India imported 7.08 million tonnes (MT) of LNG during the three-month period, up 15% from a year earlier, according to Equirus Securities’ latest report, Natural Gas Compass | Monthly Edition: Consumption Returns to Pre-War Normal. The report noted that India’s LNG import basket has increasingly shifted towards the US, Africa and non-Qatari Middle East suppliers, reducing its immediate dependence on Qatar.

The US supplied 2.19 MT of LNG during May-July, registering a 253% year-on-year increase to emerge as India’s largest supplier. Nigeria followed with 1.31 MT (+124%), while Oman supplied 1.22 MT, recording the sharpest growth among major suppliers at 341%. Angola contributed 0.80 MT, while UAE shipments declined 34% to 0.55 MT. Qatar’s supplies fell to just 0.23 MT, down 91% from the year-ago period.

India’s LNG Imports (May–July 2026)

India’s natural gas consumption

The report also highlighted a recovery in India’s natural gas consumption. Total gas demand rose to 197 million metric standard cubic metres per day (mmscmd) in June, up 7% month-on-month and 2% year-on-year. Ex-power demand increased to 176 mmscmd, approaching pre-disruption levels.

LNG consumption climbed to 110 mmscmd, registering growth of 13% over May and 10% from a year earlier, while domestic gas consumption remained stable at 87 mmscmd. As a result, import dependence stood at 56%, underlining the growing role of imported LNG in meeting India’s energy needs.

The recovery in gas demand was broad-based across sectors. City Gas Distribution (CGD) remained the largest consumer at 58 mmscmd, followed by the fertiliser sector at 55 mmscmd and miscellaneous industries at 41 mmscmd. Gas demand from the power sector improved to 21 mmscmd, while refineries consumed 15 mmscmd. Petrochemical demand recovered to 7 mmscmd, although it remained 48% lower than a year ago.

LNG imports

India also maintained healthy LNG imports despite elevated global prices. LNG berth arrivals stood at 2.4 MT in May and 2.3 MT in June, taking first-quarter FY27 arrivals to 6.2 MT. Provisional data showed arrivals of 2.1 MT in July.

Globally, the report noted that China’s LNG imports have moved above seasonal averages after a subdued start to the year, increasing competition for flexible cargoes. Meanwhile, European gas storage stood at 58%, below historical averages ahead of winter, while Asian spot LNG prices remained above USD 20 per mmbtu.

Equirus expects India’s gas demand to remain strong in July at levels similar to or marginally below June due to softer power demand, before moderating in August because of lower demand from Morbi and seasonal factors.

https://www.businesstoday.in/latest/economy/story/us-becomes-indias-largest-lng-supplier-as-qatars-share-slumps-91-during-may-july-report-548058-2026-08-07

show less

According to Equirus Securities’ latest report, “Natural Gas Compass | Monthly Edition: Consumption Returns to Pre-War Normal,” India imported 7.08 million tons (MT) of LNG during May-July 2026, a 15 per cent increase over the same period last year. The United States supplied 2.19 MT, registering a staggering 253 per cent year-on-year increase, making it India’s largest LNG supplier for the first time. Nigeria followed with 1.31 MT, Oman with 1.22 MT, Angola with 0.80 MT, while Qatar—traditionally India’s dominant supplier—saw shipments collapse 91 per cent to just 0.23 MT.

The figures represent a dramatic reversal in India’s LNG sourcing pattern. For more than two decades, Qatar had anchored India’s gas security through long-term contracts with relatively stable oil-linked pricing. Today, the country’s LNG import basket is increasingly dominated by American, African and non-Qatari Middle Eastern supplies, fundamentally altering both its energy security architecture and geopolitical exposure.

Energy security through diversification—or new dependence?

At first glance, the shift appears to strengthen India’s energy security. Diversification reduces concentration risk after geopolitical tensions in West Asia exposed the vulnerability of relying heavily on a single supplier. The report notes that India has successfully broadened its procurement strategy, sourcing LNG from multiple regions instead of depending overwhelmingly on Qatar.

