says.</description><title>Eroding connections expose Canadaâ&amp;#x80;&amp;#x99;s ports, shippers: central bank</title><pubDate>21 May 2026 12:00:00 GMT</pubDate><author><name>Michael Angell</name></author><content><![CDATA[ Blog â 21 May, 2026 Eroding connections expose Canadaâs ports, shippers: central bank By Michael Angell Canadaâs ports are less connected globally than a decade ago, exposing the countryâs shippers to more supply chain risk, its central bank says. The warning comes as the country pivots its trade relations away from the US amid plans to invest billions in its ports. The Bank of Canada (BOC), in a research report published last week, showed that the countryâs five largest ports have seen major declines in their connections to other global ports since 2016. The researchers used satellite data of container ship and car carrier transits to measure the number of unique destinations. That connectivity measure dropped 74% between 2016 and 2023, indicating âCanadian ports became relatively less central in global shipping networks compared with what they once were,â the BOCâs researchers said. âGlobal maritime shipping networks have been reshaped in ways that have reduced Canadaâs relative connectivity and carrying capacity,â the bank said. âThis less-central role for the country could mean greater exposure to supply chain disruptions that could increase the cost of doing business.â The report was released as BOC Governor Tiff Macklem testified before a Canadian Senate banking committee last Wednesday. He said the country needs to invest more in its transportation infrastructure, citing the ability of Southern California ports to handle much larger vessels than those calling Canada. The Bank of Canada researchers said some of the countryâs declining port connectivity may stem from fewer, larger container ships than those measured in 2016. More of those larger ships, though, head to US West Coast ports, with imports into Canada having to absorb the extra cost of surface transportation from Southern California. âMany imports coming on larger ships from southeast Asia, for example, must first travel to and be processed through the Port of Los Angeles before being shipped to Canada by train or truck,â the BOC report said. The Port of Vancouver only sees about half or fewer of the large container ships on the trans-Pacific than the Southern California ports, according to data from Sea-web, a sister product of the Journal of Commerce within S&amp;P Global. In the last 12 months, ships over 11,000 TEUs in capacity made 410 calls to the Port of Los Angeles and 308 calls to Long Beach, Sea-web data shows. Vancouver saw 143 such calls over the same time. Multiple projects planned Canadaâs government wants to reduce that dependency on Southern California ports, along with the US overall as a trading partner. Prime Minister Mark Carney has pledged some C$5 billion in federal funding for trade infrastructure projects, including ports. The biggest pieces of that will be the Contrecoeur marine terminal at the Port of Montreal, which has started initial work on the C$1.6 billion project. Quebec may become home to another marine terminal after local operator QSL received preliminary approval from Canadaâs customs agency for receiving international freight at the proposed site at Quebec City. DP World Canada has also unveiled a new ultra-large container ship berth at its Port Saint John terminal. On the countryâs West Coast, the Vancouver Fraser Port Authority and Global Container Terminals have pledged to work together on studying development of the proposed 2.4 million-TEU Roberts Bank marine terminal. Outside of infrastructure, Canada also wants to turn the tide on the longshore labor disruption that has plagued its ports. Canadaâs parliament could take up negotiations in the coming weeks on how to reform the countryâs labor laws. Changes to those laws could come ahead of the 2027 expiration of the longshore labor contract at Vancouver. This article was originally published in the Journal of Commerce on May 13, 2026. Inland26 registration is now open! Join us in Chicago from September 28â30 for three days of sessions and networking focused on intermodal rail, trucking, and drayage across both domestic and international supply chains. Inland26 brings together industry leaders to examine the key factors shaping North American surface transportation. Register today ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/european-and-north-american-private-credit-and-middle-market-comparison-q1-2026-s101686879</link><description>The creation of European middle-market collateralized loan obligations (CLOs) is still in its infancy, with only four vehicles priced (and one being marketed this month), trailing the more mature U.S. market.</description><title>European And North American Private Credit And Middle-Market Comparison Q1 2026</title><pubDate>20 May 2026 18:46:31 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/agriculture/052026-strait-of-hormuz-closure-may-trigger-severe-food-price-crisis-fao</link><description>The Strait of Hormuz closure could trigger a &amp;quot;severe&amp;quot; global food price crisis in the next six to 12 months, the UN Food and Agriculture Organization said in a statement May 20. The Strait of Hormuz, a critical artery for global energy and fertilizer trade, handles about 30% of global urea exports and significant volumes of ammonia and phosphates, making it a key chokepoint for agricultural</description><title>Strait of Hormuz closure may trigger &amp;apos;severe&amp;apos; food price crisis: FAO</title><pubDate>20 May 2026 13:51:00 GMT</pubDate><author><name>Sampad Nandy</name><name>Samyak Pandey</name></author><content><![CDATA[ Fertilizers, Chemicals, Energy Transition, Renewables May 20, 2026 Strait of Hormuz closure may trigger âsevereâ food price crisis: FAO By Sampad Nandy and Samyak Pandey Editor: Debiprasad Nayak Getting your Trinity Audio player ready... HIGHLIGHTS FAO Food Price Index up 1.6% MOM in April Avoid export restrictions on energy, fertilizers: FAO Onset of El NiÃ±o may further worsen the crisis: FAO The Strait of Hormuz closure could trigger a "severe" global food price crisis in the next six to 12 months, the UN Food and Agriculture Organization said in a statement May 20. The Strait of Hormuz, a critical artery for global energy and fertilizer trade, handles about 30% of global urea exports and significant volumes of ammonia and phosphates, making it a key chokepoint for agricultural inputs, according to the FAO. Decisions taken now by farmers and governments on fertilizer use, imports, financing and crop choices will determine food prices over the next six to 12 months, the FAO said. The FAO suggested policies to tackle the potential food price crisis. It recommended to look for alternative corridors to bypass the strait and urged countries to avoid imposing export limits on energy, fertilizers and inputs as near-term measures. It also suggested limiting biofuel consumption to ensure stable food supply in the medium term and building stable regional reserves to absorb food supply shortages in the long term, the FAO said in its statement. "Start seriously thinking about how to increase the absorption capacity of countries, how to increase their resilience to this choke, so that we start to minimize the potential impacts," FAO Chief Economist Maximo Torero said May 20. The latest FAO Food Price Index rose for the third consecutive month in April, averaging 130.7 points, up 1.6% from its revised level in March and 2% higher year over year. The food supply situation could worsen with the onset of El NiÃ±o, which is expected to bring droughts and disrupt rainfall and temperature patterns across several regions, the FAO said. FAO projections show that global fertilizer prices could rise 15%-20% in the first half of 2026 if the crisis persists. S&amp;P Global Energy CERA forecasts that the Middle East will export 10 million mt of nitrogen in 2026, accounting for 23.4% of global outflows. CERA projects that the Middle East will export 23 million mt of urea this year, accounting for 38.5% of global outflows. Platts, part of S&amp;P Global Energy, assessed chicken breast CIF Middle East at $2,950/mt on May 20, down $15/mt day over day. 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-when-nature-sends-the-bill-austrias-disaster-fund-shields-states-from-rising-costs-s101671043</link><description>This report does not constitute a rating action. Floods triggered by Storm Boris in 2024 were Austria&amp;apos;s most damaging weather event in at least two decades, highlighting the growing financial toll of climate hazards. Assessing how physical climate hazards affect stateâ&amp;#x80;&amp;#x99;s creditworthiness requires an understanding of climate risk exposure and the fiscal responsibilities across levels of government for disaster-related costs. S&amp;amp;P Global Ratingsâ&amp;#x80;&amp;#x99; analysis reveals a complex interplay between fede</description><title>Sustainability Insights: When Nature Sends The Bill: Austriaâ&amp;#x80;&amp;#x99;s Disaster Fund Shields States From Rising Costs</title><pubDate>21 May 2026 08:44:12 GMT</pubDate></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/industry-report-card-solar-and-wind-performance-beyond-resource-availability-emerging-threats-to-expectations-s101681175</link><description>This report does not constitute a rating action. Chart 1 S&amp;amp;P Global Ratings has affirmed ratings on most wind (89%) and solar (77%) assets since March 6, 2025, and our outlooks are largely stable in the renewable energy sector. Managing risks of an inability to store and or fully transmit this power curtailed power prices or turned them negative remains a key factor. (This report does not include hybrid solar and wind entities). A decline in actual solar generation versus P90 expectations is an </description><title>Industry Report Card: Solar And Wind Performance: Beyond Resource Availability, Emerging Threats To Expectations</title><pubDate>20 May 2026 17:16:34 GMT</pubDate></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/2026/03/us-israel-iran-war-provokes-shipping-lane-shifts</link><description>Global supply networks may feel the impact through a mixture of energy market disruptions, airfreight challenges and container freight shipping network interruptions.</description><title>US-Israel Iran war provokes shipping lane shifts</title><pubDate>03 March 2026 17:10:00 GMT</pubDate><author><name>Ines Nastali</name><name>Chris Rogers</name><name>Vania Alvarez Murakami</name><name>Eric Oak</name></author><content><![CDATA[ Research â Mar 03, 2026 US-Israel Iran war provokes shipping lane shifts By Ines Nastali, Chris Rogers, Vania Alvarez Murakami, and Eric Oak The US and Israel on Feb. 28 launched a large-scale, coordinated air campaign against Iran, striking a broad range of leadership, military, security and nuclear targets. A forced government change is now a key objective according to S&amp;P Global Market Intelligence country risk analysts. Global supply networks may feel the impact through a mixture of energy market disruptions, airfreight challenges and container freight shipping network interruptions. In the case of energy, shipping via the Strait of Hormuz needs to continue; flows of LNG may be disrupted as well as crude oil. Energy supply chain disruption Absent an extended closure of the Strait, or the destruction of liquefaction assets, the impact is unlikely to be long term in nature. The Islamic Revolution Guard Corps (IRGC) is likely to expand targeting of critical Gulf energy infrastructure if US and Israeli strikes target Iranian critical national infrastructure and major crude export terminals. Air freight disruption Global air freight networks face challenges from the halt to flights through many of the regional ports, including the hubs of Doha and Dubai. These hubs handle around 2.6 million metric tons and 2.2 million metric tons of airfreight respectively, or around 4.0% of the total global airfreight volumes. The ability of air freight networks to adapt is partly limited by aircraft flight ranges, though networks can rapidly adapt as was shown during the pandemic. Container shipping disruption Continued discussions on these events are taking place at TPM 26 this week. join the conversation. Container shipping faces challenges to both local actions in the Strait of Hormuz and the wider region through shipping via the Red Sea. Local actions in the Strait of Hormuz impact key shipping hubs for container freight, including Jebel Ali in Dubai, as we previously identified at the time of June 2025 conflict. Container lines are also redirecting shipping away from the Red Sea once more. CMA CGM SA has ordered all vessels in the Gulf to proceed to shelter and AP Moeller Maersk A/S has rerouted vessels bound for the Red Sea around the Cape. Want to understand the broader story? Connect with us to learn more Learn More ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/2026/04/hormuz-closure-project-logistics-supply-chain</link><description>The near-total closure of the Strait of Hormuz amid the war in the Middle East will haunt global breakbulk and project markets, experts say.</description><title>Hormuz closure triggers â&amp;#x80;&amp;#x98;havocâ&amp;#x80;&amp;#x99; for project logistics supply chain</title><pubDate>24 April 2026 12:00:00 GMT</pubDate><author><name>Carly Fields</name></author><content><![CDATA[ BLOG â Apr 24, 2026 Hormuz closure triggers âhavocâ for project logistics supply chain By Carly Fields The near-total closure of the Strait of Hormuz amid the war in the Middle East will haunt global breakbulk and project markets long after the final missiles are fired, sector specialists say. Speaking during a March 26 Journal of Commerce webcast, JosÃ© Enrique Sevilla-Macip, senior research analyst for Latin America Country Risk at S&amp;P Global Market Intelligence, said there had been a 97% decrease in transits across the Strait of Hormuz over the past 25 days, noting that on March 25, for the first time since the conflict began, not a single vessel crossed the waterway. The paralysis is triggering a shift from initial price shocks to actual physical shortages of fuel and goods. On the ground, the logistics of moving breakbulk and project cargo goods has become a balancing act of cancellations and rerouting. Marc Cowie, CEO for North America at project cargo forwarder Trans Global Projects (TGP), said that many carriers are refusing to even quote for cargo entering the war region due to skyrocketing insurance premiums. The disruption is also creating a âlag impactâ that will persist for months. âThere will undoubtedly be ships out of position, cargo out of position, and thereâs going to be a knock-on effect,â Cowie said on the webcast. âItâs going to take some time to get back to normality.â For panelist Christian Ohlrich, global director for logistics at energy storage products manufacturer Fluence Energy, the crisis is manifesting most acutely in the energy sector. He described the âfuel shockâ as a primary concern, with bunker supplies depleting rapidly, particularly in Asia. This has led to a chaotic environment for manufacturing and project execution. âItâs creating quite some havoc,â Ohlrich said. âItâs crunching schedules. Itâs increasing costs.â He noted that while larger projects can still attract the necessary multipurpose vessels, smaller, less âenticingâ shipments are being delayed by weeks. That is not, however, stopping Fluenceâs project operations. âWe have plenty of buffers,â Ohlrich said. âIâm still making all my commitments. Itâs just changing the flow of project execution.â This includes changing internal team arrangements to meet the sequence of a project. âItâs an inconvenience rather than a hindrance,â he said. Oil prices expected to remain elevated The bunker fuel shortage is unlikely to ease in the short term. Sevilla-Macip expects oil prices to remain above $100 per barrel for at least the next month, although he holds out hope they could return to $60 by year-end if hostilities cease soon. However, the path to peace is cluttered with âsignpostsâ of further escalation, he said. These include potential Iranian attacks on US aircraft, the involvement of Tehran-backed Houthi militants in the Bab-el-Mandeb Strait, or the targeting of critical civilian infrastructure such as desalination plants. In the face of this volatility, the advice from project shippers and forwarders is a mix of tactical flexibility and rigorous planning. TGPâs Cowie urged shippers to work in close partnership with forwarders to find alternative routes or modes, such as trucking cargo across the Arabian Peninsula to safer ports. âWe have to remain flexible, remain calm,â Cowie said. âLogistics is about challenges. It is about overcoming those challenges.â Ohlrich echoed that, stressing the need for better foresight. âTighten up your planning and forecasting as much as possible,â he advised the webcast. âThe better you can plan ahead, especially in situations where you see these kinds of disruptions, the better.â This article was originally published in the Journal of Commerce on March 30, 2026. Subscribe to JOC.com Learn more about our data and insights Click Here ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/2026/02/red-sea-shipping-reopens</link><description>Red Sea shipping resumes amid reduced Houthi attacks, but renewed threats create uncertainty for shippers. Capacity increases may impact freight rates.</description><title>Red Sea shipping reopens, but renewed Houthi threats keep route uncertainty high</title><pubDate>20 February 2026 14:10:00 GMT</pubDate><author><name>Ines Nastali</name></author><content><![CDATA[ Research â Feb 20, 2026 Red Sea shipping reopens, but renewed Houthi threats keep route uncertainty high By Ines Nastali Container carriers are now restarting services via the Red Sea amid a continued reduction in Houthi attacks on maritime shipping, according to reports. One of the routes connects India via the Middle East with the US operated by AP Moeller Maersk, confirming earlier reports that Indian shippers will benefit from a service for reefer products. To benefit from increased traffic, Red Sea Container Terminals opened Egyptâs first semiautomated facility at Sokhna Port near the southern entrance to the Suez Canal in mid-January 2026, the Journal of Commerce reports. Sending more vessels through the Suez Canal might present a downward pressure point on freight rates as capacity is freed from the longer Cape of Good Hope diversion. While these developments might mean more capacity going through the Suez Canal in the coming months, the situation could easily change if the Houthis resume their attacks. An indicator of the volatility of the situation is CMA CGM SAâs announcement that some of its Asia-Europe services (FAL1, FAL3 and MEX) that went through the Suez Canal in 2025 will go back to transiting via the Cape of Good Hope, as a result of a âcomplex and uncertain international context,â adding to the uncertainty that shippers are facing when planning journey times and amid renewed threats of attacks by the Houthis in January 2026. The share of east-to-west shipments via the canal remains at 18.7%, close to its two-year average and well below the pre-disruption level of about 80%. According to Market Intelligence analysis, there remains a severe risk of attacks on vessels in transit in the one-year outlook if, as is likely, the ceasefire between Hamas and Israel breaks down permanently. If those attacks resume, the risk for vessels is likely to remain highest closest to, and inside, Yemeni territorial waters in areas controlled by the Houthi, particularly around Hodeidah where the Houthi likely maintains a significant arsenal of anti-ship cruise missiles, uncrewed surface vessels (USV) and uncrewed underwater vehicles (UUV). All Houthi attack incidents using USVs have been conducted within a 70-nm radius of Hodeidah. The Houthis have been using the period since the announcement of a ceasefire to rearm and increase weapons shipments via Iran and the Horn of Africa and rebuild port infrastructure and facilities around Ras Isa and Hodeidah, including new jetties and artificial island facilities to support tanker and cargo ships. Those were damaged in Israeli and US airstrikes. This aligns with a similar tactical pause in attack activity that the group adopted during the previous ceasefire in Gaza from Jan. 19âMarch 16, 2025. Egypt opens new semiautomated Red Sea terminal as Suez traffic grows Learn More ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/podcasts/energy-evolution/051926-how-the-war-in-iran-is-accelerating-asias-energy-transformation</link><description>In this episode, host Eklavya Gupte explores how the war in the Middle East has exposed Asia&amp;apos;s deep reliance on fossil fuels while also accelerating the region&amp;apos;s energy transition. Ruchira Singh, energy transition editor at Platts, part of S&amp;amp;P Global Energy, speaks with Nobuo Tanaka, chair of the steering committee at the Innovation for Cool Earth Forum and former executive director of the</description><title>How the war in Iran is accelerating Asia&amp;apos;s energy transformation</title><pubDate>19 May 2026 16:36:12 GMT</pubDate><author><name>Eklavya Gupte</name><name>Ruchira Singh</name></author><content><![CDATA[ Crude Oil, Natural Gas, LNG, Energy Transition, Renewables, Hydrogen May 19, 2026 How the war in Iran is accelerating Asia's energy transformation Featuring Eklavya Gupte and Ruchira Singh HIGHLIGHTS War exposes Asia's fossil fuel reliance Crisis accelerates region's energy shift EV and hydrogen adoption set to rise In this episode, host Eklavya Gupte explores how the war in the Middle East has exposed Asia's deep reliance on fossil fuels while also accelerating the region's energy transition. Ruchira Singh, energy transition editor at Platts, part of S&amp;P Global Energy, speaks with Nobuo Tanaka, chair of the steering committee at the Innovation for Cool Earth Forum and former executive director of the International Energy Agency, about the emerging dynamics between petrostates and electrostates, and where Asia stands on the threshold of its energy future. Echoing the 1970s oil shocks that gave rise to the LNG market, Tanaka believes this crisis will spark another tectonic shift, elevating renewables to the mainstream and fast-track Asia's electrification. From faster electric vehicle adoption to expanding low-carbon hydrogen trade and strengthened regional collaboration, Asia is poised to respond with a decisive shift toward cleaner, more resilient energy systems, he says. 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/051526-world-steel-review-cbams-article-6-embrace-comes-with-strings-and-forms-attached</link><description>The European Commission&amp;apos;s draft rules on recognizing third-country carbon pricing under the bloc&amp;apos;s Carbon Border Adjustment Mechanism represent a pragmatic but tightly controlled opening that could accelerate investment in Article 6 of the Paris Agreement while creating new compliance challenges. The widely anticipated implementing regulation, published May 13 and open for consultation until June</description><title>CBAM&amp;apos;s Article 6 embrace comes with strings and forms attached</title><pubDate>15 May 2026 17:34:38 GMT</pubDate><author><name>Staff </name></author><content><![CDATA[ Energy Transition, Emissions, Carbon May 15, 2026 CBAM's Article 6 embrace comes with strings and forms attached By Staff Editor: Richard Rubin Getting your Trinity Audio player ready... HIGHLIGHTS Draft rules could spark investment in Article 6 trade Importers face mounting paperwork to claim carbon price cuts Article 6 credits capped at 10% of emissions The European Commission's draft rules on recognizing third-country carbon pricing under the bloc's Carbon Border Adjustment Mechanism represent a pragmatic but tightly controlled opening that could accelerate investment in Article 6 of the Paris Agreement while creating new compliance challenges. The widely anticipated implementing regulation, published May 13 and open for consultation until June 10, lays out detailed methodologies for how carbon prices paid abroad translate into reductions in CBAM certificate obligations. "It creates a real financial incentive to put a credible domestic carbon price in place," Adam Hearne, CEO at CarbonChain, told Platts, part of S&amp;P Global Energy. "Companies that already pay a carbon price, or buy qualifying credits, can lower their effective CBAM cost, making their goods more competitive in the EU market. This tilts the playing field towards countries that are building or linking carbon markets." Under the world's first carbon border tax mechanism, importers of carbon-intensive goods into the EU from six covered sectors -- aluminum, cement, electricity, fertilizers, iron and steel, and hydrogen -- are now liable for their emissions. Demand signals The draft's design is deliberately restrictive on international credits. Only carbon credits authorized under Articles 6.2 or 6.4 of the Paris Agreement would qualify for CBAM liability reductions, and their use would be capped at 10% of emissions covered under qualifying third-country carbon pricing mechanisms. This structure amounts to a "compliance-adjacent demand signal for authorization and tracking-ready units, potentially supporting investment in Article 6 market infrastructure," said Eszter Bencsik, voluntary carbon markets analyst at S&amp;P Global Energy Horizons. The EU's CBAM started its definitive phase on Jan. 1, 2026, but importers will only be able to purchase CBAM certificates starting in February 2027 to cover the emissions embedded in their imports for 2026, giving businesses more time to adapt to this carbon pricing mechanism. Dan Maleski, a senior environmental markets adviser and CBAM lead at Redshaw Advisors, believes the likelihood of international Article 6 credits being used under CBAM is likely to remain relatively limited. "The implementing act is very clear that any recognized carbon cost must be mandated and legally required, rather than the result of a voluntary purchase," Maleski told Platts. "In principle, this significantly limits the scope for international credits, as host countries would effectively need to forgo domestic revenue streams. Out of the 30-plus active emissions trading systems globally, only South Korea currently permits the use of international credits within its ETS, and even then under very strict limitations and conditions, Maleski added. The EU's CBAM works alongside the EU Emissions Trading System to prevent carbon leakage by imposing carbon pricing on imports as Brussels phases out free allowances for domestic producers. Carbon permits in Europe are currently almost eight times more expensive than