NGS’ NG/LNG SNAPSHOT November 1-15, 2025
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City Gas Distribution & Auto LPG
More than 16K households in Thiruvananthapuram provided with piped natural gas
Thiruvananthapuram: More than 16,000 households in Thiruvananthapuram were provided with piped natural gas (PNG) connections under the ongoing city gas distribution project, as per the latest govt data. The project is being implemented by AG and P City Gas Private Ltd, branded as Think Gas, which received authorisation from Petroleum and Natural Gas Regulatory Board (PNGRB) to operate in Thiruvananthapuram, Kollam and Alappuzha districts.
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According to the data submitted in the assembly, 16,659 households in Thiruvananthapuram and 23,167 in Alappuzha were connected to the city gas distribution network so far. The project also supplies gas to 33 commercial establishments and several major industrial units in the district.
In corporation limits, piped gas connections were already provided in 32 wards, while related infrastructure work is progressing in 10 more wards. Officials said the network was being expanded in a phased manner, covering both residential and commercial areas.
For vehicular fuel supply, 22 CNG stations are currently operational in Thiruvananthapuram, while Kollam and Alappuzha have nine and 15 stations respectively. In addition, three LCNG stations — which supply compressed natural gas for transport vehicles — are functioning across Thiruvananthapuram and Alappuzha.
As per the details provided in the assembly, consumers would receive an uninterrupted 24-hour supply, with billing and service support made available through mobile applications introduced by implementing company, Indian Oil-Adani Gas Private Ltd. The app allows customers to make payments and verify bills online and a 24X7 customer service helpline has been set up to handle service-related issues.
To ensure safety, the gas supplied through pipelines is odourised, producing a smell similar to LPG so that even minor leaks can be easily identified. The govt noted that since natural gas is lighter than air, it rises and disperses quickly, reducing the chances of suffocation or explosion compared with heavier fuels like LPG. The piped system has also been equipped with multiple built-in safety mechanisms, making it a safer and more environmentally friendly alternative to conventional cylinder-based fuel systems.
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Bilaspur, HP Gets CNG & PNG Network
Bilaspur (HP) Nov 3 (PTI) The district administration in Bilaspur district of Himachal Pradesh has initiated the establishment of a comprehensive Compressed Natural Gas (CNG) and Piped Natural Gas (PNG) network. This initiative is being implemented by Bharat Petroleum Corporation Ltd (BPCL) to ensure the availability of eco-friendly fuel to the public, said Deputy Commissioner Bilaspur, Rahul Kumar, on Monday.
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He said the Petroleum and Natural Gas Regulatory Board (PNGRB), Government of India, has authorised BPCL to develop city gas distribution networks in 81 districts across the country and Bilaspur has now joined this list, with CNG and PNG network development work already underway.
He said three CNG stations have already been established in the district. For PNG supply, a district compression unit (DCU) is being set up at AIIMS Bilaspur, and a Memorandum of Understanding (MoU) between AIIMS and BPCL has been finalised.
Additionally, another DCU is being planned for the Ghumarwin area to provide piped gas facilities to the residents there.
BPCL officials said the corporation plans to further expand CNG and PNG facilities across Bilaspur district in the coming years. This initiative will play a crucial role in advancing Bilaspur towards a sustainable and green energy future.
https://money.rediff.com/news/market/bilaspur-hp-gets-cng-png-network/36290220251103
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Why Kerala said no to free CNG buses? Tamil Nadu turned it into a ₹78 crore success
Thrissur: The Kerala State Road Transport Corporation (KSRTC) has declined an offer from the Indian Oil-Adani Group to convert 100 of its buses to Compressed Natural Gas (CNG) free of cost. The project, valued at around ₹7 crore, was withdrawn after the company reportedly received no response to multiple letters from the corporation.
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The proposal aimed to help Kerala meet National Green Tribunal (NGT) guidelines requiring older buses to comply with environmental standards by switching to cleaner fuels. However, Kerala’s transport officials did not move forward with the plan.
Tamil Nadu accepts CNG conversion for ₹78 crore
While Kerala backed away, Tamil Nadu has embraced the transition. The Tamil Nadu Transport Corporation has finalised a ₹78 crore contract to convert 1,000 diesel buses to CNG, at approximately 7.8 lakh per vehicle.
Mumbai-based Eco Fuel Systems has been tasked with converting 850 of these buses, while two other companies will handle the remaining 150. The entire project is expected to be completed within a year, after which the buses will be ready for operation.
Tamil Nadu is also preparing to issue a new contract to convert an additional 760 buses, expanding the scope of its clean transport initiative.
Kerala cites low profitability and technical concerns
According to KSRTC officials, the Indian Oil-Adani proposal was rejected because switching to CNG was not considered financially viable. They said the price difference between diesel and CNG is only about 4.50 per litre, which provides minimal savings in operational costs.
Officials also noted that buses fitted with CNG kits often suffer from engine breakdowns and lower efficiency, leading to higher maintenance expenses. These concerns, they said, outweighed the potential benefits of adopting CNG.
Notably, officials admitted that environmental advantages were not factored into the decision, focusing instead on short-term cost implications.
Tamil Nadu’s studies highlight savings and green gains
Tamil Nadu’s transport department found that switching to CNG could generate savings of ₹2.9 to ₹4 per kilometre, improving fuel economy while cutting emissions. Studies also estimate that converting 1,000 buses to CNG will help the state eliminate 5.7 lakh tonnes of carbon dioxide annually.
This large-scale project aligns with both the National Green Tribunal’s directives and India’s National Clean Air Programme (NCAP), which aim to promote cleaner urban mobility.
Experts say Kerala missed a green opportunity
Environmental experts have criticised Kerala’s decision, arguing that KSRTC turned down a major opportunity to modernise its ageing fleet at no cost. The move, they say, contradicts the state’s public stance on sustainability and pollution control.
The rejection has sparked debate on whether Kerala’s transport planning focuses too narrowly on immediate financial viability rather than long-term environmental and operational gains.
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Prayagraj plant begins bio-CNG supply
Prayagraj launches bio-CNG production, becoming India’s second city to do so. The plant will supply 4 tons daily, also producing organic fertilizer.
The commercial supply of bio-CNG, or Compressed Biogas, produced at the Arail plant in Naini here commenced on Monday. Mayor Umesh Chandra Ganesh Kesarwani showed the green flag to CNG vehicles at the plant around 1 pm.
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Prayagraj has become the second city in the country, after Indore, to produce bio-CNG.
In the first phase, four tons of bio-CNG per day will be supplied to Indian Oil and Adani Gas Pipeline Limited from the Ever Enviro plant, which is located on the banks of the Yamuna. To produce four tons of bio-CNG, the municipal corporation will have to supply approximately 100 tons of wet waste to the plant.
The corporation established the bio-CNG plant in association with the private sector at an approximate construction cost of ₹125 crore.
On a trial, bio-CNG was produced from garbage in the plant in mid-July this year. Ever Enviro’s project head Himanshu Srivastava said 600 vehicles will run on bio-CNG produced at the plant. According to him, the plant has the capacity to produce 20 tonnes of bio-CNG, for which 325 tonnes of wet garbage, cow dung, etc., will be required. When the plant gets operational at full capacity, cooking gas will be supplied to thousands of homes and vehicles, he added.
In addition to bio-CNG, organic fertiliser will also be produced from wet waste. Their sale is expected to begin in a month.
The waste left behind from bio-CNG production will be used to make organic fertiliser. Machines have also been installed at the plant for composting.
Srivastava added: “After producing bio-CNG from 100 tons of wet waste, approximately 25 tons of residual waste are left behind. This waste will be used to make compost. According to the project head, composting is a lengthy process. The processing of composting has begun and the compost will likely be sold in the market in a month.