However, the diversification also reflects a more uncomfortable reality: India’s growing dependence on imported LNG. Natural gas consumption recovered sharply to 197 million metric standard cubic meters per day (mmscmd) in June, up 7 per cent month-on-month and 2 per cent year-on-year, returning to pre-conflict levels. LNG consumption climbed to 110 mmscmd, increasing 13 per cent sequentially and 10 per cent annually, while domestic gas supply remained stagnant at 87 mmscmd. As a result, import dependence rose to 56 per cent, meaning imported LNG now accounts for more than half of India’s gas requirements.

That dependence is structural rather than temporary. The recovery has been powered almost entirely by imported LNG instead of rising domestic production, raising questions about whether India’s ambition to increase natural gas’s share in the national energy mix can be achieved without exposing itself to international market volatility.

Stronger US ties, but a more complex trade equation

The timing of America’s emergence as India’s largest LNG supplier is strategically significant.

India and the United States remain engaged in negotiations over a comprehensive bilateral trade agreement amid continuing disagreements over tariffs, agriculture, digital commerce and market access. One of Washington’s longstanding concerns has been reducing its trade deficit with India.

Although the Equirus report makes no connection between LNG imports and trade negotiations, the surge in American energy exports could strengthen the economic foundation of the bilateral relationship. Every additional LNG cargo purchased from the United States adds to American exports while helping narrow the bilateral merchandise trade imbalance, potentially providing New Delhi greater negotiating flexibility in other contentious areas.

Energy is increasingly becoming an important pillar of India-US strategic engagement, alongside defense, technology and critical minerals.

For Washington, India represents one of the fastest-growing LNG markets in the world. For New Delhi, American LNG provides diversification away from politically volatile supply regions while deepening commercial ties with a strategic partner in the Indo-Pacific.

Yet the relationship is unlikely to be one-sided.

As India’s dependence on American LNG grows, Washington’s energy policies, export approvals and domestic production decisions could acquire greater significance for India’s energy security.

A changing global LNG order

The report suggests the shift is occurring against a backdrop of profound changes in global LNG markets.

The United States has consolidated its position as the world’s leading LNG exporter following massive investments in export infrastructure. Equirus notes that US LNG exports remained robust at 10.5-10.7 MT during June and July, while seven new American LNG projects have reached final investment decision since export approvals resumed in January 2025.

This expansion is allowing the United States to replace disrupted Middle Eastern supplies across Asia and Europe, transforming energy exports into an increasingly influential instrument of American economic diplomacy.

For India, however, sourcing more LNG from North America changes the economics of imports.

Unlike Qatar’s long-term oil-indexed contracts, US LNG is more closely linked to Henry Hub gas prices, liquefaction fees and international freight costs. Cargoes also travel much longer distances, making Indian buyers more exposed to shipping disruptions, insurance costs and maritime security risks through strategic sea lanes including the Red Sea and Suez Canal.

Demand recovery masks structural vulnerabilities

Domestically, gas demand has rebounded across almost every major consuming sector.

City gas distribution (CGD) consumption reached 58 mmscmd, miscellaneous industries 41 mmscmd, fertilizer 55 mmscmd, refinery demand 15 mmscmd, and gas-fired power generation improved to 21 mmscmd. Petrochemical demand recovered to 7 mmscmd, although it remained 48 per cent below last year’s level.

Import infrastructure has also operated at elevated levels.

LNG arrivals totaled 2.4 MT in May and 2.3 MT in June, taking first-quarter FY27 imports to 6.2 MT, while preliminary July arrivals remained robust at 2.1 MT, despite rising international prices.

The willingness of Indian buyers to continue importing large volumes despite expensive spot prices illustrates both resilient demand and limited alternatives.

China’s return raises the stakes

India’s diversification strategy also faces fresh global challenges.

China has returned aggressively to LNG markets after a subdued start to the year, with imports now exceeding seasonal averages. Since global LNG trade has remained broadly unchanged at around 34.5 MT per month, stronger Chinese buying is redirecting existing cargoes rather than drawing from abundant new supply.

Europe adds another layer of uncertainty.

Gas storage across the European Union stood at just 58 per cent ahead of winter, well below historical norms. Combined with recovering Chinese demand, this has pushed Asian spot LNG prices above US$20 per million British thermal units (mmbtu), increasing procurement costs for major importers such as India.