compliance prices in China, the world's industrial powerhouse. Platts assessed EU Allowances for December 2026 at Eur75.04/mtCO2e ($87.39/mtCO2e) on May 14. This compares with China's compliance emission allowance, which was valued at Yuan 80.06/mtCO2e ($11.76/mtCO2e) on May 8, according to the Shanghai Environment and Energy Exchange. Compliance burden These rules, however, add a significant administrative burden for operators seeking to claim carbon price reductions, market participants cautioned. Operators will need to submit additional reports on carbon price reductions, on top of monitoring and verification plans and carbon accounting rules they already face, according to Pauline Miquel, policy and research lead at CBAM consultancy CBAMBOO. "This is a lot more work to be able to let an importer forecast their cost because all of this is the basis for the importer's cost modeling," Miquel said. "And without this, it's almost impossible for an EU importer to understand how much they're going to pay in CBAM liability." They will also need to calculate how the price paid translates into embedded emissions at the product level, she added. The lack of accredited verifiers presents a further hurdle. If operators choose to use verified emissions rather than default values, "it's going to make it very difficult to have all of this ready for 2027," Miquel said. But many believe the explicit recognition of Article 6 credits, even in limited form, demonstrates the EU wants to support the Paris Agreement's international carbon market mechanisms, with the 10% cap designed to prevent over-reliance on offsets and to push real domestic decarbonization. This could drive increased investment in third-country carbon pricing infrastructure, Article 6 credit supply, and verifier and accreditation services over the next 12-24 months, Hearne said. A US-based carbon market analyst said the proposal reflects a broader positive trend of the EU being more flexible and open to carbon credits and recognizing the positive effects of carbon projects, pointing to similar developments in the Corporate Sustainability Reporting Directive. Domestic vs international credits The proposal could also reinforce a price premium for credits that can be evidenced through UN-grade accounting, she added, while laying foundations for greater integration of Article 6-aligned credits into other carbon pricing frameworks. "International credits face the highest integrity gateway -- Article 6 authorization plus a quantitative cap -- while domestically issued credits, including those linked to mitigation abroad, could be recognized without an EU-level integrity screen or usage limit," Bencsik said. This bifurcation risks an uneven playing field, she noted. Exporters under regimes with permissive domestic crediting rules may be able to evidence a higher carbon price effectively paid, and therefore secure larger CBAM reductions, than peers reliant on internationally transferred units constrained by Article 6 rules. The proposal's practical impact will depend heavily on implementation details, especially administrative burden, certification and verification robustness, and interaction with rebates or other forms of compensation. A further dynamic to watch is pricing behavior in domestic credit markets. "Because domestic credits reduce CBAM obligations only insofar as they contribute to an evidenced carbon price effectively paid, some jurisdictions could face incentives to support higher domestic credit prices or tighter supply to retain compliance value domestically rather than see larger net financial outflows via CBAM certificate surrender," Bencsik 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/blog/energy-transition/052026-et-highlights-hormuz-electrification-article-six-cmab-singapore-carbon</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: Hormuz crisis pushes electrification, Brussels eyes Article 6 under CBAM, Singapore carries forward unused carbon offset</title><pubDate>19 May 2026 20:05:00 GMT</pubDate><author><name>Staff </name></author><content><![CDATA[ Energy Transition, Renewables, Emissions, Carbon May 20, 2026 ET Highlights: Hormuz crisis pushes electrification, Brussels eyes Article 6 under CBAM, Singapore carries forward unused carbon offset 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 Hormuz crisis exposes structural energy flaw, pushes electrification case: ETC The closure of the Strait of Hormuz triggered a historic disruption to fossil fuel supplies and should accelerate clean energy deployment, with governments and markets responding to disrupted oil and liquefied natural gas flows by fast-tracking renewable electricity, electric vehicles and heat pumps rather than locking in new fossil fuel infrastructure, according to the Energy Transitions Commission. The crisis has disrupted around 18 million b/d of oil supply and 20% of global LNG trade, or more than 110 Bcm/year, with 75% of the world's population living in fossil fuel-importing countries, the report said. If sustained, elevated prices could add $1 trillion-$2 trillion in annual energy costs globally, it said. "This is a reminder to governments -- both in Asia and in Europe -- that as long as we have fossil fuel-based economies, we are vulnerable to another political event," ETC co-chair Adair Turner told Platts, part of S&amp;P Global Energy, in an interview. "Four years ago, it was Russia-Ukraine. Now it's the Gulf. Who knows what the next one is." The ETC, a global coalition of leaders from across the energy landscape committed to achieving net-zero emissions by mid-century, said fossil fuel systems were "structurally vulnerable" because of their dependency on continuous extraction, trade and transport. Benchmark of the Week Eur75.04/mt ($87.23/mt) Platts-assessed, nearest December EU ETS carbon allowances May 14. Explore Platts Energy Transition Price Assessments Editor's Picks: Free and premium content SPGlobal.com Brussels opens door to limited use of Article 6 credits under CBAM Companies importing carbon-intensive goods into the EU could use international carbon credits to lower their Carbon Border Adjustment Mechanism costs under draft rules published by the European Commission, provided the credits meet Paris Agreement standards and represent no more than 10% of the emissions from facilities where the goods were produced. The Commission published the draft implementing regulation on third-country carbon price recognition under CBAM, with the guidance now open for public consultation until June 10. Australia shortlists renewable hydrogen projects for funding amid budget cuts The Australian Renewable Energy Agency has shortlisted seven renewable hydrogen projects for the second round of the Hydrogen Headstart program, according to a government announcement, a day after spending cuts to the flagship initiative were announced. ARENA has invited the projects to submit full applications for funding from the program, which received a revised allocation of A$1 billion ($660 million) in the 2026-27 (July-June) federal budget announced on May 12, ARENA said. Renewable hydrogen is complex, capital-intensive industry and takes time, but it is a critical enabler of industrial decarbonization, particularly for hard-to-abate sectors, ARENA said. Canadian Solar managing 'solar downturn' that has lasted 'longer than expected' Canadian Solar is focused on key strategic markets as solar energy production continues to experience challenges, though its battery storage business is attracting greater interest. The solar downturn has lasted longer than expected, according to Shawn Qu, Canadian Solar's executive chairman and chief technology officer. During the company's first-quarter earnings call, Qu said the company has refocused on strategic markets, noting the creation of CS PowerTech in December 2025, which is helping it reshore US manufacturing. Canadian Solar shipped 2.5 gigawatts of solar modules and 2.1 gigawatt-hours of storage capacity in the first quarter, above guidance. S&amp;P Global Energy Core Singapore allows carbon tax companies to roll over 2025 offset quota Singapore will allow companies liable for the carbon tax to carry forward their unused International Carbon Credit offset quota from emissions years 2025 to 2026, the National Environment Agency and Ministry of Sustainability and the Environment said. The one-year rollover is intended as a "transitional measure" to give international carbon markets under Article 6 of the Paris Agreement more time to mature and for more ICCs to become available, according to the statement. The move is largely anticipated by the market, though many sources expect the official announcement to be made in June, as in the previous year. Major UK construction project replaces diesel with hydrogen at no additional cost The Lower Thames Crossing infrastructure project in the UK is on target to slash CO2 emissions during the construction phase by replacing diesel with battery-electric and hydrogen fuel-cell equipment, at no additional overall cost. The company will replace a total of 63 million liters of diesel via direct electrification, hydrogen fuel cell vehicles on the construction site and biofuels, the groupâs Supply Chain and Sustainability Director Katharina Ferguson said at a recent event at the Port of Tilbury, close to the construction site. The project has a contract to purchase 2,500 metric tons of renewable hydrogen from producer GeoPura over five years, displacing over 12 million liters of diesel per year. Solar generation likely to top coal output in ERCOT for first time in 2026: EIA Annual power generation from utility-scale solar resources will surpass coal-fired generation in the Electric Reliability Council of Texas market for the first time in 2026, the US Energy Information Administration forecasts, though an analysis of ERCOT data indicates that this occurred already the year before. The EIA, in its May Short-Term Energy Outlook, forecast that solar generation in ERCOT would reach roughly 78 billion kilowatt-hours this year, compared to about 60 billion kWh for coal-fired output. By comparison, ERCOTâs solar generation in 2025 was around 57.1 billion kWh while coal produced nearly 60 billion kWh, according to EIAâs report. ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/2026/05/the-most-wanted-exposure-lp-allocation-intent-and-unicorn-ai-deal-concentration-in-private-markets</link><description>Capital continues to flow decisively toward artificial intelligence (AI), with limited partners (LPs) signaling stronger allocation intent to the AI theme than to any other across private markets. </description><title>The Most Wanted Exposure: LP Allocation Intent and Unicorn AI Deal Concentration in Private Markets</title><pubDate>05 May 2026 04:00:00 GMT</pubDate><author><name>Ilja Hauerhof</name><name>Daniel J. Sandberg</name></author><content><![CDATA[ RESEARCH â MAY 2026 The Most Wanted Exposure LP Allocation Intent and Unicorn AI Deal Concentration in Private Markets By Ilja Hauerhof and Daniel J. Sandberg Capital is flooding into AI, with no end in sight. More than 75% of limited partners (LPs) say they plan to deploy capital into AI over the next 12 months, a stark contrast to blockchain at 18%. LP demand for AI exposure is broad-based: endowments, wealth managers and family offices are all leaning in. But scalable exposure is narrowing. Global AI investment jumped 115% year over year in 2025 to $235 billion from $109 billion, with 82% of the incremental dollars coming from rounds of at least $1 billion. AI is the most-wanted exposure in private markets. Itâs also becoming the hardest to access without paying up. Read The Full Research View This Paperâs Source Code Key findings: LPs continue to prioritize AI as a core private markets allocation, with intent holding firm across investor types despite constrained liquidity, indicatingâ¯a structural preference and long-term conviction in AIâs role in value creation.â¯ AI VC fundâ¯performanceâ¯reinforces LP preferences, but both capital inflows and returns are increasingly concentrated, withâ¯mostâ¯incremental capital absorbed by $1B+â¯transactions.â¯ Geographic imbalances are widening, with US markets capturing the bulk of AI deal activity while European and UK investors increasingly export capital cross border. One case-studyâ¯highlightsâ¯howâ¯dataâdrivenâ¯screeningâ¯enables opportunity discovery across geographies and beneath the unicorn deal tier.â¯ Explore the data used to conduct this research: Headcount Analytics The Headcount Analytics dataset provides an view of a company's workforce composition, trends, and metrics. Combine Headcount Analytics with S&amp;P Capital IQ Financials, Transactions data, Key Developments, and other sources for comprehensive analysis. Monthly updates since 2010 cover more than 5 million entities worldwide. Rounds of Funding The MI Transactions Rounds of Funding offering includes private placement data for public and private companies. This data set provides detailed information for each funding stage. The details provided on the structure of each funding round help users understand growth stages more clearly. Company Intelligence The Company Intelligence dataset contains a robust offering of qualitative data, including Topic Tags. Topic Tags are niche industry classifications with nuanced insights into a companyâs operations. Currently 300+ Topic Tags are available relating to 2 million+ private and public companies relevant to the surface. With Intelligence (part of S&amp;P Global) The With Intelligence platform is a comprehensive data and analytics solution designed to support professionals across the investment management and financial services sectors. It provides users with access to a wide range of tools and resources that facilitate informed decision-making and enhance operational efficiencies. Want to replicate this research? View Our Source Code WATCH WEBINAR REPLAY Track AI and Thematic Funding Flows in Private Markets Watch Now ]]></content></item><item><link>https://www.spglobal.com/ratings/en/regulatory/article/double-whammy-hits-global-auto-volumes-s101685388</link><description>This report does not constitute a rating action. Chart 1 Tough market conditions in China and U.S. tariffs have left a mark on the global auto industry. Both weigh on an already subdued outlook for 2026. As a result of the Middle East war, we have revised our volume forecasts (see table 1). While our ratings are unaffected for now, the auto industry remains on edge, as competitive pressures and high supply chain costs coincide with mounting inflation-driven demand risk. Trade tariffs and intensi</description><title>Double Whammy Hits Global Auto Volumes</title><pubDate>19 May 2026 14:08:51 GMT</pubDate></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/051826-xpansiv-ramps-up-hourly-energy-matching-as-tech-giants-demand-stricter-rules</link><description>Renewable marketplace and infrastructure provider Xpansiv is ramping up solutions for hourly matching in energy certifications, as it sees growing demand for stricter rules of origin from tech companies and other end users. &amp;quot;Some companies are seriously thinking about hourly matching of energy consumption and certificates, and generators want to be able to serve these customers,&amp;quot; senior vice</description><title>Xpansiv ramps up hourly energy matching as tech giants demand stricter rules</title><pubDate>18 May 2026 18:23:11 GMT</pubDate><author><name>Felipe Peroni</name><name>Sidney Dumars</name></author><content><![CDATA[ Energy Transition, Renewables, Carbon May 18, 2026 Xpansiv ramps up hourly energy matching as tech giants demand stricter rules By Felipe Peroni and Sidney Dumars Editor: Benjamin Morse Getting your Trinity Audio player ready... HIGHLIGHTS Xpansiv ramps up hourly matching solutions Tech firms drive demand for stricter rules Data barriers challenge smaller market players Renewable marketplace and infrastructure provider Xpansiv is ramping up solutions for hourly matching in energy certifications, as it sees growing demand for stricter rules of origin from tech companies and other end users. "Some companies are seriously thinking about hourly matching of energy consumption and certificates, and generators want to be able to serve these customers," senior vice president Russell Karas told Platts. The company, which runs a spot exchange and several other services for environmental commodities, including carbon credits and renewable energy certificates, has partnered with Granular Energy, a digital platform for managing energy portfolios, focused on building infrastructure for hourly matching of energy certificates. The first goal of the partnership, inked in late April, is to enable energy suppliers and buyers to time-stamp energy data with registry-issued energy attribute certificates (EAC) through a single platform. Demand for hourly matching is driven by tech companies and data centers and is also boosted by regulatory frameworks such as the EU's Carbon Border Adjustment Mechanism (CBAM) and voluntary protocols such as the Greenhouse Gas Protocol. "Generators are serving data centers and hyperscalers, who want optionality and flexibility for certifying energy," said Russell Karas, Senior Vice President at Xpansiv. "We need to be able to cater to these large tech companies, or you would be at a competitive disadvantage," he added. GHG Protocol changes The GHG Protocol board held a public consultation about a change to the scope 2 guidelines, from October 2025 to Jan. 31, 2026. One of the key proposals is that a company now certifying energy consumed in an entire year would be required to match all certificates on an hourly basis for its energy use to be considered renewable. The revision was considered necessary because the current scope 2 guidance was released in 2015. At that time, renewable energy claims were made in annual or, at best, monthly increments, with companies buying certificates that match their energy consumption for the period. The GHG Protocol board is expected to hold a second public consultation in 2026, according to sources, when more opinions will be heard. Meanwhile, the EU's CBAM entered its definitive phase on Jan. 1, 2026, and under its rules, companies can reduce their carbon liability through hourly matching claims. Bottlenecks While some consider hourly matching the next frontier for clean energy, others believe this requirement is excessively tight and might drive consumers away from decarbonization initiatives. "The shift toward hourly temporal matching, updates to the GHG Protocol, and navigation of US tax credits have created massive data management barriers, particularly for smaller players," a US renewable energy consultant said. At the same time, increased energy requirements from data centers are expected to drive REC prices up over the next few months. "Data centers are aggressively procuring renewable energy, taking whatever they can get," a consultant said. "At the same time, existing renewable assets are aging and retiring with fewer new builds in voluntary markets, creating supply constraints," he added. Platts' weekly assessment of New Jersey REC Class 1 contracts increased on May 14, with the 2025 vintage increasing 60 cents to $26.05/MWh and the 2027 vintage 45 cents to $25.75/MWh. The weekly assessment of Pennsylvania Tier 1 REC 2026 vintage rose 45 cents on the same day, to $24.25/MWh, while the 2027 vintage moved to $25.75/MWh, up by 85 cents. Handling the generated energy and certificates on an hourly basis requires significant data processing capacity, which small companies don't have. Other bottlenecks include fragmented workflows for issuing, trading and redeeming certificates, manual reconciliation in some cases and difficulties in exchanging data across different platforms. One common problem mentioned by market participants is the need to navigate multiple platforms, each requiring different logins to issue, transfer and redeem certificates. With increased requirements for granularity in energy certifications, the manpower needed to complete these tasks grows exponentially. Registries have also been adapting to hourly matching, but many expect the transition to be gradual due to its complexity. "The problem we are asked to tackle is how to take lots of data and distill it, to take all the rows and be able to condense it," Karas said. "Whenever you have new rules, there is always going to be a learning curve, but the idea of these rules is to drive investment where more renewables are needed." 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/2026/04/oil-price-shocks-are-testing-resilience-across-methodologies-among-sp-smallcap-600-indices</link><description>The war in the Middle East and the subsequent surge in oil prices have been key drivers of volatility across U.S equity segments as inflation expectations risk de-anchoring. </description><title>Oil Price Shocks Are Testing Resilience Across Methodologies Among S&amp;amp;P SmallCap 600 Indices </title><pubDate>09 April 2026 06:30:00 GMT</pubDate><author><name>Patricia Medina</name></author><content><![CDATA[ Research â 9 April, 2026 Oil Price Shocks Are Testing Resilience Across Methodologies Among S&amp;P SmallCap 600 Indices By Patricia Medina Executive Summary The war and the subsequent surge in crude oil prices have amplified volatility in U.S. equity markets, including the S&amp;P SmallCap 600 Index. Analysis of small cap equities reveals varying degrees of resilience to recent market fluctuations. The AI-driven tools in S&amp;P Global Market Intelligenceâs Capital IQ Pro platform, along with Xpressfeed, Portfolio Analytics, and data from S&amp;P Dow Jones Indices, help clients uncover insights into equity volatility. This article examines the extent to which elevated oil prices influence the distribution and density of the S&amp;P SmallCap 600 index and a sample of small cap indices with diverse construction methodologies, using 10-year historical daily data. Also, it explores the sector-level dispersion of risk-adjusted returns between cyclical and defensive sectors within small caps as a potential consequence of these dynamics. The war in the Middle East and the subsequent surge in oil prices have been key drivers of volatility across U.S equity segments as inflation expectations risk de-anchoring. The chart below illustrates the density and distribution of four S&amp;P SmallCap 600 stock indices compared to oil price fluctuations since 2016. The oil price range exhibits more outliers on both ends compared to indices. On Friday, February 27 (black dot), the day before the first U.S-Israel strikes on Iran, the four S&amp;P SmallCap 600 equity indices traded at decade highs, while West Texas Intermediate (WTI) oil price stood at $67.06ânear recent lows. Then, the war began, pushing oil price higher settling at $99.56, in contrast to declining levels across the S&amp;P SmallCap 600 indices two weeks into the conflict by Friday, March 13 (red dot). During this period, the average decline across the analyzed group was about 85 points, with variations observed on each index's specific profile. Historical data is available via Xpressfeed and other delivery mechanisms that investors can leverage to populate algorithms and models. S&amp;P SmallCap 600 Index &amp; S&amp;P SmallCap 600 Equal Weighted Index Both indices experienced declines as the war continued, with the Equal Weighted version declining more than the group average and outpacing the market-cap weighted counterpart. Despite the pullback, both indices remain near long-term highs, even as oil tested $100 by March 13. Historically, the S&amp;P SmallCap 600 Index has shown retests around the 1,300 and 950 levels over the past decade. The Equal Weighted version, which has yet to break above 2,000, displays moderate density near 1,600 and 1,000 since 2016. S&amp;P SmallCap 600 Value Index &amp; S&amp;P SmallCap 600 Growth Index As oil price trended higher on the chart above, the Value and Growth categories demonstrated greater resilience to the downside during the initial 10 trading days of the war, remaining near their decade highs. The Value Index showed the highest resilience. The Growth Index's decline was also less than the group average, approaching 1,150. Both indices are characterized by limited historical stock dispersion in the last decade. As noted below, small cap equities tend to be sensitive to spikes in oil prices as they increase input and logistics costs. The climbing oil price is also impacting dispersion across the 11 sectors in the S&amp;P SmallCap 600 index. In addition to S&amp;P Dow Jones Indices performance monitoring, the chart below plots YTD figures, accessible via Capital IQ Proâs Portfolio Analytics offered by S&amp;P Global Market Intelligence. These tools can be combined with user-defined custom functions to allow for ad-hoc or scheduled batch reporting. By mid-March, Energy sector equities posted higher risk-adjusted returns while defensive sectors Utilities and Health Care hovered toward the lower end of the spectrum. Learn more about Portfolio Analytics on Capital IQ Pro Click Here Learn more about Xpressfeed Click Here ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/051326-1250-mw-chpe-transmission-line-into-nyc-reaches-commercial-operation-early</link><description>The 1,250-megawatt Champlain Hudson Power Express transmission line reached its commercial operational date on May 13, making it officially available for scheduling transactions. The line can supply roughly 20% of New York City&amp;apos;s power demand at full capacity. &amp;quot;The good news is that because we finished testing early, we are able to participate in the May energy market, which is great for New York</description><title>1,250-MW CHPE transmission line into NYC reaches commercial operation early</title><pubDate>13 May 2026 18:52:04 GMT</pubDate><author><name>Jared Anderson</name></author><content><![CDATA[ Electric Power, Energy Transition, Renewables May 13, 2026 1,250-MW CHPE transmission line into NYC reaches commercial operation early By Jared Anderson Editor: Giselle Rodriguez Getting your Trinity Audio player ready... HIGHLIGHTS Can supply 20% of NYC power demand Will participate in July capacity market The 1,250-megawatt Champlain Hudson Power Express transmission line reached its commercial operational date on May 13, making it officially available for scheduling transactions. The line can supply roughly 20% of New York City's power demand at full capacity. "The good news is that because we finished testing early, we are able to participate in the May energy market, which is great for New York City because if there is a heat wave, CHPE can help meet demand," Peter Rose, senior director of stakeholder relations for Hydro Quebec said in a phone call. The project developers and owners had initially expected the high-voltage direct-current transmission line to become operational in early June, but testing was completed early, and the line entered commercial operational status shortly after midnight on May 13. Transmission Developers, backed by private equity firm Blackstone, is developing CHPE. The project began construction in November 2022 and will be supplied with hydropower from provincially owned Hydro-Quebec's reservoir system. "CHPE is currently available for energy market operations," a CHPE spokesperson said in an email. Deadlines, economics The owners have a contract with the New York Energy Research and Development Authority that starts June 1, which is the first day of the month after the project has reached commercial operations. That means between May 13, and June 1, Hydro Quebec will schedule transactions on the line when energy market prices are high enough to support the economics, Rose said. Third parties can also schedule transactions when economic, as the transmission line is governed by an open-access tariff. The contract with NYSERDA has a strike price of $97.50/MWh in the first year, and it escalates from there. Required testing to participate in the New York Independent System Operator's July capacity market was completed by the NYISO deadline, so the line will also start participating in that market. "We thought we were only going to be available in August, but can start a month early," Rose said. "The New York Independent System Operator confirms that the CHPE transmission facility has satisfied applicable tariff requirements necessary to participate in NYISO's wholesale electricity markets," Kevin Lanahan, NYISO's senior vice president of external affairs and corporate communications, said in an email. "Following the completion of required testing and submission of a valid notice of intent, CHPE is now eligible to commence participation in the capacity market starting with the July auction and is eligible to participate in NYISO's energy market systems consistent with existing market rules," he said. Spot market transactions will depend on whether power prices support them. With higher temperatures forecast over the coming days in the New York City area, electric cooling demand could increase power prices. The high temperature in New York City on May 17 is forecast to reach 87 degrees Fahrenheit, according to the National Weather Service. A 2025 heat wave pushed NYISO Zone J spot power prices to a daily average of $181.83/MWh June 24. Zone J on-peak day-ahead power prices have averaged $43.14/MWh thus far in May. 