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Indradhanush Gas Grid commences natural gas supply to Numaligarh Refinery
Indradhanush Gas Grid Limited (IGGL) has begun supplying natural gas to Numaligarh Refinery Limited (NRL) via the Guwahati–Numaligarh Pipeline. This marks the historic commercial operation of the Northeast Gas Grid (NEGG), a crucial step in connecting the region to the National Gas Grid and promoting cleaner energy.
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Indradhanush Gas Grid Limited (IGGL) has commenced the supply of natural gas to Numaligarh Refinery Limited (NRL) through the Guwahati–Numaligarh Pipeline (GNPL) section from Tuesday onwards.
This event marks the historic beginning of commercial operations for the Northeast Gas Grid (NEGG). The commencement of gas supply signifies the first commercial flow of natural gas through IGGL’s pipeline network, a critical step in realising the vision of “One Nation, One Gas Grid.”
IGGL stated that the NEGG, a flagship project of the Government of India, aims to connect all eight states of the Northeast to the National Gas Grid, ensuring reliable and sustainable energy access to drive industrial growth and promote the adoption of cleaner fuels in the region.
IGGL added that the Guwahati–Numaligarh pipeline, an engineering marvel traversing challenging terrain including rivers, hills, and dense forests, stands as a testament to the nation’s resolve to provide clean energy to its remotest corners. This successful commencement of natural gas supply to NRL marks a significant milestone, paving the way for the commissioning of the entire 554 km Phase I pipeline network and enabling future connections to other major industrial consumers and City Gas Distribution (CGD) networks along the route.
Indradhanush Gas Grid Limited (IGGL) is a joint venture company of five major PSUs: Indian Oil Corporation Limited (IOCL), Oil and Natural Gas Corporation Limited (ONGC), GAIL (India) Limited (GAIL), Oil India Limited (OIL), and Numaligarh Refinery Limited (NRL).
IGGL is implementing the Northeast Gas Grid project to develop and operate a natural gas pipeline grid across the eight states of the Northeast region. The project is pivotal for ensuring energy security, fostering economic development, and promoting environmental sustainability in the region.
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Natural Gas/ Pipelines/ Company News
PESB recommends Deepak Gupta as next GAIL CMD
New Delhi: The government headhunter Public Enterprises Selection Board (PESB) has recommended Deepak Gupta as the next chairman and managing director of state-owned gas utility GAIL (India) Ltd. Gupta, currently serving as Director (Projects) at GAIL, is set to succeed Sandeep Kumar Gupta, who is scheduled to retire in February 2026.
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PESB, in a notice on its website, said it interviewed a dozen applicants on November 6, following which it recommended Deepak Gupta for the top job at GAIL. Once anti-corruption bodies – CVC and CBI – clear his name, the recommendation will go to the Appointments Committee of the Cabinet, headed by the Prime Minister, for approval.
Among the 12 candidates that PESB interviewed are GAIL Director (Business Development) Rajeev Kumar Singhal, Indraprastha Gas Ltd Managing Director Kamal Kishore Chatiwal, Indian Oil Corporation (IOC) Director (Finance) Anuj Jain and Engineers India Ltd (EIL) Director (Commercial) Atul Gupta.
Gupta, a mechanical engineer from the erstwhile Delhi College of Engineering (now DTU), will have a tenure of three years till his superannuation at the end of February 2029.
Current incumbent Sandeep Kumar Gupta, who previously was Director (Finance) in IOC, retires on February 28, 2026.
https://www.millenniumpost.in/business/pesb-recommends-deepak-gupta-as-next-gail-cmd-634631
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GAIL Announces Key Developments in Pipeline Expansion
In a recent update, Shri Sandeep Kumar Gupta, the Chairman and Managing Director of GAIL, announced significant advancements in their pipeline projects. He confirmed that the esteemed Prime Minister has officially inaugurated the Srikakulum Angul Pipeline (SAPL), marking a pivotal development in India’s energy infrastructure.
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Shri Gupta also shared exciting news about the company’s future projects. GAIL has received approval from the Petroleum and Natural Gas Regulatory Board (PNGRB) to initiate the Vijaipur-Bina Pipeline project. This new venture is set to involve an investment of approximately ₹450 crore and is expected to be completed within the next three years.
Highlighting the company’s financial commitment to its growth initiatives, Shri Gupta detailed the capital expenditure for the current quarter. GAIL has invested about ₹1,662 crore, primarily focusing on the expansion of its pipeline networks and enhancements in its petrochemicals division. This investment is part of a broader strategy, with the total expenditure reaching around ₹4,838 crore by the first half of the fiscal year 2026.
Project Inauguration: Prime Minister inaugurates the Srikakulum Angul Pipeline.
New Project Authorization: GAIL to commence the Vijaipur-Bina Pipeline following PNGRB’s approval.
Capital Expenditure: Current quarter investment stands at approximately ₹1,662 crore, with a focus on pipelines and petrochemicals.
Overall Investment: The cumulative capital expenditure is projected to reach ₹4,838 crore by H1 FY26.
This series of developments underscores GAIL’s commitment to enhancing India’s energy infrastructure, supporting both economic growth and energy security.
https://www.newsip.in/gail-announces-key-developments-in-pipeline-expansion
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Installation of gas pipeline from Tripura to Mizoram in progress: Official
Installation of a gas pipeline to Mizoram from neighbouring Tripura is underway, officials said on Wednesday. The project, when completed, will facilitate gas pipeline connection to households in Mizoram, particularly in Aizawl.
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Food, Civil Supplies and Consumer Affairs Minister B Lalchhanzova chaired a meeting on Tuesday to review the progress of the ongoing project under the North East Gas Grid (NEGG).
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Pipeline planned from Visakhapatnam to fuel Bhogapuram airport
Visakhapatnam: The Petroleum and Natural Gas Regulatory Board (PNGRB) has decided to develop a 60km aviation turbine fuel (ATF) pipeline from Visakhapatnam to the upcoming international airport at Bhogapuram. According to aviation experts, the development of a common carrier pipeline is essential to ensure a reliable and competitive supply of ATF to airports. While promoting competition, efficiency, and the economic use of infrastructure being developed at Bhogapuram, the initiative will also be key to meeting the anticipated rise in ATF demand and supporting the growth of the aviation sector in the state.
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Importantly, the project will reduce dependence on road transport, thereby improving safety and fuel logistics. The pipeline will have a minimum capacity of 0.5 million tonnes per year. PNGRB initiated the suo motu proposal following a public consultation process and discussions with stakeholders during open house meetings.
According to the indicative route map, the ATF pipeline connecting Vizag to Bhogapuram airport will be strategically aligned along the coast, passing through areas such as Kapuluppada, Bheemili, and Tagarapuvalasa.
A notable feature of the project is its designation as a “common carrier” pipeline. According to industry experts, common carrier status ensures that the infrastructure is available on an open-access, non-discriminatory basis to any qualified third-party oil company. This is crucial for fostering competition among fuel suppliers, which ultimately benefits airlines and, indirectly, passengers through potentially lower fuel costs and improved supply security.
The primary function of the project is to transport ATF — considered the lifeblood of modern aviation — directly from supply sources in Visakhapatnam to the airport’s fuel storage facilities. This method, known as “pipeline refuelling”, is far superior to the traditional practice of transporting fuel by road tankers. Road-based transport is prone to traffic delays, environmental risks (such as emissions and spills), and higher operational costs. In contrast, the pipeline offers a continuous, high-volume, and significantly safer supply chain, greatly reducing the airport’s reliance on road logistics.
Meanwhile, over 85% of the airport construction work has already been completed. The terminal building is about 80% complete, and access roads are around 70% complete. The state government recently allocated 500 more acres of land to the developer of the greenfield international airport for the city-side development of the aviation hub. The project is expected to be operational by the second half of 2026.