If Europe experiences a severe winter or Chinese demand accelerates further, India could once again find itself competing aggressively for flexible LNG cargoes.

Strategic gains—but new vulnerabilities

Equirus expects Indian gas demand to remain broadly stable through July before moderating in August because of seasonal factors and lower industrial consumption from Morbi’s ceramic cluster.

But the report points to a larger structural transformation.

India has reduced its dependence on a single supplier, improving resilience against regional disruptions. At the same time, it has become more dependent on imported LNG itself, tying its energy future more closely to international prices, US export capacity, global shipping routes and geopolitical competition.

The United States replacing Qatar as India’s largest LNG supplier is therefore not merely a statistical milestone. It reflects the emergence of energy as a strategic pillar of India-US economic relations, one that could reinforce bilateral trade ties while simultaneously exposing India to new forms of geopolitical and market risk. For policymakers, the challenge will be to leverage deeper energy cooperation with Washington without exchanging one form of dependence for another.

https://southasianherald.com/lng-shift-adds-new-dimension-to-india-us-trade-talks/

show less

Pipelay vessels Solitaire and Sandpiper will execute the work in water depths ranging from the shoreline to approximately 450 meters. The scope includes multiple shore crossings, shore pull-ins, above-water tie-ins, trenching activities, route stabilization, and pre- and post-lay span rectification. Combined with the project’s remote location, the complex nearshore works make for a technically demanding installation campaign.

The award reflects Allseas’ track record in delivering complex pipeline projects in challenging marine environments. By designing, building and operating its technology in-house, the company combines technical expertise with proven offshore execution – delivering demanding projects safely and predictably.

Once operational, the PRGT system will provide a new route to market for Canadian natural gas, expanding export opportunities, strengthening long-term energy security, and supporting economic development in British Columbia.

https://pgjonline.com/news/2026/august/allseas-to-install-critical-subsea-section-of-prince-rupert-gas-transmission-pipeline

show less

Senior officials from Turkmennebit, Turkmengaz, Turkmengeology and TAPI Pipeline Company Ltd., along with executives from sectoral associations and enterprises, presented reports on production and development activities.

The government said particular attention was given to construction of the Serhetabat-Herat section of the TAPI pipeline, which links Turkmenistan with neighboring Afghanistan.

“Particular attention was paid to construction of the main Serhetabat-Herat section of the Turkmenistan-Afghanistan-Pakistan-India gas pipeline in compliance with international standards,” the statement said.

Officials also outlined priorities for the energy sector, including expanding geological exploration, increasing production drilling to identify new hydrocarbon deposits, boosting oil and natural gas output, and improving the quality of extracted resources.

The approximately 1,800-kilometer (1,120-mile) TAPI pipeline is designed to transport up to 33 billion cubic meters of natural gas annually from Turkmenistan’s Galkynysh gas field through Afghanistan to Pakistan and India. Turkmenistan has long promoted the project as a key route for diversifying its gas exports and strengthening regional economic integration.

The pipeline’s gas supplies are expected to come from the Galkynysh field, one of the world’s largest natural gas deposits, with estimated reserves exceeding 27 trillion cubic meters.

In April, Turkmengaz and China’s CNPC launched the fourth phase of Galkynysh’s development, a project that includes new production facilities and additional wells expected to increase commercial gas production by up to 10 billion cubic meters annually.

The TAPI project has gained renewed attention in recent months. In an analysis published in early June, the Belfer Center for Science and International Affairs at Harvard Kennedy School said the pipeline is re-emerging in regional energy discussions as a mechanism for connecting Turkmenistan’s gas resources with growing energy demand in South Asia.

https://thekabultribune.com/en/0010588

show less

As the largest offshore gas field in eastern China, the Bozhong 19-6 field is of great significance for optimizing regional energy structures and driving high-quality economic and social development, CNOOC stated.

According to the company, the field will play a vital role in meeting the growing energy demands of local residents and industrial production.

Located in the central waters of the Bohai Sea, the Bozhong 19-6 gas field boasts proven geological natural gas reserves of more than 200 billion cubic meters, alongside proven geological liquid petroleum reserves exceeding 200 million tons.

Tapping into the field required overcoming immense engineering and geological hurdles. The gas field is buried at a depth of over 5,000 meters, featuring complex reservoirs over vast areas, with dense fractures in buried hills.