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/051426-interview-hydrogen-push-should-not-lose-momentum-once-energy-crisis-cools---hydrogen-association-of-india</link><description>Geopolitical tensions in the Middle East and the resulting volatility in energy markets have given renewed urgency to global conversations around energy security and alternative fuels. While fluctuations in crude oil prices may temporarily influence investment priorities, experts at Hydrogen Association of India believe the global hydrogen transition is being driven by much deeper structural</description><title>INTERVIEW: Hydrogen push should not lose momentum once energy crisis cools - Hydrogen Association of India</title><pubDate>14 May 2026 12:55:21 GMT</pubDate><author><name>Donavan Lim</name></author><content><![CDATA[ Energy Transition, Hydrogen May 14, 2026 INTERVIEW: Hydrogen push should not lose momentum once energy crisis cools - Hydrogen Association of India By Donavan Lim Editor: Alisdair Bowles Getting your Trinity Audio player ready... HIGHLIGHTS Hydrogen transition driven by structural forces Green hydrogen costs expected to drop to $2/kg India targets domestic hydrogen ecosystem by 2030 Geopolitical tensions in the Middle East and the resulting volatility in energy markets have given renewed urgency to global conversations around energy security and alternative fuels. While fluctuations in crude oil prices may temporarily influence investment priorities, experts at Hydrogen Association of India believe the global hydrogen transition is being driven by much deeper structural forces that extend beyond short-term market cycles. Platts recently spoke to Sachin Chugh, vice president of the Hydrogen Association of India, who said that hydrogen should not be viewed merely as a reaction to oil price volatility, but as a strategic pillar of future industrial and energy systems. "Historically, periods of high crude prices have accelerated interest in alternative fuels. However, the long-term case for hydrogen today is far stronger than in previous energy transitions because it gets linked directly to the energy security and simultaneously complements industrial decarbonization, manufacturing competitiveness, and national sustainability goals," he said. While conventional fossil fuels are expected to remain extremely important in the global energy mix for the foreseeable future, hydrogen is steadily emerging as a complementary energy vector, particularly for sectors that are difficult to electrify directly. Experts at HAI acknowledge that green hydrogen currently faces economic and infrastructure-related challenges. Production costs remain higher than fossil-derived alternatives, and significant investments are required in storage, transportation, and distribution networks. However, similar challenges were also witnessed during the early phases of solar and wind deployment, where costs declined sharply with scale, policy support, and technological innovation. "It is important to understand that energy transitions are evolutionary, not instantaneous. Hydrogen will scale progressively as infrastructure develops, demand aggregates, and technology matures," Chugh said. The HAI expects the price of green hydrogen in India to drop to around $2/kg by 2030, Chugh said. Platts, part of S&amp;P Global Energy, assessed India Renewable Hydrogen Term Contract at $3.227/kg or $28.3969/MMBtu on May 7. Beyond climate commitments For India, the hydrogen opportunity extends beyond climate commitments. With nearly 88% dependence on imported crude oil, diversification of the energy basket is increasingly being viewed as a strategic necessity for long-term economic resilience and energy independence. The association believes India's immediate focus should be on developing a domestic hydrogen ecosystem through phased and practical adoption pathways. One such approach could involve the production of hydrogen-derived e-fuels and their gradual blending with conventional fuels like gasoline or diesel, similar to the country's successful ethanol blending program. In its direct form, early applications could include blending hydrogen into gas distribution networks, deployment of hydrogen-enriched compressed natural gas (HCNG) based power generation and mobility solutions, and gradual expansion of its applications in domestic cooking systems. "Blending in any form provides an effective transition mechanism. Even small percentages can help create demand visibility, enable infrastructure development, improve operational familiarity, and stimulate investments across the value chain," Chugh said. Another critical area requiring attention is the development of globally harmonized hydrogen standards, including certification frameworks, carbon intensity definitions, and transportation protocols. Harmonization can play a vital role in enabling international trade, investor confidence, and scalability of projects. Despite current cost barriers, there is growing optimism that green hydrogen economics will improve significantly over the coming decade due to declining renewable energy prices, electrolyzer manufacturing scale-up, localization, and supportive policy mechanisms. India's green hydrogen production costs are expected to move steadily closer to global competitiveness by 2030, potentially positioning the country as both a major consumer and exporter of green molecules and derivatives such as green ammonia. "The discussion should not be whether hydrogen replaces fossil fuels overnight. The real opportunity lies in building a balanced, resilient, and diversified energy ecosystem where hydrogen becomes an important contributor to industrial growth, clean mobility, and energy security," Chugh added. As governments and industries navigate an increasingly uncertain geopolitical and climate landscape, hydrogen's role is expected to strengthen steadily, not merely because of temporary oil price fluctuations, but because of its long-term strategic relevance to the future global economy. 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/051826-india-eu-eye-collaboration-to-build-energy-supply-chains-port-infrastructure-modi</link><description>India is accelerating efforts to build resilient energy supply chains by collaborating with global partners to soften the blow from geopolitical conflicts and the energy crisis that are threatening economies across the globe, Indian Prime Minister Narendra Modi said May 16. &amp;quot;First came COVID-19, and then came wars, and now an energy crisis. This is turning out to be a decade of disasters. If</description><title>India, EU eye collaboration to build energy supply chains, port infrastructure: Modi</title><pubDate>18 May 2026 01:55:35 GMT</pubDate><author><name>Sambit Mohanty</name></author><content><![CDATA[ Refined Products, Crude Oil, Energy Transition, Gasoline, Renewables, Hydrogen May 18, 2026 India, EU eye collaboration to build energy supply chains, port infrastructure: Modi By Sambit Mohanty Editor: Aastha Agnihotri Getting your Trinity Audio player ready... HIGHLIGHTS Renews call for quick end to military conflicts Energy shortages threatening world economies India is accelerating efforts to build resilient energy supply chains by collaborating with global partners to soften the blow from geopolitical conflicts and the energy crisis that are threatening economies across the globe, Indian Prime Minister Narendra Modi said May 16. "First came COVID-19, and then came wars, and now an energy crisis. This is turning out to be a decade of disasters. If things don't normalize soon, a lot of efforts and successes that we achieved over many decades will go waste and hit the world economy," Modi told a gathering in the Netherlands during his visit to Europe, which also includes visits to Norway, Sweden, and Italy. India is witnessing a rise in calls for austerity to curb energy use, alongside flight cancellations and a reduction in imports, as supply chain disruptions stemming from the West Asia conflict have increased freight and insurance rates, while rupee depreciation is making imported inputs more expensive. With India importing more than 85% of its crude oil needs, elevated global energy prices are threatening to sharply inflate the country's oil import bill and further weaken the domestic currency, which has lost more than 5% since the start of the Middle East conflict, analysts and industry experts told Platts, part of S&amp;P Global Energy, last week. On May 10, Modi told a gathering in India that the country should reduce gasoline and diesel consumption through measures such as remote work and virtual meetings, as rising oil prices were placing significant pressure on foreign exchange outflows. "The growing strategic convergence between India and Europe and underscored the importance of trusted partnerships in an increasingly complex and uncertain global environment. India and Europe must work together to build resilient and diversified supply chains," Modi said while addressing a European Round Table for Industry (ERT) in Gothenburg on May 17. "India-EU Free Trade Agreement would further unlock new opportunities for both sides," he added. Modi highlighted India's ambitious infrastructure and energy transformation, including large-scale investments in transport, logistics, renewable energy, green hydrogen, and nuclear power. He invited European industry leaders to partner with India in areas such as telecoms and digital infrastructure; AI, semiconductors, electronics, and deep tech manufacturing; green transition and clean energy; infrastructure, mobility, and urban transformation; and healthcare and life sciences, an Indian government statement said May 17. Strategic partnerships India and the Netherlands are also actively cooperating to counter these disruptions by building trusted, transparent, and future-ready supply chains, with a specific focus on clean and renewable energy, Modi said. Modi and Prime Minister of the Netherlands Rob Jetten agreed to elevate the India-Netherlands bilateral relationship to a strategic partnership by following focused, time-bound initiatives and a joint plan of action. To this end, India and the Netherlands adopted the Roadmap of India-Netherlands Strategic Partnership for the next 5 years (2026-2030), the Indian government statement said. "With a view to further strengthening the partnership between India and the Netherlands in the field of renewable energy, the two leaders welcomed the establishment of a Joint Working Group under the Memorandum of Understanding on Renewable Energy which provides ample scope for a diversified agenda for cooperation in renewable energy, including innovative solar energy, green hydrogen, storage and investments in the renewable energy sector to facilitate energy transition," it added. In Gothenburg, Modi met with Robert Maersk Uggla, the chairman of Maersk. "We discussed the great opportunities in India and increased investment, especially in sectors such as port infrastructure, logistics, and more," Modi said on social media platform X. According to S&amp;P Global Energy CERA, India's shipbuilding industry accounts for less than 1% of the global shipping market. This contrasts sharply with China, which holds a 61% share of the order book in major commercial shipping segments. South Korea and Japan also have significant global influence, with advanced technological capabilities and strong export pipelines. India's commercial fleet is much smaller than China's large merchant marine, underscoring the country's growth potential in shipyards. India has pledged to secure 1,000 commercial ships over the next decade as part of a national push to expand its shipbuilding industry and maritime sector, according to Rahul Kapoor, head of shipping and metal analytics at CERA. New Delhi is also promoting the development of integrated shipbuilding clusters -- industrial parks with state-of-the-art facilities and skill-development centers designed to stimulate innovation and productivity. India plans to create eight maritime clusters, comprising five new facilities and three expanded ones. Backed by state governments and with pre-secured land, these clusters will host activities ranging from manufacturing and equipment production to insurance and leasing services, Kapoor 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/crude-oil/051526-singapore-airlines-warns-full-impact-of-middle-east-fuel-shock-still-to-come</link><description>Singapore Airlines Group has warned that the full impact of the Middle East fuel shock will weigh on its earnings in the next financial year, as elevated jet fuel prices are billed on a delayed basis and broader macroeconomic conditions could affect demand amid a prolonged crisis. The remarks come even as SIA posted strong FY2025/26 results for the year ended March 31, when its fuel hedging</description><title>Singapore Airlines warns full impact of Middle East fuel shock still to come</title><pubDate>15 May 2026 09:46:46 GMT</pubDate><author><name>Mia Pei</name><name>Shu ling Lee</name></author><content><![CDATA[ Refined Products, Agriculture, Energy Transition, Jet Fuel, Biofuels, Renewables May 15, 2026 Singapore Airlines warns full impact of Middle East fuel shock still to come By Mia Pei and Shu ling Lee Editor: Alisdair Bowles Getting your Trinity Audio player ready... HIGHLIGHTS Jet fuel prices more than doubled in March Fare hikes not enough to offset rising fuel costs Group reiterates aim for 5% SAF adoption by 2030 Singapore Airlines Group has warned that the full impact of the Middle East fuel shock will weigh on its earnings in the next financial year, as elevated jet fuel prices are billed on a delayed basis and broader macroeconomic conditions could affect demand amid a prolonged crisis. The remarks come even as SIA posted strong FY2025/26 results for the year ended March 31, when its fuel hedging resulted in a S$218 million (US$170 million) gain in the second half of the year, compared with a S$13 million loss in the same period the year prior, according to exchange filings on May 14. Fuel costs stood at S$5.03 billion for the financial year, accounting for 27.7% of total annual expenditure. Jet fuel prices "have more than doubled since the conflict began," SIA said, noting that the impact was only partially reflected in March because of lagged fuel pricing mechanisms. "The full impact is expected to feed through in FY2026/27," it said. While the national air carrier of Singapore and its low-cost subsidiary, Scoot, have raised air fares across their network, the adjustments do not fully offset the rise in jet fuel prices, which is the group's single-largest expenditure item. "Depending on the duration and how the situation in the Middle East develops, there could be broader implications for supply chains and macroeconomic conditions affecting demand patterns," the group said. Platts, part of S&amp;P Global Energy, assessed the FOB Singapore jet fuel/kerosene cargo outright price at $151.92/barrel on May 14, down $7.88/b on the day, with healthier regional supply pressuring spot premiums lower. The benchmark averaged $200.42/b in April and $195.40/b in March, more than double pre-crisis levels of $89.03/b in February. SIA's comments echo analysts' warnings that fuel costs will materially compress margins next year, despite higher fares and resilient premium demand. Jason Sun, analyst at DBS group research, said in a note May 15 that despite Singapore jet fuel prices having stabilized at around $150-$160/b over the past few days, materially below the peak disruption levels where prices surged more than 100%, it still represents a 70% increase from pre-conflict levels. Sun noted that "price-sensitive regional markets" are likely to face margin pressure ahead, as yield resilience is tested amid the full impact of the fuel shock. "Air India also remains a significant drag, as its recovery continues to be constrained by higher exposure to the Middle East and weaker pricing power, amid ongoing operational and FX challenges," Sun said. SIA holds a 25.1% stake in Air India after the Indian national carrier merged with SIA's co-owned Vistara in 2024. Tata Group owns the remaining 74.9% of Air India. SIA noted in its filing that Air India faces headwinds, including industry-wide supply chain constraints, airspace restrictions, and operational constraints to its key Middle East markets, on top of high fuel costs. "Nonetheless, it continues to make progress in its fleet renewal... and improve its operational performance." SAF commitment In the results briefing, SIA reiterated its commitment to decarbonizing group operations, with sustainable aviation fuel "a key lever in the journey towards achieving net zero carbon emissions by 2050." It underscored the importance of diversifying SAF sources, as well as scaling global production and adoption. Both SIA and Scoot aim to source 5% of total fuel requirements from SAF by 2030. "Since 2024, we have purchased 2,000 tons of neat SAF from Neste and around 2,500 tons of CORSIA-eligible SAF (emissions reductions) from World Energy and SkyNRG," it said in a May 15 results briefing. "In February, SIA and Scoot -- together with CAAS, the Singapore Sustainable Aviation Fuel Company (SAFCo), and seven other companies -- signed an MOU to trial SAF purchases in Singapore," it noted. The trial SAF purchases have continued as planned despite the delay in Singapore's SAF levy. Platts-assessed SAF (HEFA-SPK) FOB Straits averaged $281.65/b in April, down from $289.06/b in March but up from $245.56/b in February. Capturing sustainable demand SIA also highlighted its ongoing moves to capture growth opportunities for the long term despite a challenging operating environment, including prompt adjustments to frequencies and capacity. A SIA official told Platts last month that the group has been increasing services even as some global airlines have been cutting capacity or trimming outlooks, including ad hoc supplementary services to London Heathrow and Frankfurt in Germany, and an additional three-times-weekly service to London Gatwick. The group is also capturing "more high-value, time-sensitive cargo" across key sectors such as healthcare and perishables, with tonnage up 26% in March 2026. In the last quarter of FY2025/26, cargo operations strengthened, with the load factor rising to 55.9% from 51.2% over the year. 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/051526-cbams-article-6-embrace-comes-with-strings-and-forms-attached</link><description>The European Commission&amp;apos;s draft rules on recognizing third-country carbon pricing under the bloc&amp;apos;s Carbon Border Adjustment Mechanism represent a pragmatic but tightly controlled opening that could accelerate investment in Article 6 of the Paris Agreement while creating new compliance challenges. The widely anticipated implementing regulation, published May 13 and open for consultation until June</description><title>CBAM&amp;apos;s Article 6 embrace comes with strings and forms attached</title><pubDate>15 May 2026 12:00:34 GMT</pubDate><author><name>Eklavya Gupte</name><name>Irina Breilean</name><name>Ben Carding</name></author><content><![CDATA[ Energy Transition, Carbon May 15, 2026 CBAM's Article 6 embrace comes with strings and forms attached By Eklavya Gupte, Irina Breilean, and Ben Carding Editor: Adithya Ram Getting your Trinity Audio player ready... HIGHLIGHTS Draft rules could spark investment in Article 6 trade Importers face mounting paperwork to claim carbon price cuts Article 6 credits capped at 10% of emissions The European Commission's draft rules on recognizing third-country carbon pricing under the bloc's Carbon Border Adjustment Mechanism represent a pragmatic but tightly controlled opening that could accelerate investment in Article 6 of the Paris Agreement while creating new compliance challenges. The widely anticipated implementing regulation, published May 13 and open for consultation until June 10, lays out detailed methodologies for how carbon prices paid abroad translate into reductions in CBAM certificate obligations. "It creates a real financial incentive to put a credible domestic carbon price in place," Adam Hearne, CEO at CarbonChain, told Platts, part of S&amp;P Global Energy. "Companies that already pay a carbon price, or buy qualifying credits, can lower their effective CBAM cost, making their goods more competitive in the EU market. This tilts the playing field towards countries that are building or linking carbon markets." Under the world's first carbon border tax mechanism, importers of carbon-intensive goods into the EU from six covered sectors -- aluminum, cement, electricity, fertilizers, iron and steel, and hydrogen -- are now liable for their emissions. Demand signals The draft's design is deliberately restrictive on international credits. Only carbon credits authorized under Articles 6.2 or 6.4 of the Paris Agreement would qualify for CBAM liability reductions, and their use would be capped at 10% of emissions covered under qualifying third-country carbon pricing mechanisms. This structure amounts to a "compliance-adjacent demand signal for authorization and tracking-ready units, potentially supporting investment in Article 6 market infrastructure," said Eszter Bencsik, voluntary carbon markets analyst at S&amp;P Global Energy Horizons. The EU's CBAM started its definitive phase on Jan. 1, 2026, but importers will only be able to purchase CBAM certificates starting in February 2027 to cover the emissions embedded in their imports for 2026, giving businesses more time to adapt to this carbon pricing mechanism. Dan Maleski, a senior environmental markets adviser and CBAM lead at Redshaw Advisors, believes the likelihood of international Article 6 credits being used under CBAM is likely to remain relatively limited. "The implementing act is very clear that any recognized carbon cost must be mandated and legally required, rather than the result of a voluntary purchase," Maleski told Platts. "In principle, this significantly limits the scope for international credits, as host countries would effectively need to forgo domestic revenue streams. Out of the 30-plus active emissions trading systems globally, only South Korea currently permits the use of international credits within its ETS, and even then under very strict limitations and conditions, Maleski added. The EU's CBAM works alongside the EU Emissions Trading System to prevent carbon leakage by imposing carbon pricing on imports as Brussels phases out free allowances for domestic producers. Carbon permits in Europe are currently almost eight times more expensive than compliance prices in China, the world's industrial powerhouse. Platts assessed EU Allowances for December 2026 at Eur75.04/mtCO2e ($87.39/mtCO2e) on May 14. This compares with China's compliance emission allowance, which was valued at Yuan 80.06/mtCO2e ($11.76/mtCO2e) on May 8, according to the Shanghai Environment and Energy Exchange. Compliance burden These rules, however, add a significant administrative burden for operators seeking to claim carbon price reductions, market participants cautioned. Operators will need to submit additional reports on carbon price reductions, on top of monitoring and verification plans and carbon accounting rules they already face, according to Pauline Miquel, policy and research lead at CBAM consultancy CBAMBOO. "This is a lot more work to be able to let an importer forecast their cost because all of this is the basis for the importer's cost modeling," Miquel said. "And without this, it's almost impossible for an EU importer to understand how much they're going to pay in CBAM liability." They will also need to calculate how the price paid translates into embedded emissions at the product level, she added. The lack of accredited verifiers presents a further hurdle. If operators choose to use verified emissions rather than default values, "it's going to make it very difficult to have all of this ready for 2027," Miquel said. But many believe the explicit recognition of Article 6 credits, even in limited form, demonstrates the EU wants to support the Paris Agreement's international carbon market mechanisms, with the 10% cap designed to prevent over-reliance on offsets and to push real domestic decarbonization. This could drive increased investment in third-country carbon