During his recent visit to the airport site, Union civil aviation minister Ram Mohan Naidu said the construction work is expected to be completed and ready for inauguration by June 2026. “The project has been progressing very quickly over the past 14 months. I have conducted seven on-site reviews of the construction and two more through video conference from Delhi. The team is working hard to complete the project with full structural strength, possibly even ahead of schedule,” the minister said.
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Tata Motors partners with THINK Gas to advance India’s LNG Trucking Ecosystem
Tata Motors partners with THINK Gas to advance India’s LNG Trucking EcosystemKochi: Tata Motors, India’s largest commercial vehicle manufacturer, has signed a Memorandum Of Understanding (MoU) with THINK Gas, India’s leading City Gas Distribution player, to strengthen the LNG (Liquefied Natural Gas) refueling ecosystem for long-haul and heavy-duty trucking in the country. The partnership aims to enhance infrastructure readiness, build greater awareness around fuel quality, and enable wider adoption of LNG-powered commercial vehicles, accelerating the transition towards cleaner and more decarbonised freight operations.
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As part of this collaboration, Tata Motors will work closely with THINK Gas to identify potential freight corridors and logistics clusters for LNG infrastructure expansion. THINK Gas will focus on maintaining high standards of fuel quality and supply reliability, ensuring optimal vehicle performance and efficiency. Exclusive benefits, including preferential pricing, will also be extended to Tata Motors customers.
Speaking on the partnership, Mr. Rajesh Kaul, Vice President & Business Head – Trucks, Tata Motors, said, “As India advances towards sustainable and efficient freight movement, LNG presents a compelling solution for long-haul and heavy-duty trucking. Recognising its potential early on, we have developed robust solutions that deliver higher fuel efficiency, reduced emissions, and superior performance. Through this partnership with THINK Gas, our goal is to strengthen ecosystem readiness – ensuring reliable access to refuelling infrastructure and enabling fleet operators to adopt LNG with confidence. This collaboration marks another step forward in our commitment to advancing cleaner, future-ready mobility solutions for India’s commercial vehicle industry.”
Representing THINK Gas, Mr. Somil Garg, Senior Vice President and Business Head (LNG Fuel), said, “At THINK Gas, our aim is to make cleaner fuels accessible and affordable across India. Partnering with Tata Motors, a leader in advancing alternate-fuel mobility will help us strategically scale our expansion. Supported by our global investors —I-Squared Capital, Osaka Gas, Sumitomo Corporation, Konoike Transport, JOIN, we remain committed to building a robust, safe, and sustainable LNG network nationwide.”
Tata Motors is at the forefront of developing innovative mobility solutions powered by alternative fuel technologies such as battery electric, CNG, LNG, hydrogen internal combustion, and hydrogen fuel cell. The company offers a robust portfolio of alternate-fuel powered commercial vehicles across various segments, including small commercial vehicles, trucks, buses and vans.
THINK Gas currently operates 18 Liquefied and Compressed Natural Gas (LCNG) stations, with several additional stations under development. Its proposed LCNG corridor is designed to connect key industrial hubs, agricultural regions, and logistics centres across the country. The corridor will cater to critical transport routes enabling efficient and reliable LNG fuelling access for fleets operating across manufacturing, warehousing, export, and agricultural supply chains.
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Petronet LNG Hosts First Finance & IT Meet
The meet was designed to exchange ideas and identify new frontiers where all can work together to make PLL more agile, robust and future-ready. Petronet LNG (PLL) organised a two-day maiden Finance & IT Meet, with the theme ‘Finance, Technology and Beyond’ on 31st October – 1st November, 2025 at the Corporate Office, New Delhi. The meet was designed to exchange ideas and identify new frontiers where all can work together to make PLL more agile, robust and future-ready.
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“Finance and IT should converge to deliver integrated sustainable solutions to enhance transparency, mitigate risks, streamline operations and for prudent capital investment decisions. That is the essence of bringing Finance and IT together on a platform where Finance can think digitally and Technology, acting strategically.” said Saurav Mitra, Director (Finance) & CFO, Petronet LNG.
He also highlighted at the meet that delivering results is not only the ultimate motto anymore but it’s important to work towards delivering transformation.
The meet was attended by Finance & IT officials from all locations of PLL along with external domain experts indulging in brainstorming, discussion and training sessions paving way for innovative solutions.
About Petronet LNG (PLL)
Petronet LNG is one of the fastest growing world-class Public Company in the India energy sector. It has set up the country’s first LNG receiving and regasification terminal at Dahej, Gujarat with present nominal capacity of 17.5 MMTPA and another terminal at Kochi, Kerala having a nominal capacity of 5 MMTPA.
Petronet LNG (PLL) was formed on April 2, 1998 as a Joint Venture Company (JVC) having 50 per cent shareholding of leading 4 Oil & Gas PSUs. An Independent Board managed JVC created for development of facilities for the import, storage and regasification of Liquefied Natural Gas. With equity participation from four Oil & Gas Maharatnas viz. Oil & Natural Gas Corporation (ONGC), Indian Oil Corporation (IOCL), GAIL (India) (GAIL) and Bharat Petroleum Corporation (BPCL). Participation of Public Sector to the extent of 50 per cent, balance 50 per cent equity is being held by Public, FIIs, FPIs, Mutual Funds etc.
https://www.businessworld.in/article/petronet-lng-hosts-first-finance-it-meet-578339
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Board of Gujarat State Petronet approves investment in JV GSPL India Gasnet
The board of Gujarat State Petronet (GSPL) at its meeting held on 11 November 2025 has approved the following investments in its Joint Venture Company GSPL India Gasnet (GIGL). Presently, GSPL holds 52% in GIGL and would continue to hold 52% after this additional equity contribution in GIGL. Hence, there will be no change in terms of percentage of Shareholding by GSPL in GIGL.
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GIGL is a Subsidiary of GSPL with other Joint Venture Partners being Indian Oil Corporation (26% ), Bharat Petroleum Corporation Limited (11% ) & Hindustan Petroleum Corporation (11% ). GIGL is engaged in the execution / implementation of the Cross – Country Natural Gas Transmission Pipeline Projects namely: Mehsana Bhatinda Pipeline Project and Bhatinda – Gurdaspur Pipeline Project awarded by Petroleum and Natural Gas Regulatory Board.
The Board of Directors has approved the following:
- Subscription of GIGL’ s Right issue of Redeemable Cumulative Preference Share amounting to Rs. 35.77 crore.
- Additional equity contribution in GIGL amounting upto Rs. 7.80 crore and Cumulative equity contribution of Rs. 1339.84 crore.
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Policy Matters/ Gas Pricing/ Others
India, Germany reaffirm renewable energy partnership for sustainable growth
New Delhi [India], November 2 (ANI): Germany and India reaffirmed their long-standing commitment to advancing renewable energy and sustainable development as Parliamentary State Secretary Johann Saathoff concluded a four-day visit to India, the German Embassy said in an official release on Sunday.
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According to the release, the visit covered Chennai and Delhi-NCR and came as both nations marked the 25th anniversary of their strategic partnership, underscoring the strength of bilateral cooperation in technology, innovation, and climate-friendly growth.
In New Delhi, Saathoff inaugurated the German Pavilion at the Renewable Energy India (REI) Expo 2025, where German and Indian enterprises showcased technologies in solar, wind, and green hydrogen.
The release said Saathoff emphasised that the partnership reflects a unified approach by “Team Germany,” bringing together ministries, development organisations such as GIZ and KfW, and the private sector to strengthen global renewable energy value chains.
At the Indo-German CEO Roundtable on Solar Energy, organised by the Ministry of New and Renewable Energy (MNRE) and the National Solar Energy Federation of India (NSEFI), discussions centred on solar manufacturing, technology exchange, and investment collaboration.