During phase one of the project, workers drilled 10 ultra-deep wells exceeding 6,000 meters in depth, setting a new record for the number of ultra-deep wells in a single Bohai Oilfield development project. The average drilling depth for the project surpassed 5,500 meters.

To date, the Bozhong 19-6 gas field has cumulatively produced more than 2.8 billion cubic meters of natural gas.

The gas field is a critical component of the broader Bohai Oilfield, which is China’s first super-large offshore oil and gas field with an annual production capacity of 40 million tons.

Operations across the Bohai Oilfield have maintained a stable growth trajectory. According to the company, its cumulative oil and gas production has recently exceeded 21 million tons, hitting a new high and further safeguarding China’s energy security.

https://www.chinadaily.com.cn/a/202608/09/WS6a77f6b7a310986e2b469c05.html

show less

Michael Lewis, CEO of Uniper, commented: “This agreement is about far more than LNG. By signing this long-term off-take agreement, we are strengthening Uniper’s portfolio with a reliable source of LNG from Canada. As a trusted partner, Canada helps to broaden Europe’s energy supply and strengthens resilience against future disruptions.

“In an increasingly uncertain world, diversification is a strategic necessity. The project combines security of supply, low-carbon hydropower infrastructure and a strong partnership – exactly the kind of long-term energy partnership we seek to build.”

With first deliveries expected from 2032, the European company claims that this deal marks the first major long-term LNG supply arrangement between Canada and Germany and represents a significant step in strengthening the strategic energy partnership between the two countries.

Davis Thames, President, Founder and CEO of Western LNG, emphasized: “The LNG sales agreement that we have entered into today with Uniper is our first with a European utility, and the beginning of an important long-term relationship between our companies. Canada is naturally endowed with a world-class natural gas resource, which, through responsible development, is one of the lowest emissions production complexes in the world.

“Paired with an abundant hydro resource, Ksi Lisims LNG will be one of the lowest emissions sources of LNG in the world. We look forward to commercializing the rest of the project so that we can move into construction shortly.”

This SPA comes more than two months after the Ksi Lisims LNG project, which was proposed by the Nisga’a Nation, Rockies LNG, and Western LNG, obtained a heads of agreement (HOA) with Germany’s Securing Energy for Europe (SEFE) for the sale and purchase of 1 million tonnes per annum of LNG.

The agreement marks an important milestone for Uniper as the company continues to build a resilient and diversified long-term LNG portfolio. The fully destination-flexible volumes provide additional flexibility to support security of supply in Europe when needed.

Eva Clayton, President of Nisga’a Lisims Government, highlighted: “Since time immemorial, the Nisga’a people have adhered to the concept of a Common Bowl. This foundational idea teaches that we are all interdependent and directs us to share our abundance with others.

“Today, that same spirit of sharing has led us to pursue LNG exports on the global stage. We are proud that this agreement with Uniper reflects the Common Bowl philosophy, and we are grateful to see governments on both sides working together to make it possible.”

According to Uniper, a distinctive feature of the Ksi Lisims LNG project is its planned use of hydroelectricity to power the liquefaction process. By combining access to Canadian natural gas resources with renewable electricity from British Columbia’s hydroelectric system, the project is expected to produce LNG with a 90% lower carbon intensity than conventional LNG facilities.

Reiche underlined: “This agreement sends a strong signal for greater security of supply and strategic independence: Uniper is securing around two million tonnes of Canadian LNG per year over the long term, equivalent to approximately 30 terawatt-hours.

“This is how we strengthen our resilience: through new sources of supply, long-term partnerships and greater diversification. Canada is a strategic partner for us – reliable, rich in natural resources and closely connected to Germany through strong economic ties.”

Ksi Lisims LNG, which means “from the Nass River” in the Nisga’a language, is a proposed net-zero liquefied natural gas project in British Columbia, located on Nisga’a Nation-owned land on the northern tip of Pearse Island.

Powered by renewable hydroelectricity, the LNG project is designed to be one of the lowest-emission-intensity LNG facilities in the world with a pathway to net-zero. The facility will produce 12 million tonnes per annum of LNG from two floating LNG (FLNG) production and storage facilities.