pricing infrastructure, Article 6 credit supply, and verifier and accreditation services over the next 12-24 months, Hearne said. A US-based carbon market analyst said the proposal reflects a broader positive trend of the EU being more flexible and open to carbon credits and recognizing the positive effects of carbon projects, pointing to similar developments in the Corporate Sustainability Reporting Directive. Domestic vs international credits The proposal could also reinforce a price premium for credits that can be evidenced through UN-grade accounting, she added, while laying foundations for greater integration of Article 6-aligned credits into other carbon pricing frameworks. "International credits face the highest integrity gateway -- Article 6 authorization plus a quantitative cap -- while domestically issued credits, including those linked to mitigation abroad, could be recognized without an EU-level integrity screen or usage limit," Bencsik said. This bifurcation risks an uneven playing field, she noted. Exporters under regimes with permissive domestic crediting rules may be able to evidence a higher carbon price effectively paid, and therefore secure larger CBAM reductions, than peers reliant on internationally transferred units constrained by Article 6 rules. The proposal's practical impact will depend heavily on implementation details, especially administrative burden, certification and verification robustness, and interaction with rebates or other forms of compensation. A further dynamic to watch is pricing behavior in domestic credit markets. "Because domestic credits reduce CBAM obligations only insofar as they contribute to an evidenced carbon price effectively paid, some jurisdictions could face incentives to support higher domestic credit prices or tighter supply to retain compliance value domestically rather than see larger net financial outflows via CBAM certificate surrender," Bencsik 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/051526-japans-idemitsu-invests-in-us-carbon-removal-firm-crew</link><description>Japan&amp;apos;s Idemitsu Kosan has invested in US-based CREW Carbon through its corporate venture capital arm, the Japanese refiner said May 15, as the companies explore deploying carbon dioxide removal technology at wastewater treatment facilities globally. The collaboration will investigate using CREW&amp;apos;s Wastewater Alkalinity Enhancement technology at facilities in Japan and other Joint Crediting</description><title>Japan&amp;apos;s Idemitsu invests in US carbon removal firm CREW</title><pubDate>15 May 2026 05:14:47 GMT</pubDate><author><name>Ruchira Singh</name></author><content><![CDATA[ Energy Transition, Carbon, Emissions May 15, 2026 Japan's Idemitsu invests in US carbon removal firm CREW By Ruchira Singh Editor: Aastha Agnihotri Getting your Trinity Audio player ready... HIGHLIGHTS Wastewater Alkalinity Enhancement tech in plan CREW's wastewater tech creates carbon credits Japan's limestone aids CO2 sequestration plan Japan's Idemitsu Kosan has invested in US-based CREW Carbon through its corporate venture capital arm, the Japanese refiner said May 15, as the companies explore deploying carbon dioxide removal technology at wastewater treatment facilities globally. The collaboration will investigate using CREW's Wastewater Alkalinity Enhancement technology at facilities in Japan and other Joint Crediting Mechanism countries, Idemitsu said in a statement. "This investment allows Idemitsu to deepen their technical CDR expertise and commercial understanding of the carbon removal market," Idemitsu said. The WAE process prevents CO2 from entering the atmosphere, ensuring it remains in wastewater discharged from sewage plants, Idemitsu said. Additionally, CREW has a proprietary measuring, reporting and verification (MRV) system that calculates the net CO2 removed, enabling certified carbon credits that can be sold, it added. "Sequestering the CO2 in the wastewater removes the need for investment in carbon capture units, avoiding a large installation footprint," the company said. Net-zero at 2050 Idemitsu is evaluating business models that promote negative emissions and developing technologies that support achieving carbon neutrality in society by 2050, it said. To enable these targets, Idemitsu is making strategic investments in startups with advanced expertise and a track record in CDR and MRV, the company added. Achieving carbon neutrality targets will require a general reduction in CO2 emissions, but also reliable, transparent processes that remove CO2 from the atmosphere, it said. Japan is one of the world's leading producers of limestone used in the CREW process and provides an environment in which calcium carbonate required for CO2 sequestration in CREW's CDR solution can be economically sourced, it said. Platts, a part of S&amp;P Global Energy, assessed Pre-CEC Current Year carbon credits at $10/mtCO2e May 14, down 21.26% from a month ago. 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/051126-kawasaki-mb-energy-daimler-truck-sign-up-for-liquid-hydrogen-supply-chain-in-europe</link><description>Kawasaki Heavy Industries, MB Energy and Daimler Truck have signed a joint development agreement to establish a liquid hydrogen supply chain to Europe via the Port of Hamburg, targeting commercial operation by the early 2030s, the companies said May 11. The agreement, which expands upon an existing memorandum of understanding for a Japan-Germany hydrogen supply chain, will leverage the companies&amp;apos;</description><title>Kawasaki, MB Energy, Daimler Truck sign up for liquid hydrogen supply chain in Europe</title><pubDate>11 May 2026 11:52:44 GMT</pubDate><author><name>Ruchira Singh</name></author><content><![CDATA[ Energy Transition, Hydrogen May 11, 2026 Kawasaki, MB Energy, Daimler Truck sign up for liquid hydrogen supply chain in Europe By Ruchira Singh Editor: Ankit Ajmera Getting your Trinity Audio player ready... HIGHLIGHTS Hamburg to serve as Europe's gateway 100 fuel cell trucks to operate by 2026 Kawasaki building liquid hydrogen carriers Kawasaki Heavy Industries, MB Energy and Daimler Truck have signed a joint development agreement to establish a liquid hydrogen supply chain to Europe via the Port of Hamburg, targeting commercial operation by the early 2030s, the companies said May 11. The agreement, which expands upon an existing memorandum of understanding for a Japan-Germany hydrogen supply chain, will leverage the companies' expertise to assess the economic viability of a liquid hydrogen supply chain, according to the statement. "By bringing our liquefied hydrogen technologies to Europe, we aim to support industrial and heavy-duty vehicle demand and help establish a scalable international hydrogen corridor," said Kei Nomura, executive officer and general manager, hydrogen strategy division at Kawasaki. Kawasaki specializes in the design and manufacture of essential infrastructure, including hydrogen liquefiers, liquid hydrogen storage tanks and liquid hydrogen carrier ships, which it will utilize for this initiative, according to the statement. The collaboration aims to establish transportation routes from potential hydrogen-producing countries to Germany and, in doing so, promote the use of hydrogen across European industries, beginning with Daimler Truck's zero-emission vehicles. Daimler Truck plans to introduce 100 liquid hydrogen-powered fuel cell trucks into customer operations by the end of 2026, with series production slated for the early 2030s, according to the statement. Volker Ebeling, senior vice president, new energy, storage and infrastructure at MB Energy, said Hamburg is ideally positioned to become Germany's main gateway. "We are combining MB Energy's infrastructure, our service station network and our trading expertise with Daimler Truck's next-generation hydrogen truck developments and Kawasaki's pioneering hydrogen storage and shipping technologies," Ebeling said. In January, Kawasaki and Japan Suiso Energy signed a contract to build a 40,000-cubic-meter liquid hydrogen carrier, marking a move toward establishing a commercial-scale hydrogen supply chain. Platts, part of S&amp;P Global Energy, assessed the India renewable hydrogen term contract at $3.23/kg on May 7, up 0.6% month over month. 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/051326-australia-shortlists-renewable-hydrogen-projects-for-funding-amid-budget-cuts</link><description>The Australian Renewable Energy Agency has shortlisted seven renewable hydrogen projects for the second round of the Hydrogen Headstart program, according to a May 13 announcement, a day after spending cuts to the flagship initiative. ARENA has invited the projects to submit full applications for funding from the program, which received a revised allocation of A$1 billion ($660 million) in the</description><title>Australia shortlists renewable hydrogen projects for funding amid budget cuts</title><pubDate>13 May 2026 06:44:53 GMT</pubDate><author><name>Ruchira Singh</name></author><content><![CDATA[ Fertilizers, Chemicals, Energy Transition, Renewables, Hydrogen May 13, 2026 Australia shortlists renewable hydrogen projects for funding amid budget cuts By Ruchira Singh Editor: Surbhi Prasad Getting your Trinity Audio player ready... HIGHLIGHTS Australia shortlists seven hydrogen projects Projects span 120-750 MW electrolysis capacity Program allocates A$1B in production credits The Australian Renewable Energy Agency has shortlisted seven renewable hydrogen projects for the second round of the Hydrogen Headstart program, according to a May 13 announcement, a day after spending cuts to the flagship initiative. ARENA has invited the projects to submit full applications for funding from the program, which received a revised allocation of A$1 billion ($660 million) in the 2026-27 (July-June) federal budget announced on May 12, ARENA said. "Renewable hydrogen is a complex, capital-intensive industry and progress takes time, but it is a critical enabler of industrial decarbonisation, particularly for hard-to-abate sectors," ARENA CEO Darren Miller said. "What we're seeing are expressions of interest that are considered and well aligned to future market demand." The shortlisted projects include Bell Bay Powerfuels, a 300 MW project in Tasmania; South East Queensland Power-to-X Project, a 150 MW project in Queensland; and Portland Renewable Fuels Project, a 220 MW project in Victoria, according to the announcement. The renewable hydrogen end-use for the projects are methanol, sustainable aviation fuel, ammonia, urea and alumina, according to the government agency. Australia reprioritized funding support for clean energy in the budget May 12, halving spending for Hydrogen Headstart, in a year wracked by energy shocks and cost-of-living increases. Builds on existing support Announced in the 2023-24 budget, Hydrogen Headstart aims to catalyze Australia's hydrogen industry to become a global leader in the emerging global trade for clean fuels, according to ARENA. "Renewable hydrogen presents Australia with a significant economic and decarbonization opportunity," Miller said. "Its potential to develop low-emission fuels for aviation and shipping, as well as key inputs for fertiliser could also help improve the nation's energy resilience in the longer term." Round 2 of Hydrogen Headstart builds on ARENA's support for renewable hydrogen, with the Agency having already committed over A$1.2 billion to two projects in Round 1 and over A$396 million to 68 renewable hydrogen projects since 2017 through other funding programs. Hydrogen Headstart's first round concluded last year, awarding A$1.2 billion to Orica's 50 MW Hunter Valley Hydrogen Hub and to Copenhagen Infrastructure Partners' 1,500 MW Murchison Green Hydrogen Project. Under Hydrogen Headstart, projects seeking to produce renewable hydrogen or its derivatives can apply for a production credit delivered over 10 years to bridge the commercial gap between the cost of producing renewable hydrogen and market prices, it said. Shortlisted applicants now have until early September to submit their full applications, it said. Following the assessment phase, a recommendation will be made to Chris Bowen, Minister for Climate Change and Energy, for approval of which projects will receive support. Platts, a part of S&amp;P Global Energy, assessed Australia renewable-derived ammonia delivered into Far East Asia, with high-capacity factors at $760.77/mt May 11, up 0.76% from a month ago. ARENA's shortlisted projects for A$1 billion Hydrogen Headstart program: Applicant Project title Electrolysis facility size (MW) State Hydrogen end use Bell BayPowerfuelsPty Ltd Bell BayPowerfuels 300 Tasmania Methanol EuropeanEnergyAustralia Pty Ltd South East Queensland Power-to-X Project 150 Queensland Methanol HAMR Energy Pty Ltd Portland Renewable Fuels Project 220 Victoria Methanoland SAF HIF Asia Pacific Pty Ltd HIF Tasmania e-Fuel Facility 140 Tasmania Methanol Murchison Hydrogen Renewables Pty Ltd Murchison Green Hydrogen Project Stage 1B 500 Western Australia Ammonia PerdamanCommercial Developments Pty Ltd Perdaman Helios (Karratha): Decarbonising Fertilisers 750 Western Australia Urea Summit Hydro Pty Ltd Gladstone Green Hydrogen Project 120 Queensland Alumina Source: ARENA 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/060324-interactive-platts-global-bunker-fuel-cost-calculator</link><description>The Platts global bunker fuel cost calculator shows how Platts price assessments for methanol, ammonia, LNG, bioblends and conventional oil-based fuels can be used to calculate the cost of marine fuels around the world, taking into account the EU Emissions Trading System and adjusted for energy density to put them on an equal footing.</description><title>Interactive: Platts global bunker fuel cost calculator</title><pubDate>14 May 2026 13:30:00 GMT</pubDate><author><name>Max Lin</name><name>Rowan Staden-Coats</name><name>Abhishek Anupam</name><name>Sophie Byron</name><name>Esther Ng</name><name>Megan Gildea</name><name>Santiago Canel Soria</name></author><content><![CDATA[ May 14, 2026 INTERACTIVE: Platts global bunker fuel cost calculator By Max Lin, Rowan Staden-Coats, Abhishek Anupam, Sophie Byron, Esther Ng, Megan Gildea, and Santiago Canel Soria Getting your Trinity Audio player ready... (Latest update May 14, 2026) The Platts global bunker fuel cost calculator shows how Platts price assessments for methanol, ammonia, LNG, bioblends and conventional oil-based fuels can be used to calculate the cost of marine fuels around the world, taking into account the EU Emissions Trading System and adjusted for energy density to put them on an equal footing. Click here to explore in full-screen mode. Methanol blend Shipping firms are struggling to acquire sustainable methanol due to its scarcity, and some industry participants suggest blending the green fuel with existing gray methanol could alleviate the shortage for now. The Platts sustainable-gray methanol price slider uses the month average prices of delivered sustainable methanol bunker and FOB gray methanol in the US Gulf plus logistics cost to show a representation of the blended price of marine methanol. Biofuel blend Bioblends are emerging as the top choice as an alternative marine fuel for conventional ships as regulators introduce new rules to lower greenhouse gas emissions from shipping. The Platts UCOME-VLSFO price slider uses the month average prices of FOB Straits used cooking oil methyl ester plus logistics cost and delivered 0.5%S marine fuel oil to show a representation of the blended price of biobunker fuels. LNG blend LNG, with its accessibility and competitive pricing, has long been the most used alternative marine energy for shipowners willing to invest in alternative propulsion technology. A growing number of companies operating LNG-capable ships are introducing bio-LNG into their bunker mix for deep decarbonization, and market participants suggest the more expensive green fuel could be blended with fossil LNG -- possibly through mass balance -- for lower fuel expenses. The Platts bio-gray LNG bunker price slider uses monthly average delivered bunker prices of bio- and fossil LNG in Rotterdam to show a representation of the blended price of marine LNG. Further reading: INTERVIEW: Ammoniaâs share may be 40% of global bunker fuel demand by 2050--Amogy CEO INTERVIEW: Japan's MOL sees Southeast Asia as long-term growth engine ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/120121-gas-rally-to-have-enduring-effect-on-european-power-beyond-near-term-platts-analytics</link><description>European power prices are forecast to ease from current record levels starting in 2023, but the current rally in gas will have enduring effects on the forward curve, according to S&amp;amp;P Global Platts Ana</description><title>Gas rally to have &amp;apos;enduring effect&amp;apos; on European power beyond near term: Platts Analytics</title><pubDate>01 December 2021 09:58:00 GMT</pubDate><author><name>Andreas Franke</name></author><content><![CDATA[ 01 Dec 2021 | 09:58 UTC Gas rally to have 'enduring effect' on European power beyond near term: Platts Analytics By Andreas Franke Highlights Prices to ease from 2023, but remain elevated Germany swings to imports, Great Britain to exports Italy moves to top, Spain becomes discount market European power prices are forecast to ease from current record levels starting in 2023, but the current rally in gas will have "enduring effects" on the forward curve, according to S&amp;P Global Platts Analytics. Its latest five-year forecast sees annual power prices dropping from average levels above Eur100/MWh in 2021 and 2022 to around Eur80/MWh for 2023-24 and down to around Eur60/MWh by 2026-27. For Germany, the five-year forecast average is now double compared to actual average prices over 2016-2020. "The gas-driven surge in power prices in recent months is likely to have enduring effects beyond the near-term," Platts Analytics head of European power analysis Glenn Rickson said. By 2023, the current elevated price situation will have mostly dissipated as gas storage stocks normalize and renewable penetration continues, Rickson said. "Closures of coal and nuclear capacity, particularly in Germany, add support to prices over the next two years and also increase power prices' sensitivity to gas prices and vice versa," he said. From a policy perspective, much of the noise is around accelerating decarbonization and limiting exposure to gas, while from an investment perspective, Platts Analytics expects greater appetite for low carbon flexibility, including storage, the report said. Wind to top mix from 2025 Great Britain is projected to lose its place as Europe's premium market to Italy thanks to offshore wind development and a narrowing in its carbon premium, the report said. Spain will become Europe's discount market on an annualized average basis from 2023, it said. Europe's biggest power market Germany, meanwhile, is forecast to swing to net imports by 2023. German gas-fired generation is forecast to rise above coal and lignite by 2025 for the first time ever. Across Europe, gas generation is set to dip from 2019's peak until 2023 before recovering to 2021 levels by 2027. Nuclear is forecast to fall almost 25% below 2021 levels by 2027 despite the start-up of Hinkley Point C. Wind capacity is forecast to grow by roughly 100 GW to 263 GW by 2027, with wind set to top the generation for the 10 markets from 2025 assuming average weather. Gains for offshore wind capacity will help swing Great Britain from net imports to a net export position. Finally, solar capacity across the 10 markets is forecast to almost double to 276 GW by the end of 2027. Platts Analytics' European power model incorporates 10 markets: Germany, France, Great Britain, Italy, Spain, Portugal, Belgium, Netherlands, Switzerland and Austria. Editor: Jonathan Fox ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/podcasts/oil-markets/012921-asia-cold-spell-fuel-oil-crude-lng-demand</link><description>This episode examines the impact of a cold spell in Asia on fuel oil, crude, and LNG demand, highlighting market responses. Learn more.</description><title>Cold spell drives oil resurgence in Asia&amp;apos;s power sector</title><pubDate>29 January 2021 12:55:00 GMT</pubDate><author><name>Eric Yep</name><name>Andre Lambine</name><name>Takeo Kumagai</name><name>Rajesh Nair</name></author><content><![CDATA[ 29 Jan 2021 | 12:55 UTC Listen: Cold spell drives oil resurgence in Asia's power sector Featuring Eric Yep, Andre Lambine, Takeo Kumagai, and Rajesh Nair The last few weeks saw temperatures in many parts of North Asia drop to record lows, and energy prices hit record highs. Platts JKM, the benchmark for Asian spot LNG prices, surged to $32.50/MMBtu, the highest since it was launched in early 2009. LNG freight rates hit unprecedented levels of nearly $300,000/day, trucked LNG in China rose to around $28/MMBtu, Japan's spot electricity prices hit 220 Yen/kWh, and the Platts Northeast Asian Thermal coal price hit $80/mt. The ripple effect was felt across a variety of power generation fuels and across the whole region as supply chains were disrupted. Utilities found themselves having to shift back to fuels that have been becoming rather obsolete in the region's power mix. S&amp;P Global Platts Senior Analyst Andre Lambine, Senior Editor Takeo Kumagai, and Managing Editor Rajesh Nair join Content Lead Eric Yep to delve deep in to the latest in Asia's oil and power sectors. Also available on: Spotify and Apple Podcasts View Full Transcript Cold spell drives oil resurgence in Asia's power sector ERIC YEP: Temperatures in many parts of North Asia dropped to record lows this winter. This meant higher demand for heating fuels, power shortages, and emergency fuel procurement by governments and utilities. Several energy benchmarks, including the Platts JKM benchmark for Asian spot LNG, hit record levels. The ripple effect was felt across a variety of power generation fuels and across the whole region as supply chains were disrupted. This meant that utilities had to shift to a fuel that has been becoming rather obsolete in the power sector in many countries, fuel oil and even direct burning of crude oil. The worst of the winter seasons likely over but utilities, fuel importers, and government regulators are still assessing the aftermath of the energy crisis. Hello and welcome to the S&amp;P Global Platts Oil Market Podcast - Asia edition. I'm Eric Yep, content lead for generation fuels in Asia. And today I'm joined by Platts experts to examine the recent surge in Asia's energy demand and its impact on oil. So to discuss in more detail, we have Andre Lambine, senior analyst with S&amp;P Global Data Analytics, Takeo Kumagai, senior editor with the oil news team, and Rajesh Nair, managing editor for Asia residual fuels. Thanks for joining this podcast, gentlemen. So Andre, let's start with you. Could you give us a sense of how the power situation changed in Asia? And what led to the energy shortages in the region? (01:33) ANDRE LAMBINE: Yeah. Thank you, Eric. Yes, there's a number of factors that contributed to the situation. So first of all, like you mentioned, it got cold, like really cold, in Northeast Asia, so the demand for heating and electricity increased. So all countries including China, Japan and South Korea, they needed more thermal fuels than earlier expected. This was especially important for demand for LNG, which fuels a large portion of the power markets in Japan and South Korea, while in China, it actually tends to go more into industry. But the higher regional demand for LNG imports came at a time when there were supply disruptions in the global LNG market in places like Qatar and Australia. And there were also shipping constraints through the Panama Canal impacting LNG produced in America. It was also cold in other places such as Europe, so demand was higher also there. So all these caused the Asian spot price of LNG to reach new all time highs. As the Asian markets struggled to obtain enough LNG, the higher demand for electricity also filtered through to the coal and oil markets. And what worsened the situation this winter was somewhat lower than normal inventories, which made companies rely on spot buying to a perhaps greater extent than normal. (02:48) ERIC YEP: Could you take us through how oil fits into the power mix in Asia? And what were the reasons that we saw something like gas-to-oil switching taking place? (03:00) ANDRE LAMBINE: Great questions. Oil is a relatively small part of the power mix in most Asian countries. For places in Northeast Asia like Japan, South Korea and Taiwan, it is usually around 1% or 2% of the power mix; while it is higher in parts of South Asia with about 3% for Pakistan and up to 15% for Bangladesh. However, typically, even if oil is not a large percentage of the power mix, it's an important part of the overall picture. Often oil is relatively expensive for use in power generation so it is used to help cover peak demand periods and is also used in places without good grid connectivity such as remote islands. Now, gas-to-oil switching is taking place because spot LNG has become more expensive than fuel oil and other oil products that can be used for power generation. Most LNG is imported on long term contracts, but buyers tend to top up with some additional spot LNG when needed. But not all LNG importing countries can switch from gas to oil-fired power generation because they do not have the sufficient unused oil-fired power plant capacity. So for example, South Korea only has about 2 GW of oil capacity, and some of that is usually already in use during winter so the upside is limited. However, many other countries have available oil-fired power plant capacities such as Japan and several countries in both ASEAN and South Asia. And there perhaps especially interesting is Bangladesh and Pakistan because the timing of the situation comes at a time or the year when these countries typically see lower power demands. This is due to lower need for cooling. So there is quite a lot of unused oil-fired power plant capacity available. (04:46) ERIC YEP: Hold that thought on Pakistan and Bangladesh. We will get back to you on that shortly. Let's go over to our Tokyo correspondent Takeo Kumagai, who is right in the thick of things in the middle of winter. And I hope Takeo that you you're not snowed in right now. But can you take us through Japan's power demand and how it has resulted in fuel switching towards oil? And how has the situation played out on your end? (05:14) TAKEO KUMAGAI: Sure, Eric-san. It's been a cold winter here, and we have seen an uptick in crude and fuel oil demand in Japan as some local power utilities rush to procure more oil to meet the upsurge in power demand from severe cold spells. Japanese refiners did respond to an emergency