Saathoff stressed that renewable energy is both an economic driver and a moral responsibility to safeguard the planet for future generations, the release added.
He noted that Germany and India, both major renewable energy economies, are committed to learning from each other’s experiences in integrating large-scale wind and solar power into their national grids, ensuring fair competition and sustainable industry growth.
As part of his concluding programme, Saathoff visited the Indian Agricultural Research Institute (IARI) in New Delhi, where he toured India’s Agri-Photovoltaic (Agri-PV) demonstration site developed in partnership with GIZ India.
The project illustrates how solar panels and agriculture can coexist productively, enabling farmers to generate both food and clean energy from the same land.
The release said Saathoff described Agri-PV as a “third harvest,” combining food and energy security while contributing to sustainable rural livelihoods.
The visit also included interactions with researchers and students on advancing Indo-German cooperation in agricultural technology, research, and capacity building.
Reflecting on his first official visit to India, Saathoff said, “It has been a true pleasure to be in India and to witness the tremendous energy, innovation, and optimism that define this country.”
He added, “At Windergy India 2025 in Chennai, I saw first-hand the potential and commitment of India’s wind energy sector, and here at Renewable Energy India 2025 in Delhi, I have been inspired by the progress and ambition in solar and biogas.”
“I am joined by a strong delegation from GIZ, KfW, and leading German companies, all dedicated to deepening collaboration with our Indian partners. Together, we are connecting ideas, expertise, and industries, to grow together, to learn from each other, and to build a cleaner, brighter future for our children and grandchildren,” he said.
The release stated that the visit was organised by the Federal Ministry for Economic Cooperation and Development (BMZ), together with the German Consulate General in Chennai, under the framework of the Green and Sustainable Development Partnership (GSDP) between India and Germany. (ANI)
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India to host International Conference on Green Hydrogen on November 11–12 in New Delhi
The Ministry of New and Renewable Energy (MNRE) will host the International Conference on Green Hydrogen (ICGH 2025) on November 11 and 12 at Bharat Mandapam, New Delhi. The event aims to bring together global stakeholders to discuss strategies for scaling up green hydrogen production, developing infrastructure, and building demand under India’s National Green Hydrogen Mission (NGHM).
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The two-day conference will see participation from senior Union Ministers, including Pralhad Joshi, Minister of New and Renewable Energy and Minister of Consumer Affairs, Food and Public Distribution; Hardeep Singh Puri, Minister of Petroleum and Natural Gas; and Jitendra Singh, Minister of State (Independent Charge) of Science & Technology and Earth Sciences.
According to Santosh Kumar Sarangi, Secretary, MNRE and Chairman, SECI, the conference seeks to align the priorities of government, industry and research to accelerate implementation of the Green Hydrogen Mission.
“Green hydrogen will be an important part of India’s efforts to ensure clean, affordable and domestically produced energy,” Sarangi said. “The sector is evolving, and it is essential to bring clarity on technology choices, cost trends, infrastructure requirements and demand creation. ICGH 2025 will help harmonise these efforts and support the mission’s implementation.” he added.
ICGH 2025 will host government officials, technical experts, industry representatives, researchers, students and media professionals. The agenda includes thematic sessions on financing, certification, port readiness, skill development, technology localisation and the role of green hydrogen across diverse sectors.
International organisations and delegations—including the International Renewable Energy Agency (IRENA), Hydrogen Europe, the H2 Global Foundation, the Korea Hydrogen Alliance and the Port of Rotterdam Authority—are expected to participate in the discussions.
Further details on the event schedule and registration are available on the official website of ICGH 2025.
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PNGRB urges GAIL to phase out gas turbines, adopt electric motors
The gas regulator suggests India’s top distributor switch to electric compressor motors to cut costs as GAIL seeks a tariff hike amid higher gas prices. India’s gas regulator has asked Gail — the country’s largest gas distributor — to phase out gas turbines used in pipeline compressors and switch to electric motors to bring down costs. Gas pipelines in India currently use gas-fuelled turbines in compressors.
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Chairperson of Petroleum and Natural Gas Regulatory Body (PNGRB) Anil Jain told Business Standard that the rationale for moving towards electric motors for compressors stems from Gail’s request for pipeline tariff hike due to higher natural gas prices.
The regulator is currently evaluating the cost implications of the move. Lower electricity costs as compared to gas prices would help in reducing the cost of operations for the company, said Jain.
“We have asked entities to migrate away from gas-fuelled turbines to electric motors. It is in the feasibility phase. Work is ongoing on time required (for the shift) and cost implications,” said Jain.
A compressor is a critical device used for increasing pressure of natural gas as it travels through a pipeline. It helps in maintaining the flow of gas over long distances and through various terrains.
To ensure uninterrupted operations, existing gas turbines would be on stand-by mode in case of power discontinuity, while for future pipelines electric motors might be fitted with diesel gensets, Jain said.
In August 2024, the country’s largest gas pipeline network operator had submitted a request to PNGRB for higher integrated pipeline tariff of ₹78.72 per million metric British thermal unit (mmBtu), from current ₹58.61 per mmBtu.
The request is due as of now.
Gail’s chairman and managing director Sandeep Kumar Gupta had said the ₹20/mmBtu hike would boost pre-tax earnings by ₹3,400 crore annually, according to news agency PTI.
Queries sent to Gail remained unanswered till the press time.
Experts believe that a shift towards electric motors would require stable power supply at all times as compressors are of utmost importance to a gas pipeline.
“Operating compressors on power supply is a challenge, considering the committed availability basis in India. Any disruption in supply to a compressor may result in disruption of gas supply, which can be catastrophic. Ensuring gas supply to consumers on a continuous basis is very important,” said Gajendra Singh, former marketing director at Gail and former PNGRB member.zWhy request for tariff hike?
Seeking higher pipeline tariff, Gail argued that de-allocation of cheaper Administered Price Mechanism (APM) gas over years has resulted in the company sourcing spot liquefied natural gas (LNG) and high pressure high temperature (HPHT) gas, leading to higher operational costs. Domestic APM gas costs $6.55 per mmBtu, while HPHT gas is around $9.72/ mmBtu.
PNGRB determines pipeline tariff by considering a reasonable rate of return on capital employed by the company plus operating expenses in the natural gas pipeline. The current tariff of ₹58.61 per mmBtu has been in effect since April 2023.
After approval, the revised pipeline tariff would be applicable till 2049.
As the country aims to move away from use of fossil fuels, the Indian government aims to increase the share of gas in the energy basket to 15 per cent by 2030 from the current 6 six per cent.
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PNGRB committee recommends restoring priority APM Gas allocation to CNG
The committee also proposes a significant shift in regulatory alignment by calling for Compressed Biogas (CBG) to be recognized under the Corporate Average Fuel Efficiency (CAFE) framework.
The Petroleum and Natural Gas Regulatory Board (PNGRB) has published the report of the High-Level Expert Committee chaired by former Petroleum Secretary DK Sarraf, to evaluate challenges faced by India’s City Gas Distribution (CGD) sector and recommend policy interventions. The committee was formed in 2024.
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A key recommendation is the restoration of priority APM gas allocation for the CNG (Transport) segment. The committee notes that CNG plays a critical role in affordable public mobility and urban air quality improvement. It suggests that even in the event of APM gas shortages, allocation cuts should be shared uniformly across all APM-consuming sectors, rather than disproportionately impacting the CNG segment. This would ensure price stability, equitable distribution, and support the continued expansion of CGD networks.
The committee also proposes a significant shift in regulatory alignment by calling for Compressed Biogas (CBG) to be recognized under the Corporate Average Fuel Efficiency (CAFE) framework. Since CBG is a carbon-negative fuel, recognizing it under CAFE norms would incentivize automakers to adopt and promote CNG-CBG vehicle engines. Additionally, the committee recommends setting stricter CO₂ emission targets that favor CNG vehicles, ensuring OEMs continue to prioritize natural gas mobility solutions alongside EVs and hydrogen.