The 12-mtpa natural gas liquefaction and marine terminal project is envisioned to receive 1.7–2 billion cubic feet of natural gas per day and export it overseas once commercial operations start in late 2028 or 2029. The project obtained a 40-year export license from the Canada Energy Regulator (CER) two years before the first LNG offtake agreement was inked with Shell.

Tim Hodgson, Minister of Energy and Natural Resources of Canada, noted: “This agreement between Ksi Lisims LNG and Uniper represents more than an energy partnership. It is a powerful example of how, by working with allies like Germany, Canada can strengthen its economy and sovereignty, and support global energy security.

“Amidst energy market disruptions, international demand for reliable energy only continues to grow, and projects like this – developed in partnership with Indigenous Peoples and providing best-in-class low-carbon energy – demonstrate how Canada is not only a competitive, but a leading, energy superpower.”

https://www.offshore-energy.biz/germany-augments-gas-arsenal-as-uniper-pens-20-year-lng-deal-with-canadian-project/

show less

The newly signed contract covers a five-year period and involves the supply of LNG to a South African food processing company. Under the agreement, the customer will purchase LNG at an all-inclusive plant-gate price exceeding $16 per gigajoule (GJ), based on current exchange rates. The contract represents around 10% of the Phase 1 production capacity of the Virginia Gas Project and provides a stable revenue stream through its take-or-pay structure, which obligates the buyer to pay for the contracted volume regardless of actual consumption.

Paul Mann, Executive Chairman and Chief Executive Officer of ASP Isotopes, stated that South Africa has experienced persistent electricity shortages and load-shedding over the past several years, creating strong demand for reliable alternative energy sources. He noted that LNG produced from the Virginia Gas Project will help local industrial customers improve energy security while reducing dependence on an unstable electricity supply.

Mann also highlighted that the company remains focused on completing Phase 1 of the project. Besides supplying LNG to domestic customers, the facility is expected to begin exporting liquid helium to international markets. Global helium availability has remained constrained due to geopolitical disruptions, making the project strategically important for industries that depend on a stable supply of the critical gas.

Phase 1 of the Virginia Gas Project is expected to produce approximately 2,500 GJ of LNG per day along with around 70 thousand cubic feet (Mcf) of liquid helium daily. Commercial operations are scheduled to begin during the third quarter of 2026.

According to the company’s shareholder update issued on August 4, 2026, Phase 1 could generate annual revenue exceeding $27 million, assuming LNG prices remain between $15 and $18 per GJ and liquid helium averages approximately $600 per Mcf. ASP Isotopes expects revenue recognition to begin during the second half of 2026.

The company also confirmed that discussions continue with additional prospective customers for LNG and liquid helium supply from both Phase 1 and the planned Phase 2 expansion. Management expects to finalize the remaining Phase 1 offtake agreements during the third quarter of 2026 while initiating contracting for a substantial share of Phase 2 production later in the year.

Impact on Product and Chemical Commodity Prices

The five-year LNG offtake agreement strengthens demand certainty for LNG produced at the Virginia Gas Project, supporting stable production and encouraging further customer contracts. Reliable domestic LNG availability could reduce dependence on conventional fuels for South African industries while supporting broader industrial energy security. Increased helium production may also ease supply constraints in global specialty gas markets over time. For chemical commodities tracked by ChemAnalyst, the development is expected to have a neutral-to-slightly bearish impact on regional LNG prices over the medium term as new supply enters the market. Downstream energy-intensive chemicals may also benefit from improved feedstock availability and more stable production costs.

https://www.chemanalyst.com/NewsAndDeals/NewsDetails/asp-isotopes-secures-five-year-lng-offtake-for-virginia-43824

show less

Rendering of the Argent LNG project; Source: Argent LNG

Transgaz has signed a memorandum of understanding with Argent LNG in Bucharest, establishing a framework to explore a strategic equity investment. The MOU was signed by Ion Sterian, CEO of Transgaz, and Jonathan Bass, Chairman and CEO of Argent LNG.

The two companies also inked a non-disclosure agreement in connection with the discussions. Argent LNG is developing what is expected to be one of the largest LNG export terminals located in Port Fourchon, Louisiana, with a planned capacity of 25 million metric tons per year (mtpa).