request from the power utilities to supply more direct burning crude and fuel oil in January, according to the head of Petroleum Association with Japan on January 21. Tsutomu Sugimori, however, said the refiners do not plan to increase their direct burning crude or fuel oil supply in February and March, during when the demand will still be in the midst of the winter demand season. Sugimori's remarks underlined Japanese refiners' difficulty to increase their fuel oil output at a time when they face strong kerosene demand for heating, which is also as a result of cold spells. And there is a shortage of coastal vessels for fuel transport in Japan, after seeing lackluster oil demand for power in recent years. Japan's largest refiner ENEOS also told us recently that it has seen its fuel oil demand far exceeding the planned supply volumes and the company would have to prioritize supplying to power utilities holding supply contracts because of supply constraints and tight vessel availabilities. Japan's immediate power demand, however, peaked on January 8, and electricity demand in the first half of January jumped by about 10% from a year ago, according to the Ministry of Economy, Trade and Industry. In line with the easing of power demand, Japan's oil-fired power plant run rates fell to around 25% as of January 17, down from around 64% on January 12, according to METI, after having peaked at just about 88% on January 8. (07:30) ERIC YEP: Very interesting how the demand situation is shaping up over there. Isn't it true that Japanese power utilities have been at the forefront of dialing back on oil-fired capacity per se over the last few years? Do you see the utilities procuring more crude and fuel oil in the coming weeks as well? (07:52) TAKEO KUMAGAI: Japanese power utilities have been mothballing their oil-fired capacities as they have shifted to gas-fired power generation in recent years. Despite the increased demand for power, Japan's JERA and Kyushu Electric, for example, did not have any immediate plans to restart the oil-fired units from their complete long-term planned shutdowns. However, we are hearing that some of Japanese by utilities such as Chugoku Electric and Shikoku Eelectric are working to procure more fuel oil from Japan and abroad, while Kansai Electric is working to procure crude oil from abroad, in addition to its domestic fuel oil procurements. Japanese power utilities used to take heavy sweet Indonesian crude, such as Minas, Cinta, and Dury for power generation. We heard that there has been a sharp increase in sport heavy sweet crude purchase inquiries from Japanese power utilities around Southeast Asia recently. However, we also heard that Japanese utilities will likely struggle to find any heavy sweet crude cargoes available for second half of January shipments in Southeast Asia. And we're better off for looking for fuel oil cargoes from Singapore for prompt imports. Now the focus is about how much more fuel and crude oil will be procured by Japanese by utilities by March in order to meet the winter demand. (09:34) ERIC YEP: Thank you. So we hope to be on top of the situation as it develops over the next few weeks and wishing you warm weather over there very soon. Let's move over to Rajesh, our resident guru on fuel oil markets. Rajesh, can you take us through how the increase in power demand has impacted fuel oil markets? And is there enough fuel oil available in the system from refiners and traders and storage to meet this increase in winter demand? (10:05) RAJESH NAIR: Hi Eric, for sure. Not so much a guru though. But first of all, the start of the year has traditionally always been good from a demand perspective for the Asian fuel oil markets, in that typically both buyers and sellers are usually looking to pile on product after destocking for the financial year end in December. Now incremental demand for low sulfur material from the utility sector, especially for markets that have traditionally relied instead on cleaner burning fuels like LNG, has prompted LSFO suppliers in Singapore, especially, to sit up and plan balances in January in a way that they haven't had to for most of last year when availability was ample. Incremental demand has in fact not only been limited to low sulfur fuel oil, but also for medium to high sulfur fuel oil from regional markets like Pakistan, Bangladesh, Sri Lanka, Philippines, and for this time of the year, also from the Middle East, especially Kuwait, as the state-owned KPC's Mina Abdullah refinery, which normally supplies product to meet domestic demand undergoes upgradation works. This so-called double whammy of demand from the regional utility market and from sellers looking to restock after running down inventories in December has somewhat tilted the demand-supply balances. Market sources estimate Western arbitrage fuel oil volume of just over 2 million metric tons to arrive in Singapore for January, down about 500,000 to 600,000 metric tons from what we saw coming in for December. No surprise then that Singapore's commercial onshore residue stocks have edged down for two consecutive weeks to 22 million barrels in the week ended January 20. And according to traders, stock held on floaters off Singapore waters is also being drawn down. So the overall market sentiment is bullish. No doubt, reflecting this sentiment, the Singapore Marine Fuels 0.5% Sulfur cargo markets premium to the Mean of Platts Singapore Marine Fuels 0.5% Sulfur assessment has hit a near 11-month high of $4.7/mt on January 21. Also the market structure, which is generally an indication of market sentiment, in the case of Singapore Marine Fuel 0.5% Sulfur swaps curve, the prompt-month market structure is currently trading at a near one-year high. So that sort of explains the overarching upbeat sentiment that's in the market at the moment, Eric. (12:41) ERIC YEP: Thanks, Rajesh. Can I check with you how other consumers of fuel oil are coping with the situation especially the marine and bunker fuel market here in Singapore and also other parts of Asia that rely very heavily on fuel oil for marine fuel? (13:02) RAJESH NAIR: Yeah of course, Eric. As I mentioned just now, January has witnessed a double whammy of sorts in terms of demand. Typically it's at the start of the year that you know, people would start looking at restocking and that's not only on the supply side, it is the case for the buyers as well. And this also coincided with the cold snap, which led countries like Japan, which hasn't traditionally relied on oil for a number of years now, to start looking at oil to meet its utility demand. Now, this is also coinciding with demand for bunkering. Let me explain. The mainstay demand center for fuel oil is the marine fuel market and will continue to be that. And as I said, the beginning of the year is traditionally good in terms of demand. We have seen steady demand from the end-user marine fuels market in January. In terms of the spot market demand though, on the whole so far this month, the demand has not been particularly fantastic and that's essentially on account of a surge in the flat price, which, as we speak, is at almost a one-year high. But that said, demand is still said to be robust, especially from buyers that have inked contracts for January supply. Now, aside of that, even for bunker markets from within the region, we have seen steady demand for product to be shipped out of Singapore to meet regional bunkering demand, especially South Korea, for instance, which is usually a balanced market, if not long, in terms of their domestic bunker demand. At least two out of the four refiners, as we know it, have been importing fuel oil from Singapore to meet their domestic bunker demand and even more so, because the refiners had cut run rates owing to poor middle distillate margins. We are also seeing a steady demand to supply product to bunker markets, like Hong Kong and also high sulfur fuel oil into China. So overall, the market sentiment is that of optimism. A surge in flat price, however, has meant that some of the sellers have been able to make determined offers in a bid to attract buying interest within the spot market itself. This has in turn led spot market differentials for Singapore low sulfur marine fuel to be rather range-bound, trading in the low to mid teen levels so far this month. But that said, looking forward, what we see is that the Singapore ex-wharf contracts for Marine Fuel 0.5% bunker supply for February-loading is currently being discussed at a premium of anywhere between $5 to $6/mt, up from around $2, $2.50 at which these contracts were inked for January supply. So yeah, on the end-user side, too the market sentiment looks generally upbeat. (15:52) ERIC YEP: Great overview, Rajesh. Thanks a lot. Let's sail over to South Asia. We can't fly in the current pandemic. Andre, take us through some of the fuel switching market fundamentals in South Asia and how is the situation playing out in Bangladesh and Pakistan? How do you see the power situation there shaping up? (16:14) ANDRE LAMBINE: So you know, to me, Bangladesh is a key lead indicator for gas-to-oil switching in Asia. And that's due to really good data availability, and also the composition of the power mix and a power plant capacities that leave room for oil. So what we have seen so far in January is that power demand has been higher. But the grid-connected generation of gas-fired power plants actually fell by about 1.5 GW on average year on year. At the same time, oil-fired power generation increased with the same amount so oil increased on the expense of gas. Bangladesh has had problems obtaining bids for recent spot tender for LNG and is likely short on gas, and we assume Pakistan is in a similar situation. So all these countries can do switching. Now oil-fired power plant capacity in Bangladesh is about 7 GW, and Pakistan has around 8 GW. While we do not think these countries will fully utilize the existing oil capacity, we assume switching to oil-fire power generation could reach a combined 4 GW for January, and this could go even higher in February. Existing long-term supply contracts for LNG usually come with little flexibility, so this could limit the switching. Some switching could also take place in March, but this situation is not as clear cut as for January and February. It will come down to power plant efficiencies and the margin will just not be as high as what we see for February. In general, power demand is likely to stay around normal for this time of year as the weather forecast has come down to normal levels for the next couple of weeks. (17:52) ERIC YEP: Thanks, Andre. Rajesh can I dial back to you know about this whole theme of oil-fired power generation capacity and the way it is being phased out over the last few years? Even here in Singapore we don't really burn oil for power generation anymore, although it's still happening in a lot of countries. Do you see the recent events this winter forcing a rethink among either refiners or fuel suppliers on fuel switching? And does fuel oil still have a future in Asia's power mix? (18:26) RAJESH NAIR: That's a very interesting question. One thing that the market might sort of want to do going forward, especially taking into consideration what is currently going on at the moment, is to perhaps better plan their balances going forward, especially when we are talking about going into peak winter season demand. As you rightly said, especially countries like Japan, which used to back in the day be a fair demand center for low sulfur fuel oil has completely switched to cleaner burning fuels. This year around it sort of was a bit of a jolt, so to speak, in terms of demand that arose from markets like Japan, and even for that matter, Korea, which, you know, we've seen at least three cargoes if not more, for utilities going into Korea so far this year. So this is all essentially incremental demand that we saw and very unlike what we would see, especially this part of the year. But that said, to answer your question, in terms of the fuel oil as a burning fuel within the burning mix, and as Andre sort of pointed, there is more than a handful of countries within this region which needs to up its power generation capacity. And as that capacity goes up, even as there is more reliance on cleaner burning fuels, we do see an opportunity for fuel oil to find that incremental demand going forward. And as such, even now when we talk about fuel oil demand into the utilities market, we're seeing pockets of demand which depending on the demand supply balances then can be rather strong positive for the market. Talking about markets like Pakistan and Bangladesh, you know, from where we've seen fairly steady demand for fuel oil, even Sri Lanka or even Philippines, the one giant demand center that I have so far missed out on talking about is, of course Saudi. Peak summer season utility demand for Saudi is estimated to be a little over 3 million mt a month and that is significant. And that is only the utility demand that we're talking about. Then, of course, we also have demand for industrial applications. Again, if you're talking about Saudi Arabia, there is a fair amount of fuel oil that goes into the desalination plants. So it doesn't look like at all that fuel oil as a burning fuel is going to be completely phased out anytime in the near or foreseeable future, Eric. (20:48) ERIC YEP: That was a fantastic overview, Rajesh. Thank you very much. I guess this whole situation highlights how critical the whole energy transition conversation in Asia is at the moment and how carefully both governments and companies would have to evaluate their dependence on individual fuels. It also highlights how the conversation around carbon emissions from fossil fuel burning can evolve over the next few years, especially if countries have to consider critical demand seasons, like winter, for instance. That is all that we have for today's podcast. Thank you very much for joining us. And thank you very much, Andre, Takeo and Rajesh for your insights. ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/european-energy-insights-october-2021</link><description>European Energy Insights October 2021 covers energy market trends, pricing dynamics, and regional supply-demand conditions.</description><title>European Energy Insights October 2021</title><pubDate>10 November 2021 18:30:00 GMT</pubDate><content><![CDATA[ Blog â 11 Nov, 2021 European Energy Insights October 2021 Here you will find a collection of this monthâs top European energy insights. Want to stay informed? Subscribe to receive our monthly insights directly to your inbox > Learn more about Market Intelligence Request Demo ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/coal/032321-australia-flooding-tightens-regional-thermal-coal-supply-supports-prices</link><description>Flooding in eastern Australia tightens thermal coal supply, bolstering prices as mining operations and supply chains face significant disruptions.</description><title>Australia flooding tightens regional thermal coal supply, supports prices</title><pubDate>23 March 2021 11:46:00 GMT</pubDate><author><name>Neka Liau</name><name>Jessie Li</name><name>Weng Yi-Le</name><name>Carina Li and Eric Yep</name></author><content><![CDATA[ 23 Mar 2021 | 11:46 UTC â Singapore Australia flooding tightens regional thermal coal supply, supports prices By Neka Liau, Jessie Li, Weng Yi-Le, and Carina Li and Eric Yep Highlights Thermal coal exports affected by disruption to deliveries, shipments Spot coal prices to jump on supply disruptions, Platts Analytics says Met coal participants wary of weather developments in Queensland Singapore â Asian thermal coal supply is expected to tighten due to the floods in eastern Australia that have disrupted rail freight, impacted loading operations and are likely to delay shipments in the coming days as weather conditions worsen, but the impact on metallurgical coal operations has so far been limited, according to analysts and sources. Tighter supply from the Port of Newcastle is supportive for thermal coal prices, and comes just ahead of India's usual strongest demand period over April and May, when buyers restock for the monsoon season, which usually runs from May to September. Other importers exposed to extreme Australian weather include South Korean utilities, which have already expressed buying interest in Indonesian coal following recent closures of nuclear reactors in the country, according to sources. They might be forced to look further afield to alternatives like Russian high calorific value coal. Chinese power utilities are not expected to have major requirements for coal, although some bullish sentiment has been noted from downstream consumers, sources said, while Japan has ample renewables electricity generation and generation fuel inventories coming out of the peak winter season, reducing its need for thermal coal. Spot coal prices to jump "The port of Newcastle handles around 70% of Australia's thermal coal exports, and around 15% of its met coal exports. The wet weather is expected to continue until March 24, and it could be the end of March before all railings to port return to normal," Matthew Boyle, S&amp;P Global Platts Analytics' lead analyst for Global Coal &amp; Dry Bulk Freight, said. Boyle said however that the Australian thermal coal export forecast for 2021 of 199 million mt had not been adjusted due to the floods or issues with coal shiploaders at the NCIG terminal, and coal stocks at ports were adequate to continue shiploading despite a lack of coal railings to port. "We expect coal producers will look to make up lost exports in the second quarter of 2021, so the overall impact on exports, when considered on an annual basis, will be limited," Boyle said. "We do however expect spot coal prices to jump on the supply disruptions," he said, adding that high calorific value thermal coal prices were already indicated above $90/mt FOB Newcastle and could climb to the $100/mt level on news of the floods by the end of March. "This would be a near-term resistance price level, and if breached, which we believe it could, would hit an almost two-and-a-half-year high," Boyle said. S&amp;P Global Platts assessed the price of Newcastle 5,500 NAR at $57.50/mt on March 23, up 50 cents on day. Muted impact on met coal Metallurgical coal market participants said there was minimal disruption to Bowen Basin production in Queensland state, but they will be monitoring higher water levels at rivers and creeks. Rainfall at mining sites in Central Queensland and ports is expected to continue for a few weeks amid the monsoon season. "We lost two or three days of production at both sites last week. I would expect to see similar falls this week," a coal producer said. An international trader said that there had not been "any material impact on mining and logistics" so far, but noted that it would "take time to fully assess the damage or rail washouts inland." "The weather disruption could make an already tight market even tighter," the trader added. The uptick in thermal coal prices has resulted in higher prices for other grades of metallurgical coal, mainly weaker grades of met coal like pulverized coal injection and semi-soft. This is because the pricing of these grades of coals are interlinked depending on their energy composition. As thermal coal prices move up due to the floods, a producer can also command higher prices for the pulverized coal injection and semi-soft. A Northeast Asian trader described the market for weaker coals as a "sellers' market" in the near term. Price spreads between premium hard coking coal and weaker metcoal grades have narrowed due to differing market dynamics --- the premium hard coking coal is cheaper due to ample supply as China has been blocking imports from Australia, while prices of pulverized coal injection and semi soft are higher due to the floods. S&amp;P Global Platts assessed Premium Low Vol Coking Coal, a premium hard coking coal, at $111.50/mt FOB Australia March 22, down $1/mt on day. The ratio between premium hard coking coal and pulverized coal injection stands at 96%, and 89% for semi-soft, based on Platts assessments basis FOB Australia March 22. Both ratios had been the highest since the indexes were launched in October 2011. Editor: Alisdair Bowles ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/033122-geopolitical-risk-dominates-outlook-for-europes-energy-carbon-markets-in-q2</link><description>Gas one incident away from fresh spikes Low nuclear, hydro weaken power resilience Demand downside risk for carbon market Already dazed from months of extreme volatility, Europe&amp;apos;s energy markets enter</description><title>Geopolitical risk dominates outlook for Europe&amp;apos;s energy, carbon markets in Q2</title><pubDate>31 March 2022 13:42:00 GMT</pubDate><author><name>Stuart Elliott</name><name>Andreas Franke</name><name>Frank Watson</name></author><content><![CDATA[ 31 Mar 2022 | 13:42 UTC Geopolitical risk dominates outlook for Europe's energy, carbon markets in Q2 By Stuart Elliott, Andreas Franke, and Frank Watson Highlights Gas one incident away from fresh spikes Low nuclear, hydro weaken power resilience Demand downside risk for carbon market Already dazed from months of extreme volatility, Europe's energy markets enter the second quarter of 2022 with no sign of a let-up in the daily turmoil brought on by the conflict in Ukraine. The gas market -- already bowing under the weight of record high prices -- is set for further unprecedented change as the EU looks to slash demand for Russian gas and new storage obligations shift trading dynamics. The TTF day-ahead price hit a new all-time high of Eur212/MWh ($233/MWh) on March 7, according to S&amp;P Global Commodity Insights assessments, a 1,190% increase year on year, as the fall-out from Russia's invasion of Ukraine on Feb. 24 continued to roil markets. Fundamentals of supply and demand have largely given way to price movements driven by the Ukraine war and the related gas-focused responses from both Europe and Russia. The radically changed geopolitical landscape has fed into the gas market, with the EU taking swift action on storage and supply security, imposing mandatory storage obligations on member states in a bid to avoid a repeat of concerns over stock levels this winter. European storage sites were filled to just 77% of capacity last summer, with facilities 26% full as of March 30, according to data from Gas Infrastructure Europe. The first regulatory phase under the EU's storage reforms will see member states obliged to fill storages to 80% of capacity by Nov. 1, 2022, with intermediate targets through the year that must also be met. The traditional gas injection season in Europe begins in April, but it remains to be seen whether there will be sufficient gas supply to help boost inventories at a time when Russian flows remain curtailed. The US has pledged an additional 15 Bcm of LNG this year to help Europe, with other suppliers such as Azerbaijan and Norway also pumping at maximum capacity. Russian deliveries via Ukraine have increased to their contractual maximum since Moscow's invasion as spot prices surged, making Russian gas delivered under long-term contracts more competitive. However, Russian flows through the Yamal-Europe line remain erratic and mostly at zero. Any impact from hostilities on the transit system in Ukraine would likely trigger more panic on European gas markets. EU leaders have also agreed to set up a joint gas procurement mechanism to present a more unified stance toward sellers, and details of the initiative are likely to emerge in Q2. The EU finds itself in a difficult position, however. It still needs Russian gas to fill storage sites through Q2 but has also pledged to cut demand for Russian gas by two thirds by the end of 2022. Analysts at S&amp;P Global Commodity Insights believe gas prices will remain supported by continued concerns over Russian supply reliability which, in turn, prompts other suppliers to target Europe to provide alternatively sourced gas. Norway continues to pump at maximum levels, regularly breaching the 350 million cu m/d export level to markets in Europe, while LNG is also expected to come in large volumes in Q2 after high supplies in Q1. "Platts Analytics forecasts continued strong LNG deliveries and record Norwegian gas production for Q2, with production permits increased, maintenance delayed, and gas over oil prioritization continuing," it said. Norway's Aker BP is pivoting toward gas at its Skarv field, while Equinor plans to maintain higher gas output at its Heidrun, Osberg and Troll fields after increased production permits were approved by the energy ministry. High prices are also leading to some European demand curtailments that are set to continue through Q2. "Industrial and power sector gas demand destruction and switching are also forecast to continue, with residential/commercial demand in Europe now trending below 2018-2021 averages," S&amp;P Global analysts said. Low nuclear hampers diversification Ramping up Europe's remaining coal plants could reduce Q2 gas-for-power demand by 6 Bcm in Europe's main markets, but long-term low nuclear generation is set to offset the bulk of these efforts. "Europe is about to head into a summer with significant risk of tightness due to low French nuclear availability and low hydro stocks in Southwest Europe which has the potential to see a feedback loop of regional power prices chasing each other higher in order to attract net imports," S&amp;P Global Commodity Insights' head of European power analysis Glenn Rickson said. S&amp;P Global forecasts a year-on-year decline in Q2 nuclear output of around 24 TWh, the energy equivalent of 4.5 Bcm of gas. Elsewhere, solar and wind capacity gains and the prospect of demand destruction due to high prices could help further offset the loss of nuclear. Nevertheless, France has become the premium market with Q2 baseload in a range of Eur250-300/MWh for much of the second half of March, EEX data showed. New French links to Italy (the 1.4 GW Piedmont-Savoy) and Britain (the 1 GW ElecLink) are to start commercial operations during the period. Closer to the conflict, Finland's new 1.6-GW Olkiluoto-3 nuclear reactor is set to produce some 3 TWh in Q2 ahead of commercial production in July, reducing imports of Russian electricity that climbed to 9 TWh in 2021. In summary, European power's ability to turn down gas demand this spring and summer is limited by relatively low hydro stocks, weak nuclear and supply constraints at coal and lignite plants. Anticipated demand destruction, with Q2 demand projected some 0.8% lower year on year assuming average temperatures, offers little hope for hard-pressed consumers enduring costs some way beyond their worst projections. "A return to business as usual is hard to imagine [with] the coming