Another key recommendation is to formally include CNG vehicles under India’s Vehicle Scrappage Policy, alongside EVs and hydrogen vehicles. Extending scrappage incentives to CNG vehicles would accelerate the replacement of older, polluting internal combustion engine vehicles and promote adoption of low-emission mobility at scale. The report frames CNG as a strategic transition fuel in India’s Net Zero Roadmap.
While electric and hydrogen technologies represent the long-term destination, CNG offers immediate emissions reduction benefits, cost efficiency, and compatibility with existing infrastructure. Therefore, integrating CNG into the national decarbonisation roadmap would ensure a phased and realistic transition pathway.
To drive adoption, the committee suggests nationwide mandates for use of CNG in public transport and commercial vehicles, especially in cities with high pollution levels, building on the proven success of Delhi and Mumbai.
Further, it proposes that large fleet operators (such as in mining, cement, and logistics) be required to convert at least 20% of their vehicles to CNG. Finally, to support smaller fleet operators economically, the committee recommends allowing a five-year life extension for diesel trucks retrofitted to CNG under the scrappage framework.
Collectively, the recommendations highlight a coherent policy strategy to reinforce CNG and CBG as central pillars of India’s near-term clean mobility transition, while enabling a balanced move toward long-term zero-emission solutions.
In response to the news, shares of India’s City Gas Companies, IGL, MGL and Gujarat Gas saw a brief spike. While IGL cooled off from the day’s high, MGL has gained as much as 2.5%.
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LNG Use / LNG Development and Shipping
India’s Natural Gas Output Falls as LNG Imports Rise in September 2025
According to data from the Petroleum Planning and Analysis Cell (PPAC), local output dropped to 2,860 million standard cubic metres (MMSCM) during the month, compared with the year-earlier period. India’s domestic natural gas production slipped nearly 4 per cent in September 2025, even as liquefied natural gas (LNG) imports edged higher, underscoring the country’s growing reliance on overseas supplies to meet its energy needs.
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According to data from the Petroleum Planning and Analysis Cell (PPAC), local output dropped to 2,860 million standard cubic metres (MMSCM) during the month, compared with the year-earlier period. At the same time, LNG imports rose 1.2 per cent, touching 2,819 MMSCM. Together, total gas availability for sale stood at about 5,207 MMSCM, marking a modest 1.1 per cent decline.
State-owned ONGC remained the top producer with 1,518 MMSCM, followed by Oil India at 254 MMSCM. Private and joint-venture fields contributed 1,088 MMSCM. Roughly 84 per cent of the gross output was available for commercial sale, while the rest was consumed internally or flared off.
On the demand side, the fertiliser industry continued to dominate gas consumption, accounting for 28 per cent, followed by city-gas distribution at 24 per cent, power generation at 13 per cent, refineries at 8 per cent and petrochemicals at 6 per cent. City-gas consumption rose nearly 9 per cent year-on-year, and petrochemical use jumped more than 34 per cent. However, demand from the power sector fell sharply by over 17 per cent.
For the first half of the financial year (April–September 2025), cumulative consumption reached 34,867 MMSCM, about 5 per cent lower than the same period last year. Gujarat remained the country’s biggest gas consumer with 44.2 MMSCMD, followed by Uttar Pradesh (31.1 MMSCMD) and Maharashtra (27.6 MMSCMD).
Industry analysts attribute the fall in domestic output to ageing gas fields, project delays in new offshore blocks, and technical challenges in some producing regions. Meanwhile, urban network expansion and industrial pipeline connectivity are boosting LNG demand, particularly in western India.
As domestic production struggles to recover, India’s dependence on imported LNG is expected to deepen in the coming quarters, keeping energy security and pricing flexibility high on the policy agenda.
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India’s Petronet LNG to get 500,000 T LNG from Exxon in 2026 under new deal
India’s top gas importer Petronet LNG (PLNG.NS), will receive 500,000 tons of liquefied natural gas (LNG) in 2026 in its 1.2 million ton per year supply deal with ExxonMobil (XOM.N), from Australia’s Gorgon project, its managing director said on Friday.
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Petronet already imports 1.42 million tons per year of LNG from the Gorgon project, in which ExxonMobil has a stake, under a separate long-term contract with the U.S. oil major.
The first cargo under the new 15-year deal, which was agreed in 2017, is expected to arrive between March and April next year, Managing Director A.K. Singh told a press conference.
ExxonMobil will deliver about eight cargoes to Petronet in 2026, Singh said. The volumes will gradually increase over three years to 20 cargoes annually, equivalent to 1.2 million tons per year, he said.
Singh said global LNG prices could hover around $11-$12 per million British thermal units if the winter is severe, but expects prices to soften in 2026 as more supply comes online globally.
Indian companies are investing in their gas infrastructure as the country aims to raise the share of natural gas in its energy mix to 15% by 2030 from the current 6.2%.
Petronet plans to complete the expansion of its Dahej LNG import terminal in western India to 22.5 million tons per year by March 2026, Singh said.
It also operates a 5 million-ton-per-year LNG terminal at Kochi in southern India and is building a new 4-million-ton-per-year plant at Gopalpur in easter Odisha state.
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Electric Mobility/ Hydrogen/Bio-Methane
India has potential to emerge as world’s green hydrogen hub
Green hydrogen has emerged as a key fuel to cut emissions in difficult sectors such as steel, fertilisers, shipping, aviation, and road transport as the world fights the war against climate change, according to an article by former G20 Sherpa and NITI Aayog CEO Amitabh Kant.
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While Europe, Japan, Korea, and the Middle East are investing billions into renewable hydrogen, India has the right mix of resources, policy, and demand to emerge as the world’s pre-eminent hub for this new energy vector, states the article by Amitabh Kant in India Narrative.
The article identifies five decisive strengths that are working in India’s favour.
First, India offers globally unmatched rates for round-the-clock renewable energy, with prices ranging from Rs 4.60 to Rs 5 per kWh, making green hydrogen production extremely cost-competitive. Second, government policy has been both consistent and ambitious: the National Green Hydrogen Mission sets clear targets and provides the regulatory confidence that investors and companies seek. Third, India’s industrial base is already strong, spanning engineering capabilities, pipelines, refineries, and ports, providing a ready ecosystem for scaling green hydrogen. Fourth, India’s large domestic demand for fertilisers, refining, steel, and chemicals ensures that hydrogen uptake will be driven not just by exports but also by domestic consumption. And fifth, the global export opportunity is immense. Markets like Europe and Japan are actively seeking clean hydrogen imports, and India is uniquely placed to serve them, the article states.
Highlighting the achievements of India’s green hydrogen drive, the article points out that the Solar Energy Corporation of India (SECI) has awarded contracts for 450,000 tonnes per annum of green hydrogen production with leading firms like Reliance, Greenko, ACME, and L&T in the fray. SECI has also finalised a 724,000 tonne green ammonia tender aggregating demand from 13 fertiliser plants nationwide. This tender achieved a record-low price of Rs 55.75 per kilogram, among the most competitive globally. Similarly, Indian Oil Corporation has awarded a landmark project at its Panipat refinery, and Bharat Petroleum has partnered with Singapore’s Sembcorp to develop green hydrogen and green ammonia projects in India.
The article also states that while the risks associated with expanding India’s green hydrogen industry are significant, they are not insurmountable. High capital costs can be addressed through concessional finance, sovereign green bonds, and blended finance models. Certification disputes must be preempted by adopting international standards and securing bilateral recognition agreements with major markets. Skill shortages can be mitigated through a national skilling mission tailored to hydrogen and allied industries. The challenge of tender cancellations and delays can be improved by better bid design and more realistic project timelines.