On the other hand, Transgaz is the fourth-largest natural gas transmission system operator in the European Union (EU), and the only TSO that operates national gas transmission systems in two countries, one an EU member state and the other an EU accession candidate.

The Romanian firm explained: “In recognition of that role, and of Romania’s strategic position in the region, Argent LNG has invited Transgaz to become a shareholder in Argent LNG. The primary objectives are to enable the transit of U.S. LNG through Romania to the Republic of Moldova and Ukraine, and onward to Hungary, Austria, the Czech Republic, Slovakia, and Germany, among others, while diversifying Romania’s natural gas supply sources.”

The TSO underlines that Romania’s modernized natural gas transmission infrastructure, combined with the Vertical Corridor, supports the diversification of gas supply sources and routes, reduces dependence on Russian gas, and strengthens the energy security of Romania, Moldova, Ukraine, and the broader Central, Eastern, and Southeastern European and Balkan region.

The MOU establishes a non-binding framework for the parties to explore, structure, and negotiate the terms of the equity investment, as Transgaz has expressed its intention to become a shareholder in Argent LNG, alongside other major American companies.

The TSO claims that this investment reflects a strategic interest in securing long-term access to U.S. LNG supply and holding a direct stake in the company overseeing the broader Argent LNG development platform.

Romania, through Transgaz, has led and supported the Vertical Corridor concept since 2016 as a strategic initiative to curb dependence on Russian natural gas and facilitate the supply of American LNG.

https://www.offshore-energy.biz/transgaz-argent-lng-mou-advances-us-gas-route-to-central-and-eastern-europe/

show less

The switch is expected to reduce LANXESS’s carbon emissions by approximately 6,000 metric tons per year. The initiative supports the company’s broader efforts to lower the carbon intensity of its manufacturing operations while demonstrating that hydrogen can be integrated into established industrial processes on a commercial scale.

The hydrogen used at the facility is generated through chlorine electrolysis at the neighboring Covestro plant. It is transported directly to LANXESS through a dedicated pipeline, allowing the company to access a local hydrogen supply without requiring long-distance transportation. The close integration between the two facilities is a major factor behind the project’s implementation.

LANXESS installed the hydrogen burner in late 2025 and progressively brought the system into operation. The equipment has been designed to run entirely on hydrogen and includes a dedicated hydrogen pipeline, a modified burner, upgraded measurement and control technology, and additional safety systems. The technological conversion replaces the previous natural gas-based drying process with a lower-greenhouse-gas alternative.

The project also highlights the benefits of the Verbund production model at Krefeld-Uerdingen. Shared infrastructure, short pipeline connections, established safety procedures, and close cooperation between industrial partners allow hydrogen to be supplied reliably to the pigment production facility.

LANXESS and Covestro have maintained a long-standing production partnership at the site. Covestro supplies nitrobenzene, which LANXESS uses as a raw material in iron oxide pigment manufacturing. Aniline generated as a byproduct is subsequently returned to Covestro, where it serves as an important feedstock for plastics production. The hydrogen project further strengthens this integrated production network by creating an additional pathway for resource-efficient and lower-carbon manufacturing.

LANXESS’s Inorganic Pigments business is among the world’s leading producers of iron oxide and chromium oxide pigments. Its products serve construction, paints and coatings, plastics, and specialty applications. The Krefeld-Uerdingen site is the company’s largest iron oxide pigment production facility globally and has manufactured these pigments for around 100 years.

The company also benefits from the Laux process, which provides efficient energy use and generates virtually no waste compared with alternative production methods. Combining this process with hydrogen-based drying could further improve the environmental performance of LANXESS’s iron oxide pigment portfolio.