weeks and months likely to see a series of wide-ranging policy responses which will likely be as severe an intervention into Europe's power market design since power market liberalization began in the 1990s," S&amp;P Global's Rickson said. Downside risk for carbon Following a sharp drop in March linked to Russia's invasion of Ukraine, EU carbon prices have rebounded, leaving the outlook slightly bearish going into the second quarter of 2022. EU Allowance prices for December 2022 delivery rebounded to Eur78.38/mtCO2e at the close March 30, from a low of Eur58.19/mtCO2e on March 7. The rebound has left prices exposed to a slight downside risk going into Q2, with milder temperatures expected to limit energy demand. On the supply side, the market was also looking healthier after EU member states allocated 54% of the available pool of free allowances to industrial companies for 2022, according to European Commission figures released March 17. A total of 288 million allowances had been issued as of that date, from an eligible total of 533 million for 2022, the figures showed. Countries yet to allocate included Italy, Poland and Spain, and the volumes entering the market could limit upside for prices going into Q2. EUA prices are forecast to ease slightly to Eur77.20/mtCO2e on average in April, Eur75.40/mtCO2e in May and Eur73.60/mtCO2e in June, according to a forecast by S&amp;P Global Commodity Insights in its European Emissions Trading System Market Outlook released March 18. "The escalation of the Russia-Ukraine conflict has led to a dramatic fall in speculator and financial interest in the EU ETS market, as investors de-risk and take profits following near-record high EUA prices," S&amp;P Global said. The power sector has added bearish pressure on EUAs since escalation of the conflict, as EUAs are sold in favor of covering higher oil, gas and coal commodity prices, it said. Wider doubts over the macro-economic picture in Europe also represent a bearish risk factor for carbon prices moving into Q2. "There are concerns that EU industrial production will fall amid current high energy costs, with signals indicated by the glass and fertilizer sectors," S&amp;P Global said. "We expect power sector demand to weaken into summer 2022 with receding seasonal demand but expect uplift to winter 2022 prices with increased coal burn following reduced imports of Russian gas," it said. Upside risk factors include further disruption to natural gas supplies which could favor greater coal burn for power generation in 2022. Equally, the supply side could offer additional support for prices amid ongoing regulatory efforts to reform and expand the EU ETS, including a possible phase down of free allocation. Negotiations are ongoing among EU member states under the French presidency of the EU Council which ends on June 30. Those factors point to tighter supply over the long term, which could re-attract investor and compliance interest in carbon allowances. Editor: Daniel Lalor ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/080521-german-gas-generation-falls-35-coal-rebounds-as-margins-diverge</link><description>German gas fired power generation fell in July as record high European gas hub prices further eroded margins, while hard coal generation almost exceeded gas fired generation and lignite topped the Ger</description><title>German gas generation falls 35%, coal rebounds as margins diverge</title><pubDate>05 August 2021 15:29:00 GMT</pubDate><author><name>Thomas Schumacher</name><name>Neil Hunter</name><name>Andreas Franke</name></author><content><![CDATA[ 05 Aug 2021 | 15:29 UTC German gas generation falls 35%, coal rebounds as margins diverge By Thomas Schumacher, Neil Hunter, and Andreas Franke Highlights Lignite tops July mix TTF front-month hits 2008-high above Eur40/mt Year-ahead clean spark spread negative first time since 2019 German gas-fired power generation fell in July as record high European gas hub prices further eroded margins, while hard coal generation almost exceeded gas-fired generation and lignite topped the German power mix. TSO data aggregated by Fraunhofer ISE shows that gas generation totaled 3.3 TWh in July, down 35% year on year as gas prices hit the highest levels on record. July Generation Generation Type July output (TWh) Year-on-year change (%) Month-on-month change (%) Solar 7.01 -1% -12% Wind 6 -15% 34% Lignite 7.29 15% -8% Hard Coal 3.1 111% 16% Gas 3.29 -36% -19% Nuclear 5.52 30% 12% Biomass 3.32 -13% -5% Hydro 1.76 2% -13% Imports 1.07 135% 37% Other 0.39 129% 3% Source: Fraunhofer ISE Storage concerns heading into the winter gas season and ongoing supply constraints continue to support prices in Europe, with Dutch TTF gas prices climbing above Eur40/MWh. Fundamentals in Europe are just part of the reason global gas prices have hit significant highs, with JKM and Henry Hub prices hitting significant levels of $15/MMBtu and $4/MMBtu, which saw European LNG imports in July fall to their lowest levels since January. The quarter-ahead Dutch TTF gas contract climbed 15% in July, while EUAs went in the opposite direction. After hitting an all-time high of Eur57.87/MWh on July 5, the December 2021 EUAs contract shed 10% in the remainder of the month. This saw coal- and gas-fired power margins diverge, with the German quarter-ahead clean spark spread for a 50%-efficient CCGT hitting a three-year low by the end of the month. Conversely, the equivalent dark spread for 45%-efficient plants recently hit its highest levels on record, according to S&amp;P Global Platts data that dates back to 2017, despite an increase in coal prices. According to Platts assessment data, the quarter-ahead CIF ARA coal contract hit its highest levels since September 2011. Negative clean sparks Challenging conditions for German gas plants are priced to extend into 2022, as Platts year-ahead clean spark spread with CSS (50% efficiency) assessment turned negative on Aug. 4 for the first time since April 2019 as the TTF 2022 gas contract rose above Eur28/MWh. According to S&amp;P Global Platts Analytics' latest five-year forecast published Aug. 4, German gas-fired output will rise above the 2020 high from next year on the back of nuclear, lignite and coal closures, averaging around 9 GW throughout the forecast period. All six German reactors are set to shut by the end of 2022, while Germany has auctioned over 8 GW of coal closure compensation since December 2020, bringing 2022 capacity well below 15 GW. RWE is also set to shut another 2.5 GW of lignite unit, mainly linked to the Hambach mine, by the end of 2022. Germany's leading candidate to replace Chancellor Angela Merkel after the Sept. 26 election, Armin Laschet (CDU), has rejected calls by the Greens and its sister party CSU to re-negotiate coal exit dates. Laschet added, however, that higher carbon prices could lead to quicker-than-anticipated coal closures achievable by 2030 in Western Germany. Holding back Short-term prospects for gas-fired generation, meanwhile, may have taken another hit in August delivery, as lower Russian gas flows through Yamal in Germany have given prices one less reason to fall, leaving Europe further exposed to global gas price strength. After a consistent flow of 81 million cu m/d throughout summer, net imports at Yamal's Mallnow terminus have slipped to 49 million cu m/d. Both German and Polish transit networks have told Platts that this is due to market behavior, and no upstream issues have been reported on the Russian side. While aggregate German storage is now over half full, this is still well below the 89% fill this time last year, Gas Infrastructure Europe data showed. Gazprom's Rehden storage facility in Germany is just 12% full, after beginning summer at 9.5%. With little change in onward transport to Central and Southern Europe, German imports have been affected the most, at a time when as much gas as possible is needed for storage, and indeed for power generation. Also supportive of prices is an evident lack of winter volumes on the market that would be delivered by Nord Stream 2 if it wasn't forbidden from operating. A similar situation was seen ahead of the signing of the Russia-Ukraine transport accord, which saw short-term volumes collapse after the agreement, and winter prices supported before it. Nord Stream 2 has the potential to facilitate a major fuel switch towards gas in Germany, should its purpose not be to avoid costly transport through Poland and Ukraine, for which just a few years of operation would completely offset and provide a return on investment. However, without a U-turn by German regulator BNetzA on exemption from production-transmission unbundling, and further assent from the European Commission that Nord Stream 2 does not contravene the principles of energy union, fuel switching and price compression potential seem unlikely for some time to come, especially if non-contract Russian volumes to Germany continue to be withheld until said derogation is granted. Editor: Jonathan Fox ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/blog/energy-transition/043026-indias-power-and-renewables-market-demand-stalls-capacity-rises</link><description>India&amp;apos;s power sector reached a turning point in fiscal year 2025-26 (April 2025-March 2026), as record renewable capacity additions of 51 GW coincided with the first annual contraction in electricity demand since the pandemic. </description><title>India&amp;apos;s power and renewables market: Demand stalls, capacity rises</title><pubDate>30 April 2026 06:58:38 GMT</pubDate><author><name>Gautam Sood and Md. Jawed Alam</name></author><content><![CDATA[ Electric Power, Energy Transition, Nuclear, Renewables April 30, 2026 Indiaâs power and renewables market: Demand stalls, capacity rises Gautam Sood and Md. Jawed Alam Editor: Roma Arora Getting your Trinity Audio player ready... India's power sector reached a turning point in fiscal year 2025-26 (April 2025-March 2026), as record renewable capacity additions of 51 GW coincided with the first annual contraction in electricity demand since the pandemic. The unusual combination stemmed from prolonged monsoon conditions that suppressed cooling demand and accelerated clean energy deployment, according to Central Electricity Authority data and S&amp;P Global Energy CERA analysis. Energy demand contracts marginally Electricity demand in FY 2025-26 contracted 0.3%, falling to about 1,690 terawatt-hours from 1,695 terawatt-hours in FY 2024-25, according to CEA data. This muted demand was largely due to milder summer temperatures and the early onset of the monsoon, which reduced cooling requirements during peak demand months, according to CERA analysis. Looking ahead, CERA expects electricity demand to rebound 4.7%-5.4% between April and December. However, this outlook remains below earlier projections of 6.0%-6.6% for calendar year 2026, as GDP growth slows due to ongoing geopolitical disruptions stemming from the Middle East conflict, according to S&amp;P Global Market Intelligence. Renewables drive capacity expansions India's installed capacity reached 533 GW by March, rising 12.2% year over year from 475 GW, according to CEA data. Renewables drove this expansion, contributing 51 GW of the total 62.4 GW added during FY 2025-26. Installed renewable capacity reached 223.3 GW, up 29.5% year over year from 172.4 GW in March 2025. India is expected to add 38.5 GW of new capacity between April and December , with renewables accounting for 30.5 GW, according to CERA. Conventional capacity additions are projected at 3.7 GW of coal, 1.1 GW of hydro, 1.0 GW of nuclear and 2.2 GW of battery storage. Power exchanges gain market share Electricity trade through India's three power exchanges -- Indian Energy Exchange, Hindustan Power Exchange and Power Exchange India Limited -- reached about 158.7 TWh in FY 2025-26, accounting for about 9.4% of India's total electricity demand, according to the data compiled by CERA. This represented a strong year over year growth of nearly 16%, driven primarily by higher open access participation and increased power cost optimization by distribution companies. Thermal generation displacement Overall electricity generation in FY 2025-26 increased marginally by 0.2% year over year to 1,817 TWh, according to CEA data. Renewable energy generation surged 19.7% to 301 TWh from 252 TWh, increasing its share to 16.6% from 13.9% in FY 2024-25. This renewable surge displaced conventional generation. Coal-fired generation declined 3.9% year over year to 1,280 TWh. Gas-based generation fell by 17.4% to 26 TWh, accounting for just 1.4% of total generation. During the January-March period, the rapid expansion of renewable capacity translated into strong growth in renewable power generation. Renewable output increased by more than 21% year over year, reaching nearly 75 TWh, compared with 62 TWh, according to CEA data. As renewables continued to gain a larger share of the generation mix, coal-based generation declined modestly. Coal output fell by about 1.5% year over year to 337 TWh in January-March 2026, down from 342 TWh. Renewable momentum Activity in the renewable energy certificate market strengthened significantly during FY 2025-26, with traded volumes rising by 51% year over year to about 50 million certificates, according to IEX data. Prices softened modestly, declining by about 3% year over year but remaining broadly stable within the $3.6-$4.0/MWh range. In the January-March 2026 period, REC transactions increased at a slower 8% year over year to about 15.7 million certificates, according to IEX data, reflecting weaker short-term demand conditions. On the procurement side, renewable tendering activity remained robust during FY2026, with a total of 24â¯GW of capacity awarded through competitive bids. However, procurement momentum weakened in the January-March period, with awards falling to 7.6â¯GW, a 12% year over year decline. The slowdown reflects growing caution among procurers as curtailment risks and integration challenges become more pronounced, even as longâterm renewable capacity expansion targets remain unchanged. Curtailment represented 0.27% of the total variable renewable generation during the January-March 2026 period, according to NLDC data. Renewable energy curtailment rose sharply by about 200% year over year to 184â¯GWh, up from 61â¯GWh, indicating that while seasonal demand provided some support, underlying grid integration and flexibility challenges remained unresolved. Path forward India's power sector faces a delicate balancing act. The country must sustain renewable capacity additions -- CERA projects 30.5 GW between April and December 2026, representing 79% of total expected capacity additions, while simultaneously investing in transmission, storage and grid flexibility to ensure a reliable electricity supply. The sector has proven it can deploy renewable capacity at record speed, adding 51 GW in FY 2025-26 alone. The harder challenge now is building the ecosystem to effectively utilize that capacity. With Ashish Singla. Further reading: India Power and Renewables Market Briefing: Q2 2026 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/102621-updated-climate-commitments-still-falling-short-of-global-temperature-goals-unep</link><description>New and updated climate commitments from governments still fall short of the effort needed to reach the goals of the Paris Agreement on climate change, the United Nations Environment Program said in a</description><title>Updated climate commitments still falling short of global temperature goals: UNEP</title><pubDate>26 October 2021 14:42:00 GMT</pubDate><author><name>Frank Watson</name></author><content><![CDATA[ 26 Oct 2021 | 14:42 UTC Updated climate commitments still falling short of global temperature goals: UNEP By Frank Watson Highlights Eight years left to almost halve emissions: UNEP Eyes on closing global 'emissions gap' as COP26 summit looms UNEP highlights potential for methane and carbon markets New and updated climate commitments from governments still fall short of the effort needed to reach the goals of the Paris Agreement on climate change, the United Nations Environment Program said in a report Oct. 26. Current commitments by countries leave the world on track for a temperature rise of at least 2.7 degrees Celsius this century -- well above a global goal to limit warming to 1.5 degrees C above pre-industrial levels. "Climate change is no longer a future problem. It is a now problem," said UNEP Executive Director, Inger Andersen. "To stand a chance of limiting global warming to 1.5 C, we have eight years to almost halve greenhouse gas emissions: eight years to make the plans, put in place the policies, implement them and ultimately deliver the cuts. The clock is ticking loudly," she said in a statement. The report found that countries' updated Nationally Determined Contributions -- and other commitments made for 2030 but not yet submitted in an updated NDC -- only take an additional 7.5% off predicted annual greenhouse gas emissions in 2030, compared with the previous round of commitments. Reductions of 30% are needed to stay on the least-cost pathway for 2 degrees C and 55% cuts for 1.5 C, it said. Coming ahead of the UN Climate Change Conference in Glasgow Nov. 1-12, UNEP's report found that net-zero emissions pledges could make a big difference. "If fully implemented, these pledges could bring the predicted global temperature rise to 2.2 C, providing hope that further action could still head off the most catastrophic impacts of climate change. However, net-zero pledges are still vague, incomplete in many cases, and inconsistent with most 2030 NDCs," UNEP said. To have any chance of limiting warming to 1.5 C, the world has eight years to take an additional 28 billion mt of CO2 equivalent greenhouse gases off global emissions, over and above what is promised in the updated NDCs and other 2030 commitments, it said. "To put this number into perspective, carbon dioxide emissions alone are expected to reach 33 gigatons [billion mt] in 2021. When all other greenhouse gases are taken into account, annual emissions are close to 60 Gt CO2e. "So to have a chance of reaching the 1.5 C target, we need to almost halve greenhouse gas emissions. For the 2 C target, the additional need is lower: a drop in annual emissions of 13 Gt CO2e by 2030," UNEP said. Focus on methane, carbon markets Methane emissions in particular offer a massive opportunity to curb the global temperature rise, UNEP said, as the gas is 80 times more potent than CO2 over a 20-year period. "Available no- or low-cost technical measures alone could reduce anthropogenic methane emissions by around 20% per year," UNEP said. Along with broader structural and behavioral measures, this reduction figure could be expanded to 45% per year, it said. "Carbon markets, meanwhile, have the potential to reduce costs and thereby encourage more ambitious reduction pledges, but only if rules are clearly defined, are designed to ensure that transactions reflect actual reductions in emissions, and are supported by arrangements to track progress and provide transparency," UNEP said. Closing 13 billion mt gap Highlighting the scale of action needed to achieve global temperature targets, global emissions from fossil fuel combustion are expected to reach 34.17 billion mt in 2040 under a September 2021 Reference case by S&amp;P Global Platts Analytics. That is almost 13 billion mt above the 21.25 billion mt forecast under Platts Analytics Two Degrees Outlook for 2040. Both scenarios are based on Platts Analytics' Global Integrated Energy Model. The emissions gap identified by UNEP, Platts Analytics, the International Energy Agency and dozens of think-tanks and industry groups, carries implications for a broad swathe of commodity markets because it implies that governments and industry will need to go significantly further in cutting emissions to avoid crossing temperature thresholds. Large-scale emissions abatement options include: Further displacement of coal and lignite for power generation in favor of natural gas, renewable energy and nuclear power A switch to electric and other low-carbon vehicles including fuel cell technologies and biofuels Hydrogen to displace gas in industry and buildings Biofuels and other low-carbon fuels in shipping and aviation Reducing methane emissions from venting, flaring and fugitive emissions Potential use of carbon capture and storage technologies The deployment of land-use projects and technology to absorb atmospheric carbon Energy efficiency programs in energy generation, industry, transportation, buildings and agriculture Editor: Kshitiz Goliya ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/agriculture/021722-crude-benchmarks-continue-to-rise-on-ukraine-russia-tensions</link><description>Crude price benchmarks climbed Feb. 16, with Dated Brent rising above $100/b, supported by continued tensions along the Ukrainian border.</description><title>Crude benchmarks continue to rise on Ukraine-Russia tensions</title><pubDate>17 February 2022 00:12:00 GMT</pubDate><author><name>Staff and Eric Yep</name></author><content><![CDATA[ 17 Feb 2022 | 00:12 UTC Crude benchmarks continue to rise on Ukraine-Russia tensions By Staff and Eric Yep Highlights Dated Brent rises above $100/b Crude futures later slip as US, Iran near agreement West skeptical as Russia says some troops withdrawn from border Crude price benchmarks climbed Feb. 16, with Dated Brent rising above $100/b, supported by continued tensions along the Ukrainian border. S&amp;P Global Platts assessed its Dated Brent benchmark at $100.795/b, up $3.14 on the day, and the highest since Sept. 4, 2014. American GulfCoast Select (AGS) was assessed at $94.85/b, up $1.37. Despite Moscow's claims it was withdrawing troops from the border, Western nations have continued to point out that the threat of conflict has yet to diminish, with NATO secretary-general Jens Stoltenberg warning Feb. 16 that Russia continues to increase troop numbers on the border. Crude futures fell following the assessments, after Iran's top negotiator Ali Bagheri Kani said via Twitter that the US and Iran were nearing an agreement in ongoing nuclear talks. At 2200 GMT, ICE Brent was trading at $91.79/b, down $1.49, while NYMEX WTI was trading at $90.62/b, down $1.45. The Russian Defense Ministry said Feb. 15 that it was pulling back some of its troops from the Ukrainian border after the completion of some planned military exercises. However, US President Joe Biden later said the troop movements were not verified. "An invasion remains distinctly possible," Biden said during a press conference. "Russian president Vladimir Putin's stated plans to 'partially' reduce troops near Ukraine Feb. 15, but uncertainty will persist as long as his intentions remain strategically ambiguous," Paul Sheldon, chief geopolitical adviser at Platts Analytics, said. "In any case, we still do not expect a notable curtailment of oil exports, either from US sanctions or Russia voluntarily holding back volumes." Trade -- Russian gas transport through Ukraine has been on the decline in recent years and collapsed at the start of 2022. Ukraine remains a key transit route for Russian gas to Europe, accounting for a little under 10% of Europe's gas demand in 2021. Under a five-year transit deal between Gazprom and Ukraine's Naftogaz in 2019, the Russian company agreed to send a minimum of 110 million cu m/d of gas via Ukraine to Europe under ship-or-pay terms in 2022. Gas deliveries via Ukraine at the key Velke Kapusany entry point fell sharply in January but recovered somewhat in February. Flows of 34 million cu m/d were seen Feb. 14 compared with January lows of 25 million cu m/d. Gas flows through the Nord Stream 1 pipeline have trended below capacity since Feb. 10, last seen near 1.7 TWh/d Feb. 14. -- Ukraine is a critical route for oil flows into Eastern Europe and the fringes of the EU. Ukraine moves Russian oil to Slovakia, Hungary and the Czech Republic. The country's transit of Russian crude for export to the EU was 11.9 million mt in 2021, down from 12.3 million mt in 2020, while oil transit to Belarus remained unchanged at about 800,000 mt. Last year, crude shipments via the southern branch of the Druzhba pipeline network included 5.2 million mt, or around 104,427 b/d, to Slovakia; 3.4 million mt, or around 68,279 b/d, to Hungary; and 3.4 million mt, or around 68,279 b/d, to the Czech Republic. -- Ukraine is one of the world's largest exporters of grains, with any disruption to supplies potentially impacting food security and prices. Ukraine accounts for around 13% of global corn exports, the fourth largest exporter in the world and Europe's largest by some way. Half of its exports go to the EU, with China being another major importer. The corn is used in animal feed, while the biofuel sector also takes a significant share. It is forecast to export 33.5 million mt for marketing year 2021-22 to June 30. The country accounts for around a tenth of global wheat exports, which have risen 27% so far in marketing year 2021-22 (July to end-June) to 16.1 million mt, as neighboring Russia increased its export taxes. Platts Analytics projected Ukraine will export 22.5 million mt of wheat in marketing year 2021-22. -- Ukraine is also the world's 13th-largest producer of steel and the fifth-largest exporter of iron ore by volume. Ukraine produced 21.4 million mt of crude steel in 2021, with 80% of its steel output exported. It exported 44.4 million mt of iron ore products in 2021 and imported 9.85 million mt of metallurgical coal and coke products. Ukraine raised 3.9 million mt of steel scrap, of which 616,000 mt was exported. Prices -- Oil prices first hit seven-year highs mid-January, spurred by a recovery in mobility levels, worries over spare capacity among key producing nations, slow progress in getting Iran's sanctions lifted and tensions over Ukraine. Prices for Russia's Urals crude, which ships via Ukraine, have increased since mid-December in line with global oil prices. Platts assessed Urals crude at $93.225/b Feb. 16, up $2.55 on the day. -- European gas prices have risen since mid-January as an attack by Russia against Ukraine could impact gas supplies. The benchmark European gas contract TTF day-ahead surged to a record Eur182.77/MWh Dec. 21 before falling to Eur61.28/MWh at the end of the year. By market close Feb. 16, the contract was at Eur68.075/MWh, Platts data showed. Any conflict impacting gas supplies into Europe could have knock-on impacts on power, carbon and coal prices. CIF ARA spot coal prices have risen 31% since the start of the year to be assessed by Platts at $177/mt Feb. 14. Over the year, the material has risen 173% in value. Prices in the EU Emissions Trading System hit a record Eur97.50/mtCO2e (December 2022 delivery) on the ICE Endex exchange Feb. 4, in part due to continued uncertainty over European gas stocks. The price had fallen to Eur92.87/mt by market close Feb. 14. -- Ukrainian corn prices have been rising on the back of strong global demand and Russian plans to impose export duties on grains. Ukraine FOB Black Sea corn export prices hit a seven-year high of $301/mt in May 2021. Prices then dipped to $254/mt in September but have risen steadily since to be assessed at $284/mt as of Feb. 16. Infrastructure -- Russia could close off Ukrainian ports due to its control of Crimea and Black Sea chokepoints. The Kerch Strait connects the Black Sea and the Sea of Azov and is used both ways, to supply soft commodities, and ship steel/pig iron and other raw materials from Mariupol. Russia's Azov and Rostov ports serve as both transshipment ports to load deep water vessels at the Russian port of Kavkaz and as loading points to make small parcel shipments of wheat, barley and corn to destinations in the east Mediterranean. Exports of both corn and wheat take place through a number of Ukrainian sea ports, including the southwestern Panamax-capable ports of Odessa, Pivdennyi and Chornomorsk, all of which are well away from the front line. However, they are all within easy reach of Crimea, which is currently under Russian occupation. -- The security of the Druzhba pipeline and ports are key for markets. Ukraine ships Russian oil to Slovakia, Hungary and the Czech Republic via the southern leg of the key 25 million mt/year Druzhba pipeline. Mariupol, Ukraine's main port in the Sea of Azov, is vital for pig iron and steel export from Ukraine and imports of steelmaking raw materials, particularly coking coal. In recent years, steel shipments from Mariupol have represented about a quarter of Ukraine's total exports in value terms. Any limitation of vessels through the Kerch Strait would likely affect supply routes used by Ukrainian mining and steel group Metinvest and other bulk shipping on the route. -- A cloud now hangs over the future of the Nord Stream 2 pipeline linking Russia with Germany. The future of the now complete Nord Stream 2 gas link could rest on affairs in Ukraine. EC President Ursula von der Leyen said Feb. 4 that Nord Stream 2 could not be "removed from the table" as far as sanctions were concerned and that Brussels had prepared a "robust and comprehensive" package of sanctions that it could impose on Moscow if Russia invaded Ukraine. US President Joe Biden said Feb. 15 that Nord Stream 2 "will not happen" if Russia invaded Ukraine. Platts Analytics has pushed its base case scenario for Nord Stream 2's startup to October 2022. Editor: Shashwat Pradhan ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/essential-energy-insights-october-2021</link><description>Essential Energy Insights October 2021 covers energy market developments and supply-demand dynamics across global oil, gas, and power sectors.