By producing the cheapest green hydrogen in the world, building value-added products like green steel, ammonia, and fertilisers, and establishing itself as the trusted supplier for the world, India can leapfrog into global leadership in the clean economy. The green hydrogen race is underway, and while many countries are running hard, India is uniquely positioned to finish in front, the article concludes.
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Dharan Infra-EPC bags ₹215-crore deal to build 75 MW solar plant in Maharashtra
The project will be developed across nine sites in the Nanded district of Maharashtra. It is expected to be completed during 2025-26 to 2026-27.
Dharan Infra-EPC Ltd on Saturday said it has signed an agreement worth *215 crore with Skymax Infrapower to set up a 75 MW solar power plant in Maharashtra.
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The agreement signed by the company’s wholly-owned subsidiary Dharan Infra Solar Pvt Ltd mainly covers the design, engineering, procurement, supply, installation, testing and commissioning of a 75 MW Alley Solar Project, Dharan Infra-EPC said in an exchange filing.
The project will be developed across nine sites in the Nanded district of Maharashtra. It is expected to be completed during 2025-26 to 2026-27.This is a non-related party transaction carried out in the ordinary course of business, as per the filing.
This is the second major contract from Skymax Infrapower Ltd, the company said. On August 31, 2025, the company had secured EPC contracts worth ₹1,171.21 crore from Skymax Infra Power Ltd, for infrastructure development and renewable-linked EPC works at Orvakal Industrial Park, Andhra Pradesh.
Dharan Infra Solar Pvt Ltd has been awarded solar EPC work contracts aggregating to ₹262.10 crore for the development of a grid-connected solar power plant for the solarisation of segregated agriculture feeders at distribution substations across multiple districts in Uttar Pradesh.
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Oswal Energies signs MoU with Deendayal Port Authority to develop Green Hydrogen, Methanol, Ammonia, and a 100 MLD Desalination Plant
Oswal Energies Ltd. has signed an MoU with Deendayal Port Authority to develop Green Hydrogen, Green Methanol, Green Ammonia, and a 100 MLD Desalination Plant. This collaboration supports India’s clean energy goals and net-zero vision, with Oswal Energies leading the development of these crucial green energy facilities.
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Oswal Energies Ltd has signed a MoU with the Deendayal Port Authority (Kandla-Gandhidham) for the development of Green Hydrogen, Green Methanol, Green Ammonia, and a 100 MLD Desalination Plant under the National Green Energy Initiative.
Highlighting the significance of the agreement, Ratan Bokadia Managing Director, Oswal Energies Ltd., said, “This MoU marks a transformative milestone in Oswal Energies’ journey toward sustainable innovation. Our collaboration with the Deendayal Port Authority reinforces our commitment to driving India’s clean energy transition through advanced technologies and strategic partnerships. We are proud to contribute to the nation’s mission of achieving energy self-reliance and a greener future.”
The MoU was signed and officially exchanged during the India Maritime Week 2025, a flagship event organized by the Ministry of Ports, Shipping and Waterways, Government of India Goregaon, Mumbai.
The MoU was exchanged in the presence of senior representatives from both organizations. From Oswal Energies Ltd., Mr. Dixit Bokadia – Director and Mr. M Suresh –Chief Strategic Officer, were present during the ceremony.
Over the years, Oswal Energies has evolved from a traditional oil and gas company into a next-generation green energy enterprise.
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India may shift from natural gas to hydrogen in 5–10 years, says official
With hydrogen prices declining faster than anticipated, India could see hydrogen become a viable alternative to natural gas within the next five to ten years, making this route central to our decarbonisation and global competitiveness goals, a top Government official said on Tuesday.
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Addressing the CII Steel Summit 2025 here, Union Steel Secretary Sandeep Poundrik said: “The DRI (Direct Reduced Iron) plus Hydrogen route offers a promising pathway for green steel production.”
He highlighted that there are significant opportunities for investments in the steel industry, driven by growing needs from sectors such as defence, space, automotive and power – all of which are expanding rapidly and increasing demand for high-grade steel products.
Poundrik said that with consistent growth in consumption and capacity, along with rising opportunities from specialty steel and green steel, India is on its way to achieving the target of 500 million tonnes by 2047.
“Aligned with the vision of Viksit Bharat, our target is to reach 500 million tonnes steel-making capacity by 2047. At the current pace, we would be adding around 100 million tonnes every five to seven years, positioning India to not only meet domestic demand but also emerge as a global leader in sustainable steel production,” he said.
The Steel Secretary pointed out that there is a misconception that India’s steel industry is driven only by a few large producers. In fact, nearly 47 per cent of the steel in the country is produced by around 2,200 medium and small enterprises. These players form the backbone of India’s distributed and resilient steel ecosystem, he noted.
“There is a strong need for India to achieve self-reliance in the steel sector, given its strategic significance. The Ministry of Steel is working closely with the Ministry of Coal to increase the share of domestic coking coal in steelmaking, ensuring greater self-reliance and security in raw material supply. The government is also taking proactive measures to ensure that cheap and substandard steel does not flood the Indian market,” he added.
He underlined that the government was creating a level playing field through Quality Control Orders (QCOs) to ensure that both domestic and foreign producers meet the same quality benchmarks.
Tata Steel Ltd Executive Director and CII National Committee on Steel Co-Chairman Koushik Chatterjee highlighted that steel forms the backbone of India’s industrial transformation and national resilience. As the foundation for construction, transport, energy, and manufacturing, the sector will be pivotal in shaping world-class infrastructure, modern cities, and sustainable growth.
Emphasising India’s demographic advantage and the structural reforms like GST 2.0 fueling new consumption opportunities, JSW Steel Ltd Joint Managing Director & CEO and CII National Committee on Steel Co-Chairman Jayant Acharya noted that rapid urbanisation, a growing middle class, and rising discretionary spending are creating strong demand prospects for the steel industry.
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Paradip to get airport, cruise terminal and green hydrogen hub: CM Majhi
Majhi said this while inaugurating the Kalinga Bali Jatra at Paradip, marking ancient Odisha’s maritime tradition which is a symbol of courage of Odia sailors and traders. Asserting that Paradip in Odisha’s Jagatsinghpur district would soon emerge as the gate way to eastern India, Chief Minister Mohan Charan Majhi Tuesday said the port town will have a greenfield airport, a cruise terminal and also become a hub of green hydrogen.
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Majhi said this while inaugurating the Kalinga Bali Jatra at Paradip, marking ancient Odisha’s maritime tradition which is a symbol of courage of Odia sailors and traders.
“This festival reminds us about our ancestors who conquered the high waves of the sea and established trade and cultural relations with various countries by taking ships to different places,” he said.
Paradip will become a green hydrogen hub and house a cruise terminal. The terminal will be built on the Mangala River to make Paradip a tourism hub and the state government has allocated Rs 500 crore for this, Majhi announced adding that the port town will soon have an airport.
The CM said that Paradip Port is a key facility of India now, which has become a hub of industry, trade and employment.
Our government will do everything for the overall development of Paradip along with the port. We have plans such as establishing a green field airport, developing a megacity comprising Bhubaneswar-Khurda-Jatni-Cuttack-Paradip and Puri, preparing industrial corridors, and making Paradip beach suitable for tourism development, he said.
Odisha’s Industries and Skill Development Minister Sampada Chandra, Jagatsinghpur MP Bibhu Prasad Tarai, Chairman Paradip Port Authority P L Harnadha attended the function.
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Adani Energy Solutions to supply 60 MW green energy to textile firm RSWM
RSWM has invested ₹60 crore under the group captive scheme with a renewable energy generator to secure 31.53 crore units of green power annually, AESL said in a release. Textile manufacturer RSWM Ltd, a flagship company of the LNJ Bhilwara Group, has entered into an agreement with Adani Energy Solutions Ltd (AESL) to source 60 MW of renewable energy for its manufacturing operations across Rajasthan.