Impact on Product & Chemical Commodity Prices

LANXESS’s hydrogen conversion should have a positive impact on the sustainability profile of iron oxide pigments, potentially strengthening demand from construction, coatings, plastics, and other customers seeking lower-carbon materials. However, the immediate effect on pigment prices is likely limited because the project affects one production facility and primarily changes its fuel source. For chemical commodities tracked by ChemAnalyst, hydrogen demand could receive a modest structural boost, particularly in industrial applications, while natural gas demand at the site should decline marginally. Lower fossil-fuel consumption could reduce exposure to gas price volatility. Overall, the move is more likely to influence long-term production economics and carbon premiums than trigger immediate commodity price changes.

https://www.chemanalyst.com/NewsAndDeals/NewsDetails/lanxess-replaces-natural-gas-with-hydrogen-at-pigment-43871

show less

The project’s first batch of green hydrogen was successfully produced in late July, at the Q13a-A platform operated by Eni Energy Netherlands, located approximately 13 kilometers off the coast of Scheveningen district in The Hague.

According to a spokesperson, it is the first “fully electrified production platform” in the Dutch sector of the North Sea. Onsite, seawater is converted into demineralized water that’s subsequently transformed into hydrogen through electrolysis.

The electricity required for this process is supplied by offshore wind energy. All the while, simultaneous production of natural gas continues. Alongside the platform’s operator Eni, other project partners include DEME Group, EBN, Eneco, Emerson, Gasunie, Hatenboerwater, Investa Expertise Centrum, Iv, Nel, Nexstep, NGT, Nogat, TAQA and TNO.

A Watershed Moment For Green Hydrogen

Lex de Groot, managing director, Eni Energy Netherlands, said: “It is remarkable to see that, together with all these public and private partners, we have been able to achieve a world first through PosHYdon.

“The reuse of existing offshore platforms for sustainable applications is now becoming a tangible reality. Together, we are taking a meaningful step towards a future offshore energy system in the North Sea.”

Forbes Daily: Join over 1 million Forbes Daily subscribers and get our best stories, exclusive reporting and essential analysis of the day’s news in your inbox every weekday.

Rene Peters, business director, energy infrastructure, TNO, called the project an important step in scaling up offshore hydrogen production based on offshore wind energy.

“We believe, the pilot offers the opportunity to gain valuable knowledge and practical experience that are essential for the further development of large-scale offshore hydrogen production. This helps to reduce risks and control costs more effectively.”

Nathan Pettus, president of process systems and solutions business, Emerson, described the recent production of green hydrogen at sea by PosHYdon as “a watershed moment” for global energy transition solutions.

“When we began this journey in 2022 with our project partners, we knew it would be quite the feat to combine offshore wind power, hydrogen production and natural gas production at sea. Today, that integrated vision has become a reality.”

Pettus also flagged Emerson’s automation and control technologies that helped make PosHYdon’s milestone possible, managing the complex integration of desalination, electrolysis and gas blending processes with precision and safety.

“This project validates what we’ve long believed: that advanced digital solutions are essential to accelerating the hydrogen economy. As we look ahead, the success of PosHYdon opens unprecedented possibilities.”

The Next Stage

The excitement of having achieved the project’s first green hydrogen production is palpable along with the recognition of its next critical stage.

While PosHYdon’s backers continue to gain practical experience with integrating multiple energy systems offshore and producing hydrogen in a marine environment, project research and modelling is also focused on costs, maintenance requirements, and operational performance of offshore hydrogen installations.

Additionally, during the latest test phase, green hydrogen will be produced initially with the objective of achieving stable system operations and the extent to which the system can respond to fluctuations in offshore wind power generation.

A spokesperson said the entire operational approach has been carefully assessed for safety and environmental impact, enabling the collection of valuable practical data.

The key findings from the pilot are expected to be analyzed and compiled in August and September. The results will be shared with the hydrogen sector and Stientje van Veldhoven-van der Meer, minister of climate and green growth, The Netherlands.

Those results will help determine the next steps toward scaling up offshore green hydrogen production in Europe, and beyond.

Bulk of hydrogen currently produced around the world is gray hydrogen made from natural gas through a process known as steam methane reforming. Next comes blue hydrogen, a lower carbon version still made using SMR but with carbon capture and storage, and finally there is green hydrogen generated through electrolysis of water using renewable power quite like the PosHYdon project.

However, despite rising green investments, blue and green hydrogen currently account for less than 1% of global production, according to the International Energy Agency. This will need to change for hydrogen to play a meaningful role in a future net zero economy.

https://www.forbes.com/sites/gauravsharma/2026/08/11/dutch-project-produces-first-green-hydrogen-on-north-sea-gas-platform/

show less