</description><title>Essential Energy Insights - October 2021</title><pubDate>11 October 2021 18:30:00 GMT</pubDate><content><![CDATA[ Blog â 12 Oct, 2021 Essential Energy Insights - October 2021 Gain essential insights into top trends in the energy sector. Learn more about updates in ESG and Global power sectors. Learn more about Market Intelligence Request Demo ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/120821-germanys-new-government-to-speed-up-transition-via-fit-for-65-decarbonization-plan</link><description>Germany&amp;apos;s new coalition government under Chancellor Olaf Scholz plans to speed up Germany&amp;apos;s energy transition to achieve a 65% cut in CO2 emissions by 2030 on 1990 levels.</description><title>Germany&amp;apos;s new government to speed up transition via &amp;apos;Fit for 65&amp;apos; decarbonization plan</title><pubDate>08 December 2021 14:48:00 GMT</pubDate><author><name>Staff and Eric Yep</name></author><content><![CDATA[ 08 Dec 2021 | 14:48 UTC Germany's new government to speed up transition via 'Fit for 65' decarbonization plan By Staff and Eric Yep Highlights German power demand is forecast to increase to 680 TWh-750 TWh/year in 2030 Scholz coalition excluded any mention of the Nord Stream 2 project in its treaty Germany consumed 1.1 million b/d of diesel and gasoil in 2020 and 450,000 b/d of gasoline Germany's new coalition government under Chancellor Olaf Scholz plans to speed up Germany's energy transition to achieve a 65% cut in CO2 emissions by 2030 on 1990 levels. S&amp;P Global Platts reporters provide context for a country that is Europe's biggest importer of oil, gas and coal and biggest producer of electricity. Power Germany is Europe's largest wind and solar market with 120 GW capacity already installed, putting a strain on north-south power flows. Further additions may again result in negative hourly prices during offpeak days another reason for Germany's strong appetite for hydrogen. German power demand is forecast to increase to 680 TWh-750 TWh/year in 2030, up 16%-23% from pre-COVID levels in 2019. Germany is to exit nuclear generation by end-2022 while a first wave of coal closures has begun under an existing 2038 phaseout deadline. The coalition plans to boost the share of renewables in the generation mix from 65% to 80% by 2030. Phasing out coal "ideally by 2030" under the coalition agreement accelerates the need for flexible supply including new gas-fired plants that are hydrogen-ready for longer-term decarbonization conversions. German coal and lignite generation of 131 TWh for Jan.-Nov, 2021 is up 26% on year, while 2021 nuclear generation around 65 TWh is still covering 12% of power demand. Platts Analytics projects German year-ahead power prices to average around Eur70/MWh for 2023-2023, double the average price for 2016-2020. Platts assessed Platts assessed the cost of producing renewable hydrogen via PEM electrolysis in Europe at Eur16.01/kg Dec. 6 (Netherlands, including capex), based on front-month power, up fourfold since the start of the year. Natural gas Germany is the biggest gas consuming country in Europe by some distance, with demand of 87 Bcm/year. It is a modest gas producer with output in 2020 of 5 Bcm. Germany is Russian Gazprom's biggest export market with sales in 2020 of 45.8 Bcm -- a little over half of Germany's total gas demand. German gas is traded at the THE hub, which began operation in October following the merger of the Gaspool and NCG hubs. Since launch, the day-ahead THE price has averaged Eur85.08/MWh, a premium of more than Eur3/MWh over the benchmark Dutch TTF day-ahead price. Germany has one of the best connected gas markets in Europe, with direct links to imports from the Netherlands, Norway and Russia, as well as connections with other regional markets. The 55 Bcm/yr Nord Stream 2 pipeline from Russia was completed in September but awaits regulatory clearance before operation can start. The new coalition excluded any mention of the project in its coalition treaty. Based on previous declarations, the SPD is largely in favor of the pipeline, but the Green Party and FDP have previously called for the project to be halted. Germany has no LNG import infrastructure. Two terminals are under development: the 12 Bcm/year Stade and the 8 Bcm/year Brunsbuttel facilities. Related podcast: Nord Stream 2: No end in sight to long-running saga over controversial gas pipeline Oil Although oil consumption peaked in the late 1970s, Germany remains Europe's biggest oil consumer. Germany burned 2.12 million b/d of oil products last year, or 19% of the total demand in Western Europe, according to Platts Analytics. With almost no domestic production, almost all the country's oil needs are imported. In 2022, the country is expected to return to 2019 oil demand levels of 2.32 million b/d. Germany is also Europe's largest fuel market and refining hub. Germany consumed 1.1 million b/d of diesel and gasoil in 2020 and 450,000 b/d of gasoline, putting it ahead of both the UK and France. Europe's biggest refiner Rosneft is also set to become Germany's biggest refiner in 2025 after Shell shuts some units at its Rhineland refining complex. Platts assessed cracking margins for refining Russian Urals crude in the ARA hub at $2.375/b Dec. 6, down from $3.3/b at the start of the year. Like most of its European peers, Germany has seen sales of diesel and gasoline cars fall sharply since 2020 helped by incentives to promote electric cars. During the third quarter of 2021, registrations of new gasoline and diesel cars fell to 55% of total sales, with hybrid, plug-in and fully electric cars making up 44% of sales, according to sector association ACEA. For key biofuels, Platts assessed the spread between renewable diesel, or HVO, and ultra-low sulfur diesel in Europe at $1588.45/mt. The spread between biojet (SAF) and jet fuel was assessed at $1,776.43/mt on Dec. 6, Platts data show. Battery metals Germany aims to have at least 15 million electric vehicles by 2030, a goal the new coalition lifted from previous targets. German EV sales are expected to nearly double to 755,000 in 2021, according to Platts Analytics. This is expected to rise to 1.13 million in 2025 and 1.7 million in 2030. To meet increasing demand, seven EV battery gigafactories with a combined 246 GWh capacity are planned in Germany including Tesla's 100 GWh Gruenheide factory outside Berlin. Battery metal prices have been skyrocketing in 2021. Seaborne lithium carbonate and hydroxide prices reached almost daily record highs with Platts' assessments at $31,000/mt and $30.5000/mt CIF North Asia respectively. Similarly, European cobalt metal prices reached a three-year high of $31.25/lb IW Europe. Steel Germany's steel industry accounts for 30% of all CO2 emissions from industries and 6% of Germany's overall emissions. Steelmakers aim to cut emissions by a third by 2030 through changes in the manufacturing process estimated to cost Eur100 billion. Steel association WV Stahl welcomed plans by the coalition to support energy costs as the carbon-intensive blast furnace mills, among them Europe's biggest steelmaker Thyssenkrupp, are under pressure to stem the price of switching from coal- to hydrogen-based production while undergoing the transition from blast to electric arc furnace production. Platts daily HRC assessment has come down to Eur955/mt Dec. 6 since a record Eur1190/mt EXW Ruhr in June, but margins remain healthy at mills. Expected decarbonization costs for the European steel industry already changed pricing policies at mills and led steelmakers to introduce or plan carbon surcharges as extra costs on base prices. Petrochemicals Germany hosts some of the largest petrochemical companies in Europe. The sector will be seeking a level playing field with global counterparts on carbon emissions to prevent the risk of investment leakage. Germany is at the forefront of EU plans to reduce plastic waste pollution and increase the use of recycled plastic. Germany is well positioned with PET plastic bottle collection rates above 90%, but strong demand and exports means Germany is facing an uphill battle to ensure that 2025 mandates are met. Post-consumer PET bottle bales, the feedstock for recycled PET, have more than doubled in 2021 to Eur850/mt FD NWE Dec. 6, Platts data show. Hydrogen The new government plans to double Germany's electrolyzer capacity target to 10 GW by 2030. The outgoing government had already pledged Eur9 billion in support for electrolyzer and related projects at home and abroad. German hydrogen demand accounts for approximately 2% of current global consumption, or 1.6 million mt/year, almost all from unabated fossil fuel production, with demand concentrated in the refining and fertilizer sectors, according Platts Analytics. Demand could reach 2.2 million mt/year by 2030, Platts Analytics said in its European Hydrogen Long-Term Forecast in October. Platts Analytics Hydrogen Production Asset Database tracks a total of 640,000 mt/year of production capacity in Germany by 2030. GERMAN PRIMARY ENERGY MIX (%) Q1-Q3 2021 Q1-Q3 2020 Oil 32 35.6 Gas 26.3 25 RES 16.1 16.9 Lignite 9.1 7.5 Coal 8.4 7.2 Nuclear 6.4 6.1 Source: AGEB (Nov. 8, 2021) Editor: Andy Critchlow ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/122421-commodities-2022-ill-timed-year-of-european-plant-closures-clashes-with-gas-crisis</link><description>Explore the challenges of European plant closures in 2022 amid a gas crisis, analyzing the implications for energy supply and market dynamics.</description><title>Commodities 2022: ill-timed year of European plant closures clashes with gas crisis</title><pubDate>24 December 2021 09:00:00 GMT</pubDate><author><name>Andreas Franke</name></author><content><![CDATA[ 24 Dec 2021 | 09:00 UTC Commodities 2022: ill-timed year of European plant closures clashes with gas crisis By Andreas Franke Highlights 4 GW German nuclear to shut boosting coal despite closures Wind, solar output to rise 8 GW based on normal weather Platts Analytics sees 2022 gas-fired power hit 2014-low European power markets enter 2022 in crisis. There is no near-term path out of the current gas-driven super-inflation of prices, while another slew of coal and nuclear closures is poised to intensify Europe's reliance on price-setting gas-fired generation. The interconnected nature of European power systems makes this the case even for national markets with little gas-firing. Generation costs for a 50% efficient gas-fired power plant in Northwest Europe hit a record Eur287/MWh ($323/MWh) Dec. 17 for Q1 2022 compared to an average Eur43/MWh a year ago, S&amp;P Global Platts data show. This has lit a fire under forward contracts. German Cal-2022 baseload power, Europe's benchmark contract, had risen over 500% in 2021 to trade Dec. 21 above Eur300/MWh, exchange data showed. And this ahead of the closure of Germany's last three nuclear reactors by end-2022, taking 4-GW out of the market. France meanwhile faces another winter of record-low nuclear availability reflected in the front-month peakload contract, trading Dec.17 above Eur1,000/MWh on the EEX exchange. Demand key variable While a fall in gas prices and growth in renewables should ease the crisis next year, plant closures "will increase the power market's exposure to gas prices and we see the potential for the extreme prices seen in 2021 to be repeated in Q1 2022 overshadowed by French reactor delays," said Glenn Rickson, who heads up Platts Analytics' European power team. "Demand is a key uncertainty for 2022, with COVID risk only one factor at play," he said. Platts Analytics sees 2022 demand across the ten European markets it covers rise by around 2% or 5 GW on average in a year-on-year comparison. Nuclear is set to remain the single biggest source of electricity for the ten markets, but forecast to fall 4 GW to a record-low 65 GW hourly generation average. Wind output meanwhile is set to overtake that of gas in 2022, with hydro in fourth. Coal and lignite output is forecast to rebound only slightly to around 22 GW on average for 2022, despite record-high generation margins -- plant closures have severely diminished capacity over recent years, with only Germany and Poland maintaining significant fleets. Gas-fired generation was projected to dip to a 41 GW average, driven lower by poor spark spreads. Run times could see upside, however, reflecting variable demand and wind generation, the latter being below average in 2021. Dispatchable plant closures As noted, Europe's biggest power market Germany is set for a big shift in its supply-demand balance in the near terms with three reactor closures at the end of 2021 to be followed by a final three closures at end-2022, removing 8 GW or 12% of German supply in all. Meanwhile, barring a possible lifetime extension, Belgium's Doel 3 reactor is set to close in Oct. 2022, to be followed early 2023 by Tihange 2. In the UK, finally, there will be no reprieve for Hunterston B and Hinkley Point B reactors, both set for permanent closure during 2022. On the coal front, Germany has already shut 6 GW of hard coal in 2021 following closure compensation auctions with at least another 3 GW to follow in 2022 including the first wave of lignite closures capping combined capacity at 30 GW. Further out, the new government in Berlin plans to review the coal exit deadline of 2038, with the intention of bringing this forward to 2030 if possible. Other notable 2022 events include closure of Riverstone's 730 MW Rotterdam coal plant expected to shut in Q2 and closures of at least two more French coal units ahead of Presidential elections in April. EUROPEAN PLANT CLOSURES 2021/22 Plant MW Fuel Country Date Gundremmingen C 1300 Nuclear DE Dec. 2021 Brokdorf 1400 Nuclear DE Dec. 2021 Grohnde 1400 Nuclear DE Dec. 2021 Doel 3 1000 Nuclear BE Oct. 2022 Hunterston B 1000 Nuclear UK 2021/22 Hinkley Point B 1250 Nuclear UK July 2022 Hambach units 900 Lignite DE Dec. 2021 Neurath A 300 Lignite DE April 2022 Neurath D+E 1200 Lignite DE Dec. 2022 RDK7 500 Coal DE Summer 2022 Wilhemshaven, Mehrum 1500 Coal DE Dec. 2021 Rotterdam 730 Coal NL tba West Burton A 600 Coal UK Sept. 2022 La Spezia, Fusina 870 Coal ITA 2021 Litoral 1200 Coal ESP 2022 Emile Huchet 6, Provence 5 1200 Coal FRA 2022 Cordemais 1200 Coal FRA tba Source: S&amp;P Global Platts First new reactors Offsetting these debits, Europe's first EPR reactor in Finland is finally about to come online with first electricity to be produced in January 2022 and commercial operations to start in June. In France, fuel loading at the Flamanville 3 EPR is scheduled for end-2022, allowing for a 2023 start for the first new French reactor in a generation. On the gas front, new CCGT capacity is to start at Keadby 2 (GB), Landivisau (France), Agios Nikolaos (Greece) as well around 2 GW in Germany replacing coal at VW Wolfsburg and Herne 6. European wind power is set for a boost after sluggish growth, with UK offshore projects leading new additions while France is to bring online its first offshore wind farm at the 500 MW Saint Nazaire site. In all, Platts Analytics forecasts average wind and solar production in the ten European markets it covers to average at a record 64 GW in 2022 assuming average weather conditions, up from a 55 GW average in 2021 amid below average wind speeds across NW Europe. Finally, new interconnector commissioning between France and Italy and France and GB, will help integrate new renewables in 2022 while a booming battery storage sector in the GB should trim excessive balancing costs seen in recent months. NEW EUROPEAN POWER ASSETS 2022 NEW GAS-FIRED CCGTs MW Country Start Landiviseau 450 FRA Q1 2022 start Keadby 2 840 UK Q2 2022 start VW Wolfsburg 500 DE 2022 Herne 6 600 DE 2022 Agios Nikolaos 825 GR 2022 NEW REACTORS Olkiluoto 3 1650 FIN June 2022 COD Flamanville 3 1650 FRA Dec. 2022 fuel loading Mochove 3 471 SLO 2022 NEW INTERCONNECTORS Savoie-Piedmont 1200 FRA-ITA Q1 2022 ElecLink 1000 FRA-UK mid-2022 Source: Developers, S&amp;P Global Platts Editor: Henry Edwardes-Evans ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/podcasts/energy-evolution/032526-ontario-power-generation-leads-the-north-american-race-to-build-advanced-nuclear</link><description>When it comes to advanced nuclear generation, most North American power producers are in the study and development phases. But Ontario Power Generation is currently constructing the first of four small modular nuclear reactors at its Darlington facility, with the first 300-megawatt unit scheduled to complete construction and connect to the grid by 2030. The other three reactors are scheduled to be</description><title>Ontario Power Generation leads the North American race to build advanced nuclear</title><pubDate>25 March 2026 21:00:15 GMT</pubDate><author><name>Dan Testa</name></author><content><![CDATA[ Electric Power, Energy Transition, Nuclear, Renewables March 25, 2026 Ontario Power Generation leads the North American race to build advanced nuclear Featuring Dan Testa HIGHLIGHTS 300-MW unit connects to grid by 2030 Public utilities lead North American projects When it comes to advanced nuclear generation, most North American power producers are in the study and development phases. But Ontario Power Generation is currently constructing the first of four small modular nuclear reactors at its Darlington facility, with the first 300-megawatt unit scheduled to complete construction and connect to the grid by 2030. The other three reactors are scheduled to be completed in the mid-2030s, totaling 1,200 MW of firm capacity from advanced nuclear reactors. In this episode, Dan Testa speaks with OPG President and CEO Nicolle Butcher, from the sidelines of the CERAWeek by S&amp;P Global conference in Houston, about the state of the advanced nuclear project so far, how OPG selected this reactor design and why public power providers, like OPG in Canada and the Tennessee Valley Authority in the US, are taking the first steps to build advanced nuclear generation in North America. 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/061120-limited-support-for-blue-hydrogen-in-germany-green-potential-capped-by-res</link><description>Government backs green hydrogen, CFDs a lifeline for blue hydrogen Electrolysis to supply a sixth of 2030 demand due to power constraints Uniper CEO in national hydrogen council representing all secto</description><title>Limited support for blue hydrogen in Germany, green potential capped by RES</title><pubDate>11 June 2020 12:04:00 GMT</pubDate><author><name>Andreas Franke</name></author><content><![CDATA[ 11 Jun 2020 | 12:04 UTC â London Limited support for blue hydrogen in Germany, green potential capped by RES By Andreas Franke Highlights Government backs green hydrogen, CFDs a lifeline for blue hydrogen Electrolysis to supply a sixth of 2030 demand due to power constraints Uniper CEO in national hydrogen council representing all sectors Germany's national hydrogen strategy, presented June 10, focuses on kick-starting a green hydrogen economy based on the electrolysis of renewable energy, but there is a small opening for blue hydrogen. The strategy talks of a 'stakeholder debate' with the energy-intensive chemical and steel sectors on possible decarbonization methods other than green hydrogen using carbon capture and utilization (CCU) technology as well as carbon contracts for difference. Related interview: COVID-19 could delay Germany's subsidy-free renewables: Aurora And with Germany's ability to produce green hydrogen domestically constrained by renewable electricity volumes, there is room for blue hydrogen (steam methane reforming plus carbon capture) to grow if it can do so without the bulk of the subsidies on offer. The government plans a pilot carbon CFD program for steel and chemical sector projects, it said. That would subsidize the cost difference between a project's avoided CO2 emissions and the CO2 price in the European trading scheme (EUA), it said. Germany's 2030 climate law has set legally binding emissions targets for all sectors from power to transport and industry. The focus on green hydrogen in the strategy, however, should not be underestimated with Eur9 billion ($10 billion) in support, of which Eur2 billion would be for green hydrogen projects abroad. "The government's recognition that only green hydrogen from renewable sources is sustainable reduces the long term risk of fossil gas surviving through the backdoor," Felix Heilmann, researcher at climate think-tank E3G said. "At the same time, the long negotiations within the government regarding the potential for green hydrogen production in Germany illustrate the difficulties that countries which pin too many hopes on hydrogen will face," Heilmann said. Green hydrogen from the planned 5 GW of electrolyzer capacity by 2030 would only produce a sixth (14 TWh) of hydrogen demand by then, the strategy estimates. German hydrogen demand is set to almost double from 55 TWh to a forecast range of 90-110 TWh. The government expects CO2-free hydrogen derived from natural gas to play a role in other European hydrogen markets and, therefore, in Germany. Meanwhile German utility lobby BDEW has criticized the lack of a clear European certification process for green hydrogen, decarbonized gases and a trading system for such products. The BDEW was working on a relevant proposal, it said. National hydrogen council A new national hydrogen council (NHC) will be essential in the implementation of the strategy. The government has appointed a cross-section of 25 industry managers, scientists, unions, experts and environmental activists to the council. "Feeling the responsibility for being the only direct representative of the German large utilities in the NHC, I am delighted to make this expertise available to the Hydrogen Council," Uniper CEO Andreas Schierenbeck said. Schierenbeck has called for a technology-neutral approach to hydrogen. Uniper has a joint venture with Siemens involving its closed coal plant sites. "Hydrogen is the connecting element between the sectors and helps us as a society to avoid the billions of euros in damage caused in Germany alone by the destruction of the value of unused electricity from renewable energy sources," Schierenbeck said. Some 3%, or 6.5 TWh, of renewables were curtailed last year to keep the power grid stable, most of it wind during winter. The advisory NHC, comparable in composition to Germany's coal commission, includes company representatives from all industrial sectors such as BASF, Daimler, Linde, MAN, ThyssenKrupp/Salzgitter, Siemens and Viessmann alongside scientists, researchers, unions and environmental activists such as BUND and Klima Allianz. Germany's biggest power generator RWE, which on June 10 signed an agreement with steel maker ThyssenKrupp on a green hydrogen project, called for a quick implementation of the strategy. The GETH2 project would be based on a 100 MW electrolyzer at RWE's Lingen site with the hydrogen transported via pipeline by gas operator OGE (also represented in the NHC) to the Duisburg steel plant, supplying 70% of the plants demand to produce 50,000 tonnes of green steel annually. A June 5 study by Prognos for the energy ministry highlighted energy-intensive sectors such as steel and chemicals as essential for decarbonization, but with wholesale transformation only feasible in the 2030s due to massive energy demand. The hydrogen strategy's focus on green hydrogen would add approximately 20 TWh in additional demand for renewable power to feed the 5 GW electrolyzer capacity by 2030 with the government keen not to increase power sector emissions amid the coal-phase-out with the 2022 nuclear exit already reducing CO2-free electricity in Germany's power mix. Editor: Dan Lalor ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/essential-energy-insights-september-2021</link><description>Chile&amp;apos;s early bet on clean energy paid off. Now the government has offered up the country as a hydrogen laboratory to the world, with a goal of becoming one of the top three exporters by 2040.