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Under the arrangement, AESL will manage the entire green power value chain for RSWM’s additional power requirements. RSWM has invested ₹60 crore under the group captive scheme with a renewable energy generator to secure 31.53 crore units of green power annually, AESL said in a release.
With this addition, the contribution of renewable energy in RSWM’s total energy requirement will rise from the current 33% to 70%, two-thirds of its total energy mix.“This achievement underscores our long-term vision to align growth with sustainability and reinforce our position as a forward-looking industrial leader,” said Riju Jhunjhunwala, Chairman, Managing Director and CEO, RSWM Ltd. “By sourcing 70% of our total energy requirement from renewable sources, RSWM continues to set industry benchmarks in responsible energy transition.”
Kandarp Patel, CEO of Adani Energy Solutions Ltd, said, “We are delighted to partner with RSWM on this landmark initiative that demonstrates how sustainability is becoming integral to businesses. This collaboration reflects the scalability and impact of renewable power in driving industrial growth while ensuring environmental responsibility.”
Rajeev Gupta, Joint Managing Director of RSWM Ltd, called the project “a milestone in our sustainability journey,” highlighting that the ₹60-crore equity investment aligns with global clean energy standards. “By integrating hybrid power, RSWM is not only reducing its carbon footprint but also enhancing long-term energy security and operational efficiency,” he added.
RSWM has been embedding sustainability into every facet of its operations—from renewable energy adoption to circular material use and responsible water management—strengthening its position as a future-ready textile leader contributing to a regenerative and resilient economy.
AESL, through its Commercial & Industrial (C&I) vertical, provides bulk electricity users with tailored, cost-competitive, and increasingly green energy solutions. The company aims to expand its C&I portfolio to 7,000 MW over the next five years, underscoring its commitment to enabling industrial decarbonization at scale.
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KPI Green Energy Inks Agreement With Gujarat Urja Vikas Nigam For Electricity Supply From 150 MW Wind Energy Project
This follows the Letter of Intent issued on July 14, 2025, under GUVNL’s competitive bidding process and subsequent approval from the Gujarat Electricity Regulatory Commission (GERC) for the tariff and PPA, a company statement said.
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New Delhi: KPI Green Energy on Thursday said it has inked an agreement with Gujarat Urja Vikas Nigam Ltd (GUVNL) for supply of electricity from a 150 MW wind energy project.This follows the Letter of Intent issued on July 14, 2025, under GUVNL’s competitive bidding process and subsequent approval from the Gujarat Electricity Regulatory Commission (GERC) for the tariff and PPA, a company statement said.
The project, scheduled to commence power supply on November 3, 2027, will operate under a power purchase agreement (PPA) with a fixed tariff of Rs 3.64 per unit for 25 years.The PPA enhances KPI Green’s utility-scale wind portfolio and aligns with the company’s growth trajectory toward achieving 10 GW of installed renewable capacity by 2030.”The project underscores our consistent performance in competitive bidding and reinforces our commitment to accelerating India’s clean energy transition. This milestone also brings us closer to our strategic objective of achieving 10 GW of installed renewable capacity by 2030,” Faruk G. Patel, Chairman and Managing Director, said.
Established in 1994, KP Group has grown into a multi-faceted conglomerate with core expertise in renewable energy, infrastructure, and innovation.Over the past three decades, the group has championed sustainability by spearheading transformative projects in wind, solar, hybrid energy, Battery Energy Storage System (BESS) and green hydrogen, thereby contributing to India’s green energy mission.
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MP News: 8 Cities To Get 1,100-Tonne Biogas Plants Under Swachh Bharat Mission
Around 15 smaller cities have been linked with these eight cluster cities to channel daily organic waste. Bhopal (Madhya Pradesh): Eight cities of Madhya Pradesh are set to get their first-ever Compressed Bio Gas (CBG) plants under Swachh Bharat Mission. The total processing capacity will be 1,100 tonnes per day, aimed at turning organic waste into Bio-CNG and other useful by-products.
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According to Urban Administration Department (UAD), the project seeks to tackle improper disposal of organic waste, which leads to pollution, foul odour and groundwater contamination.
Around 15 smaller cities have been linked with these eight cluster cities to channel daily organic waste from households, restaurants and markets for processing. For instance, Harsud and Mundi are grouped under Khandwa district cluster.
The decentralised waste management model converts organic waste into biogas, which is purified and compressed into CBG, a clean, sustainable fuel alternative to diesel and petrol. The process also generates organic manure, promoting eco-friendly agricultural practices.
What is CBG?
CBG is derived from organic waste and emits far fewer pollutants than fossil-based CNG. It also produces digestate that can be used as fertiliser. Officials said that the project will help manage agricultural residues such as stubble, further reducing environmental hazards.
Cost & funding
The project is estimated to cost Rs 236 crore and will be jointly funded by Centre, State and participating cities. The Central Government will bear 50% of the cost under the Gobardhan Bio-CNG initiative, while the remaining amount will be shared between the State Government and respective Urban Local Bodies based on financial capability.
City selection & project progress
Cities were chosen based on waste segregation, plant viability and minimal transportation distance for waste delivery. Four of the eight plants will have a capacity of over 100 tonnes per day, with Gwalior hosting the largest facility, capable of processing 350 tonnes of garbage daily. The Detailed Project Report for the Sagar plant, which will process 115 tonnes, has already been finalised, while the other seven plants are currently in tender and land allocation stages.
Revenue & buy-back model
The Central Government has proposed a Public-Private Partnership model for buy-back of biogas and manure. Urban Local Bodies will receive annual royalties from operators, with the highest royalty of Rs 40 lakh per year nearly finalised for the Khandwa plant. Rates for other plants are still under negotiation.
Timeline
An official from UAD told Free Press that the entire project is expected to take about a year to complete. Once tendering and land processes are finalised, installation will begin, with operations likely to start by late 2026 or early 2027.
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Saatvik Green Energy arm bags ₹299 crore solar module orders
New Delhi: Saatvik Green Energy on Friday said its material subsidiary, Saatvik Solar Industries, has received and accepted new orders worth ₹299.40 crore for the supply of solar photovoltaic modules. The orders have been placed by three independent power producers and engineering, procurement, and construction players in India, the company said in a statement. It added that these were repeat orders and will be executed between December 2025 and March 2026 in line with the project timelines of the respective developers.
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“These fresh repeat orders come on the back of a robust first half of FY26, where we have strengthened our manufacturing base and broadened our product portfolio. As India accelerates its renewable energy deployment, bankable partners with dependable supply chains become critical,” said Prashant Mathur, Chief Executive Officer, Saatvik Green Energy.
The company said that the new orders will further augment its order book and align with its ongoing manufacturing expansion. Saatvik is setting up a 4.8 GW solar module facility at Ambala, Haryana, and an integrated 4 GW module and 4.8 GW solar cell greenfield facility in Odisha to support India’s solar manufacturing capacity.
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BASF India partners with CleanMax for hybrid solar–wind captive power project in Gujarat
The 12.21 MW Jamnagar-based plant will supply renewable energy to BASF’s Dahej and Panoli sites from 2026, supporting its global net-zero target by 2050. the Indian subsidiary of the German multinational chemical company, on Tuesday said it has entered into an agreement with Clean Max Enviro Energy Solutions to procure renewable power from a hybrid solar and wind project in Gujarat for captive use at its Dahej and Panoli manufacturing sites. Under the agreement, BASF will invest in a 12.21 MWwind–solar hybrid captive power plant located in Jamnagar district. The facility, developed under the group captive mechanism, will supply 28,860 MWh of renewable energy annually to BASF’s production sites
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According to the official press release, the project, operated under Clean Max Amalfi, will combine 6.6 MVA of wind capacity and 5.61 MWp of solar capacity, and is expected to become operational in 2026. “By combining wind and solar generation under a captive model, we aim to ensure reliable, cost-effective, and green power for BASF’s operations in Gujarat. The collaboration highlights how industrial players can work together to decarbonize manufacturing and accelerate the adoption of clean energy,” said Kuldeep Jain, Managing Director, Clean Max Enviro Energy Solutions. The collaboration supports BASF’s strategy to expand renewable energy use across its operations in India and aligns with its global net-zero target by 2050, covering emissions from production, energy purchases, and raw material procurement.