</description><title>Essential Energy Insights - September 2021</title><pubDate>12 September 2021 18:30:00 GMT</pubDate><content><![CDATA[ Blog â 13 Sep, 2021 Essential Energy Insights - September 2021 Chile's early bet on clean energy paid off. Now the government has offered up the country as a hydrogen laboratory to the world, with a goal of becoming one of the top three exporters by 2040. Learn more about Market Intelligence Request Demo ]]></content></item><item><link>https://www.spglobal.com/market-intelligence/en/news-insights/research/european-energy-insights-september-2021</link><description>European Energy Insights September 2021 highlights energy sector performance, commodity movements, and market developments in Europe.</description><title>European Energy Insights September 2021</title><pubDate>10 October 2021 18:30:00 GMT</pubDate><content><![CDATA[ Blog â 11 Oct, 2021 European Energy Insights September 2021 Here you will find a collection of this monthâs top European energy insights. Want to stay informed? Subscribe to receive our monthly insights directly to your inbox > Learn more about Market Intelligence Request Demo ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/123021-german-reactors-at-grohnde-brokdorf-gundremmingen-to-end-production-dec-31</link><description>German reactors at Grohnde, Brokdorf and Gundremmingen with a combined capacity of 4.2 GW are to end production on Dec. 31, with the units to be disconnected from the grid during the evening, transpar</description><title>German reactors at Grohnde, Brokdorf, Gundremmingen to end production Dec. 31</title><pubDate>30 December 2021 12:28:00 GMT</pubDate><author><name>Andreas Franke</name></author><content><![CDATA[ 30 Dec 2021 | 12:28 UTC German reactors at Grohnde, Brokdorf, Gundremmingen to end production Dec. 31 By Andreas Franke Highlights Wind surge deflates spot, Cal-22 near record-highs Final three German reactors to close by end-2022 Nuclear generated 65 TWh in 2021, 12% of demand German reactors at Grohnde, Brokdorf and Gundremmingen with a combined capacity of 4.2 GW are to end production on Dec. 31, with the units to be disconnected from the grid during the evening, transparency data shows. The 1.4 GW Grohnde and 1.5 GW Brokdorf units in northern Germany were scheduled to ramp down during the evening and to be disconnected from the grid around 22:30 local time, according to operator PreussenElektra. The 1.3-GW Gundremmingen-C in southern Germany is already ramping down, with production reaching close to zero by 16:30 CET and disconnection scheduled for 19:00 local time, according to operator RWE's transparency notes on EEX. Spot power prices for Dec. 31 plunged amid a surge in wind above 30 GW. Day-ahead baseload settled at Eur12.13/MWh, the lowest in five months and compared to a record-high Eur416.72/MWh just nine days ago, Epex Spot data shows. Five hours early Dec. 31 settled below zero. Germany's energy and environment ministers Robert Habeck and Steffi Lemke (both Greens) welcomed the closures in a joint statement Dec. 28. Plans to exit nuclear date back two decades to a first coalition of the SPD with the Greens bringing in production quota for reactors. In 2011 after the Fukushima nuclear accident, Germany decided to immediately close reactors built before 1980 and reverse a planned run-time extension for modern nuclear plants by setting mandatory closure dates. So far, only three modern reactors were shut, at end-2015, end-2017 and end-2019. The final six closures are in an unprecedented short period and coincide with coal and lignite plant closures. That, combined with record gas and CO2 prices, pushed German power prices to record highs, with Cal 2022 up fourfold this year closing Dec. 29 at Eur219.88/MWh, exchange data shows. German nuclear generated over 65 TWh of electricity in 2021, covering almost 12% of German power demand. Editor: Jonathan Fox ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/010522-dutch-2021-gas-fired-output-falls-as-coal-gains-bigger-share-in-power-mix</link><description>Gas fired power production in the Netherlands fell in 2021, as coal gained a larger share in the power mix, an analysis by S&amp;amp;P Global Platts showed Jan. 5.</description><title>Dutch 2021 gas-fired output falls, as coal gains bigger share in power mix</title><pubDate>05 January 2022 16:25:00 GMT</pubDate><author><name>Kira Savcenko</name></author><content><![CDATA[ 05 Jan 2022 | 16:25 UTC Dutch 2021 gas-fired output falls, as coal gains bigger share in power mix By Kira Savcenko Highlights Dutch gas-fired generation declines 18% on the year to 40.35 TWh Coal-fired production jumps 69% to 20.5 TWh Dutch gas-fired production to drop to 3.7 GW in 2022: Platts Analytics Gas-fired power production in the Netherlands fell in 2021, as coal gained a larger share in the power mix, an analysis by S&amp;P Global Platts showed Jan. 5. Dutch gas-fired generation declined 18% on the year to 40.35 TWh in 2021, according to data from Fraunhofer ISE, as record high prices made gas unattractive for power production. That boosted coal-fired production 69% on the year to 20.5 TWh, even as aggregate wind output increased on the year. Offshore wind generation jumped 73% to 8.25 TWh, more than offsetting a drop in onshore wind output. Biomass and waste output was down 7% and 5%, respectively, during the year. Aggregate Dutch power demand slipped to 106.5 TWh in 2021, from 108 TWh, a year earlier. January outlook Dutch gas burn in January has been sluggish, as mild weather leads to weak heating demand, with prices favoring coal over gas for electricity generation. Gas-fired generation averaged just about 2 GW Jan. 1-4, according to Fraunhofer, compared with more than 5 GW in January 2021. The Dutch TTF front-month and front-quarter gas contracts have remained firmly above corresponding Coal Switching Price indicators (CSPI) in recent weeks, data from S&amp;P Global Platts Analytics showed. That could discourage strong gas burn in the Netherlands during winter, as the new 50%-efficient gas-fired plants become unprofitable to run, compared with the 40%-efficient coal units. The older 45%-efficient gas plants fell out of favor, as they provided almost the same efficiency, particularly on the near curve, compared with the coal units. Platts Analytics expects Dutch gas-fired production to drop to 3.7 GW in 2022, from 6.4 GW in 2021, with November 2021 and December 2021 production based on scaled data, according to a most recent forecast from Dec. 16. The Netherlands has limited high-calorie gas availability to spare for power generation. Dutch aggregate gas storages were 36.1% full as of Jan. 3, firmly below 67.4%, a year ago, the most recent data from Gas Infrastructure Europe showed. This was driven by low stocks at the high-calorie Bergermeer storage site, where Russia's Gazprom holds considerable capacity, with the facility just 23.3% full Jan. 3. Stock levels of low-calorie gas -- mostly used for heating purposes -- were higher. The weather in the Netherlands is expected to stay milder-than-average until at least Jan. 11, according to CustomWeather, with temperatures in Amsterdam forecast to hold at 2 C above seasonal norms. That could keep heating demand lower, although an ongoing national lockdown in the Netherlands could force people to stay at home longer, driving up consumption. Dutch Power Generation (TWh) 2021 2020 % change Gas 40.35 49.38 -18 Hard Coal 20.5 12.1 69 Wind offshore 8.25 4.77 73 Others 15.78 23.46 -33 Nuclear 3.62 3.87 -6 Wind onshore 4.17 5.08 -18 Waste 3.05 3.22 -5 Solar 0.31 0.16 94 Biomass 0.13 0.14 -7 Source: Fraunhofer ISE Editor: Ankit Ajmera ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/093021-re-balancing-of-europes-gas-power-markets-seen-unlikely-in-q4</link><description>Gas stores at historically low levels French nuclear more robust on year CO2 auction supply to fall 30% on year A rapid re balancing of the European gas market looks an unlikely prospect in Q4 2021 as</description><title>Re-balancing of Europe&amp;apos;s gas, power markets seen unlikely in Q4</title><pubDate>30 September 2021 14:26:00 GMT</pubDate><author><name>Stuart Elliott</name><name>Andreas Franke</name><name>Frank Watson</name></author><content><![CDATA[ 30 Sep 2021 | 14:26 UTC Re-balancing of Europe's gas, power markets seen unlikely in Q4 By Stuart Elliott, Andreas Franke, and Frank Watson Highlights Gas stores at historically low levels French nuclear more robust on year CO2 auction supply to fall 30% on year A rapid re-balancing of the European gas market looks an unlikely prospect in Q4 2021 as prices continued to reach fresh record highs deep into September. With storage stocks at historically low levels for the time of year, Asia beating out Europe for LNG cargoes, and Russia continuing to keep a lid on exports, there is real concern that Europe could face gas shortages through Q4. One potential potential supply-side savior would be an early approval and startup of the Nord Stream 2 pipeline, which could bring much-needed gas into Europe before the end of 2021. But with the German regulator allowed to take up to four months -- to January -- to publish a draft decision, there is a real risk Nord Stream 2 will remain idle until well into 2022. The unprecedented market tightness has left producers other than Russia supplying as much gas as possible to the market, from the UK, to Norway, Algeria and Azerbaijan. Any unexpected disruption in the upstream in any of these countries could be disastrous for European balances in the absence of significant LNG supplies. S&amp;P Global Platts Analytics sees more LNG coming to Western Europe in Q4 than the same period of 2020, however, which could bring some relief. It forecast net imports of 224 million cu m/d in the October-December period, up from 193 million cu m/d in the fourth quarter of 2020. But with Platts JKM LNG price still at a premium to the TTF -- and the two benchmarks chasing each other ever higher to secure spare spot cargoes -- much will depend on the weather in the respective regions. A cold winter could spell "trouble" for Europe, France's Engie said late September. According to Platts Analytics, the market may need to balance on more demand destruction or substitution. "Beyond hoping for mild weather, there is no one clear solution to our balancing needs this winter, not even Nord Stream 2." It may turn out that Q4 will end up being a demand story in European gas, with gas-guzzling fertilizer plants already having been idled or production curtailed. "We forecast industrial gas demand destruction (especially fertilizers) and refineries switching from gas to liquids, as well as the final unprecedented source of flexibility which is gas-to-oil switching in the power sector," Platts Analytics said. While gas demand in the residential sector was expected to remain flat in Q4 versus the same quarter of 2020, Platts Analytics expects 14 million cu m/d of demand destruction and switching in the industrial sector, and 30 million cu m/d of gas giving market away to coal and oil generation in the power sector. Of course, not all European gas buyers are paying the current spot prices -- Russia's long-term contract holders have been in part protected from the price increases as their prices are calculated using a different formula. Some Russian long-term contracts are still partly indexed to oil, while others use a hybrid of short- and medium-term hub indexation, often with a time lag of 6-9 months. But with Russia seemingly linking approval of Nord Stream 2 with additional gas supply, it is coming under increasing pressure to act now to help supply the European market. The International Energy Agency said late September that Russia "could do more" to increase gas availability in Europe and help full storage sites, which remain low for the time of year, built to just 74% of capacity by Sept. 26. A cold winter could also tighten an already struggling supply outlook, with LNG continuing to be pulled to Asia by the sky-high JKM spot LNG price, which Platts assessed Sept. 30 at a record $34.47/MMBtu. Scope for coal switching Europe's power markets have tracked the gas rally closely, indicating any material correction would only come from a re-balancing in supply and demand. "A major factor behind the increased sensitivity of power prices to gas is coal and nuclear closures over recent years," Platts Analytics head of European power analysis Glenn Rickson said. Germany alone is set to retire 10 GW of coal and nuclear capacity in 2021. "There is some scope for coal capacity to return online as well as a limited amount of gas-to-oil switching this winter," Rickson said. Gas-fired generation's share in the power mix is set to fall below 20% in Q4 across the 10 markets modeled by Platts Analytics, with a 13 GW average year-on-year decline forecast. That would likely be offset by coal and lignite burn some 10 GW higher for the period, with Germany's remaining 15 GW of lignite plant maxed out. Marginal year-on-year gains for nuclear dispatch and wind and solar capacity would offset a lower hydro forecast, while Q4 power demand would be up 2% year on year based on average temperatures. "Germany's exposure to wind generation on the back of 4 GW nuclear closures by end-2021 will likely spur high price volatility in Q1-22," Sabrina Kernbichler at Platts Analytics said. More generally, new power cables may help subdue some of the volatility, with all eyes on operational testing of the NSL and Eleclink cables to the UK, following an enforced outage on the 2 GW IFA 1 link to France. UK nuclear output is forecast to average 5.8 GW in Q4, the lowest since 2008, while French nuclear output is forecast at 44 GW, a recovery on last year. The gas rally has lifted year-ahead power to a record Eur122/MWh in France, almost triple the regulated ARENH price at which EDF has to sell 100 TWh to domestic suppliers. While there is pressure to increase ARENH volumes for 2022, it has been resisted by the government. In summary, upside risk remains despite current high pricing, but a mild winter and strong wind generation after a disappointing first nine months could rapidly change that picture. EU carbon supported EU carbon futures contracts for December 2021 delivery are expected to trade at Eur59/mt in October and November and Eur60/mt in December, Platts Analytics forecast in its European Emissions Trading System Market Outlook Sept. 22. December 2021 EUA futures prices already rallied to a fresh intra-day high of Eur65.06/mt Sept. 27, suggesting demand remained strong from compliance entities and financials alike. "Rising gas prices continue to provide fuel switch price signals in favor of coal generation, with risk of demand destruction; non-emitting generation [was] robust in August but fell in early September to lift coal generation and support EUAs," Platts Analytics said. On the supply side, carbon auction volumes in Q4 are set to average at just under 45 million mt/month, down nearly 30% year on year, excluding UK volumes and after removals by the Market Stability Reserve. The sharp year-on-year drop in supply is partly driven by the inflated volumes over September to November 2020, which included additional volume from Poland and other sources. Upside risks for the carbon price outlook include ongoing tight natural gas markets in Europe, as described above. A possible downside risk could emerge from industrials selling free allocations of allowances who may decide to take advantage of current record-high prices. However, that factor may ultimately be mitigated by concerns over a longer-term shortage, prompting companies to hold on to any surplus volume. Editor: Daniel Lalor ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/electric-power/122120-scottishpower-sets-up-hydrogen-business-targets-industry-transport-food</link><description>ScottishPower has set up a dedicated green hydrogen business with first projects launched next year to focus on high temperature industrial processes, heavy transport and food and drink sectors, the I</description><title>ScottishPower sets up hydrogen business, targets industry, transport, food</title><pubDate>21 December 2020 11:20:00 GMT</pubDate><author><name>Henry Edwardes-Evans</name></author><content><![CDATA[ 21 Dec 2020 | 11:20 UTC â London ScottishPower sets up hydrogen business, targets industry, transport, food By Henry Edwardes-Evans Highlights Follows parent Iberdrola's 600 MW electrolysis goal 'Significant contribution' to UK's 5 GW target Dedicated UK hydrogen strategy due early 2021 ScottishPower has set up a dedicated green hydrogen business with first projects launched next year to focus on high-temperature industrial processes, heavy transport and food and drink sectors, the Iberdrola-owned utility said Dec. 21. In November, Iberdrola outlined plans to develop 600 MW of electrolysis-based green hydrogen capacity in mainland Europe by 2025. "As we move towards Net Zero, electrification will only take us about 80%-90% of the way, what's left is a number of sectors and industry that will require further support," said Barry Carruthers, ScottishPower's hydrogen director. "We can take our expertise and knowledge in the development and operation of renewables and apply it to the roll-out of green hydrogen in areas where electrification can't reach," he said. Earlier this year ScottishPower, electrolysis company ITM Power and industrial gas company BOC announced a partnership to develop green hydrogen production facilities with clusters of refueling stations across Scotland. The partnership targets local authorities and others with fleets of heavy duty vehicles. It aims to supply hydrogen to the commercial market within two years. "The new hydrogen business will continue with this work and look to replicate its success with other partnerships over the coming years," ScottishPower said. It would look to work with the steel, petrochemicals, ammonia and distillery sectors, making "a substantial contribution" to the UK government's goal of 5 GW of low-carbon hydrogen production by 2030. "As with all new, emerging technologies, we need a mechanism from government to allow the investment needed to boost competition in green hydrogen," Carruthers said, referencing the UK's support for offshore wind, and the resultant cost efficiencies. Scotland is well-placed to run electrolysers using its vast wind power resource. In November, UK balancing costs exceeded GBP200 million, largely due to constraint costs on north-south transition lines caused by surplus wind power generation in Scotland. Using this excess wind generation would provide a low-cost feedstock to electrolysis assets while reducing network system costs. On Sunday, Dec. 20, UK wind generation peaked at 17.28 GW between 1300-1330 GMT, a new record, National Grid said. Wind represented 43.2% of the generation mix at the time. Scottish wind capacity stands at 9.5 GW, with a further 14 GW consented or in planning. Presenting the government's Energy White Paper Dec. 14, Secretary of State for Business Alok Sharma said "we will switch to new, clean fuels such as hydrogen for heat, power and industrial processes." A dedicated hydrogen strategy would be published in early 2021, he said. Working with industry, the government aimed for 5 GW of low-carbon hydrogen production by 2030, producing 42 TWh of hydrogen per year by then, with an interim target of 1 GW installed by 2025. Some GBP240 million would be available through the Net Zero Hydrogen Fund up to 2024/25, it said. "A variety of production technologies will be required to satisfy the level of anticipated demand for clean hydrogen in 2050. This is likely to include methane reformation with CCUS [carbon capture, utilization and storage], biomass gasification with CCUS and electrolytic hydrogen using renewable or nuclear generated electricity," the white paper said. The UK currently produces 27 TWh/year of conventional hydrogen. Editor: James Leech ]]></content></item><item><link>https://www.spglobal.com/energy/en/news-research/latest-news/energy-transition/092721-analysis-shift-in-energy-policy-in-spotlight-for-japans-leadership-change</link><description>Japan&amp;apos;s impending leadership change, which would typically not change the course of its energy policy, is in the spotlight due to a potential major shift in focus after the ruling Liberal Democratic P</description><title>Analysis: Shift in energy policy in spotlight for Japan&amp;apos;s leadership change</title><pubDate>27 September 2021 06:30:00 GMT</pubDate><author><name>Takeo Kumagai</name></author><content><![CDATA[ 27 Sep 2021 | 06:30 UTC Analysis: Shift in energy policy in spotlight for Japan's leadership change By Takeo Kumagai Highlights Japan set to decide strategic energy plan, NDC Renewables boost to be priority under new government Contrasting views on use of nuclear power Japan's impending leadership change, which would typically not change the course of its energy policy, is in the spotlight due to a potential major shift in focus after the ruling Liberal Democratic Party votes to elect a new president on Sept. 29. Four candidates -- Taro Kono, Fumio Kishida, Sanae Takaichi and Seiko Noda -- are running in the LDP's presidential election after Prime Minister Yoshihide Suga's abrupt announcement Sept. 3 that he would not re-seek the ruling party's leadership. Suga's decision not to contest paves the way for a new premier in October when the new cabinet will approve the country's new Strategic Energy Plan, as well as submit its Nationally Determined Contribution or NDC ahead of the 26th UN Climate Change Conference of the Parties (COP26) in Glasgow over Oct. 31-Nov. 12. The draft Strategic Energy Plan, Japan's principle energy policy, calls for non-fossil fuel power supply sources to account for roughly 60% by fiscal year 2030-31 (April-March). The draft NDC aims for a 46% cut in the country's greenhouse gas emissions by the same fiscal year. Both are currently undergoing a month-long public comment process until Oct. 4. Regardless of who becomes the next LDP president and premier, there is no turnaround in Japan's push for renewables as outlined in the draft Strategic Energy Plan, with its climate policies to be among the key priorities in its 2050 carbon neutrality pathway. "Climate policy should be equally or more important for the new Japanese leadership, relative to the Suga government," said Jane Nakano, senior fellow in the energy security and climate change program at the Center for Strategic and International Studies. "The Japanese public will be better served by a national leader who has a strong grasp of the magnitude of the climate challenge and an ability to proactively seize on some potential opportunities," Nakano said. "The Biden administration would welcome a new leader who shares its sense of urgency in addressing climate crisis, and work with the United States as partners." Nuclear policy Japan's nuclear power policy and renewables are among the key areas that could be approached and emphasized differently by each candidate. So far Kono, the minister in charge of administrative reform; Kishida, former chairperson of the LDP policy research council and foreign minister; Takaichi, former minister for internal affairs and communications and Noda, the LDP executive acting secretary-general, all agree on the need to utilize operable nuclear power plants to ensure Japan's stable energy supply. However, there is a distinctive difference between Kono and Takaichi's public stances on nuclear power policy, with the former advocating letting nuclear power plants phase out without newbuilds and the latter accelerating developments of small modular reactors and nuclear fusion reactors. "Should Taro Kono become prime minister, that would likely result in a big push for renewable power in Japan," said Henning Gloystein, director of global energy and natural resources at Eurasia Group. "And although he has recently moderated his well-publicized critical views on nuclear power, the atomic energy industry would almost certainly stall under a government led by him," Gloystein added. Japan, which has maintained a target share of 20%-22% nuclear power in the electricity mix by FY 2030-31 in the draft Strategic Energy Plan, has restarted only 10 nuclear reactors under new regulatory standards introduced in 2013 -- a sign that the country has made little progress in restoring public trust after the 2011 Fukushima nuclear crisis. "Currently, the life of Japan's nuclear power plant is 40 years and 60 years even after operational extension," Kono said during a Sept. 18 public debate among the LDP leadership candidates. "Nuclear power will gradually decrease as reactors reaching the life [of service limit] get decommissioned." Japan's current "biggest issue" with nuclear power is that it has not been able to decide how to process nuclear waste, Kono said at the time, calling for discussion on realistic processing methods. Nobuo Tanaka, former executive director of the International Energy Agency, agrees on the need for initiating serious discussions under a new cabinet to consider ways of processing spent nuclear fuel and fuel debris from the Fukushima crisis. "Japan's emerging significant issue is the spent nuclear fuel and the processing of fuel debris at Fukushima," said Tanaka, who is currently chairman of the Innovation for Cool Earth Forum's steering committee. "Japan will need to reduce nuclear waste from processing the spent fuel and reduce radioactive material from processing the debris." Serious discussions will be needed over the development of small modular fast reactors, which could be used for processing nuclear waste, as well as being used for industries and producing hydrogen for decarbonization, Tanaka said. Boosting renewables Kono's public remarks on phasing out coal, oil and natural gas, while maximizing and prioritizing renewables' introduction for 2050 carbon neutrality, also suggest a possible shift in Japan's energy policy focus. "In order to achieve the 2050 carbon neutrality and curb climate change, we need to stop coal and oil first and eventually make a break away from natural gas," Kono said during a Sept. 10 press conference. The Ministry of Economy, Trade and Industry's 2050 power source idea released last December included nuclear as a carbon-free source, together with fossil fuels, with carbon capture, utilization and storage, and carbon recycling, accounting for 30-40%, renewables for 50-60% and hydrogen and ammonia about 10%. "If Japan is serious about achieving its net zero emissions target by 2050, which we assume any new government will be, then the cuts to the country's thermal coal usage will have to start soon," Gloystein said. "Some of that will be replaceable via LNG, but even natural gas usage will need to gradually be dialed back to get near net zero." Editor: Wendy Wells ]]></content></item></channel></rss>