“India is emerging as a key market for renewable energy, and BASF is proud to contribute to this transformation. This project is an important step toward BASF’s global net-zero journey and demonstrates our longterm dedication to integrating renewable energy into our value chains,” said Alexander Gerding, Managing Director of BASF India. BASF said that the investment reflects its make-and-buy approach to renewable energy, combining internal capacity building with strategic partnerships. The initiative forms part of its phased green transformation strategy, which involves increasing renewable electricity access, adopting new technologies, and scaling up sustainable products
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INTERNATIONAL NEWS
Natural Gas / Transnational Pipelines/ Others
US: BP to sell stakes in US onshore pipeline assets for $1.5 billion
Nov 3 (Reuters) – BP (BP.L), has agreed to sell minority stakes in some of its U.S. onshore pipeline assets in the Permian and Eagle Ford basins to investment firm Sixth Street for $1.5 billion, it said on Monday. The sale is part of a $20 billion divestment programme aimed at bringing debt levels down that the group is running to end-2027, and comes as BP reviews its oil and gas portfolio and cuts costs.
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UBS analyst Josh Stone called the announcement a “small positive” which is expected to bring BP’s leverage ratio down about 1%, with a net income impact of around $100 million to $200 million.
BP has been under pressure from investors and became the target of activist investor Elliott after an ill-fated foray into renewables hit profitability.
Once the sale is completed, BP’s U.S. onshore oil and gas business, bpx energy, will hold a 51% stake in the Permian assets and 25% in the Eagle Ford assets.
BP is scheduled to report third-quarter results on November 4.
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Peru: Cost of proposed Peru coastal gas pipeline reaches US$1.8bn
The reference price to build a natural gas pipeline along Peru’s coast is US$1.81bn, according to Transportadora de Gas del Perú (TGP), which transports Camisea natural gas and natural gas liquids to the coast from the Amazon. TGP provided the figure to the energy and mines ministry as part of its request submitted last year to extend its 33-year concession by 10 years, starting January 8, 2034.
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The company’s update highlights that the duct would stretch 817km from Humay to Ilo.
The system would include two branches, one to Arequipa (90km) and another to Mollendo (16km), and the installation of a compression plant in Atico.
Minimum transport capacity is pegged at 300Mf³/d with a 24-inch diameter for the main line and 14 inc
TGP has also proposed expanding infrastructure along its 1,000Mf³/d existing system for an estimated US$179mn.
These works include the installation of a fifth turbo compressor at the Chirquintirca compression plant and a new compression plant at Cañete.
The projects’ details and latest addendums are in the Documents box in the right corner of the screen.
https://www.bnamericas.com/en/news/cost-of-proposed-peru-coastal-gas-pipeline-reaches-us18bn
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Energean and Cyfield Sign Intent Letter to Advance Israel-Cyprus Gas Pipeline
Energean plc has signed a Letter of Intent with the Cyfield Group to potentially supply natural gas to Cyfield’s planned power plant in Mari, Larnaca, Cyprus. Reported on Monday, the agreement hinges on the development of a proposed undersea pipeline from Israel.
Energean has already submitted a proposal for the pipeline to both the Israeli and Cypriot governments. The pipeline would connect the Energean Power floating production and storage vessel, operating in Israeli waters, directly to Cyprus’s energy infrastructure.
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The project, which requires governmental approval from both nations, is being framed as a pivotal step for regional energy integration. If approved, the pipeline would provide Cyprus with a new source of natural gas, enhancing its energy security and reducing its dependence on petroleum fuels.
Officials said the project would also promote cleaner electricity generation, supporting Cyprus’s decarbonization efforts and European Union climate goals, while potentially stabilizing energy costs.
Israeli Energy and Infrastructure Minister Eli Cohen called his country’s natural gas a “strategic advantage.” He said selling gas to Cyprus would strengthen Israel’s international position and deliver “stability, prosperity and significant state revenues.”
Mathios Rigas, Energean’s chief executive, also supported the proposal, saying that it “offers a practical and economically viable solution to Cyprus’s energy isolation, ” with Giorgos Chrysochos, Cyfield Group’s chief executive, adding that the partnership “can transform Cyprus’s energy future.”
According to Chrysochos, gas import from Israel would enable “cleaner and more efficient electricity generation,” leading to “reduced costs for consumers.”
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Israel: Israeli energy minister halts $35bn natural gas deal with Egypt
Israel’s energy minister Eli Cohen has stalled approval of a $35 billion natural gas deal with Egypt, saying Israel must first secure better commercial terms for its domestic market. The move angered U.S. officials, who view the agreement as key to regional energy cooperation.
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Cohen insisted he would not approve the deal until Israeli interests are safeguarded and a fair domestic price is established. Industry sources say the dispute centers on gas pricing in NewMed Energy’s ongoing negotiations with Israeli buyers.
The proposed agreement would nearly triple gas exports from the Leviathan field to Egypt by 2029. But amid the Gaza conflict and rising diplomatic tension between Israel and Cairo, the energy standoff has become another flashpoint in Middle Eastern geopolitics.
https://ua.news/en/world/ministr-energetiki-izrayiliu-zupiniv-gazovu-ugodu-z-egiptom-na-35-mlrd
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China: Gazprom updated the record of daily gas supplies to China on October 30
Gazprom updated the historical record of daily gas supplies to China via the Power of Siberia for the fifth time in a month. This is stated in the company’s message. The volume delivered exceeded Gazprom’s contractual obligations.
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This is the eighth record since the release of supplies via the Power of Siberia gas pipeline to the maximum contractual level on December 1, 2024.
Russian gas supplies are carried out under a long-term gas purchase and sale agreement between Gazprom and CNPC.
Gazprom (TIN 7736050003) is the world’s largest natural gas company.
As of December 31, 2024, the Russian Federation, represented by the Federal Agency for State Property Management, owns 38.37%, JSC Rosneftegaz — 10.97%, JSC Rosgazification – 0.89%.
Net profit attributable to Gazprom shareholders in January-June 2025, according to IFRS, amounted to 983 billion rubles against 1.04 trillion rubles a year earlier. Revenue decreased by 2% to 4.99 trillion rubles from 5.088 trillion rubles. EBITDA increased by 6% to 1.547 trillion rubles.
AK&M Rating Agency: Gazprom is among the leaders of the fifth rating of responsibility to society and the eighth rating of social efficiency of the largest Russian companies.
https://www.akm.ru/eng/news/gazprom-updated-the-record-of-daily-gas-supplies-to-china-on-october-30/
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Uzbekistan, CNPC expand collaboration on major gas projects
TASHKENT, Uzbekistan, November 1. Minister of Energy of Uzbekistan Jurabek Mirzamakhmudov held a meeting with a delegation of the China National Petroleum Corporation (CNPC), led by Chairman Dai Houliang, to discuss deeper cooperation on major natural gas projects, Trend reports.
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The parties emphasized that relations between Uzbekistan and China are consistently expanding across all areas, including the fuel and energy sector, and have reached the level of strategic partnership.
During the discussions, both sides explored promising areas of joint work, including the development of the Central Asia–China gas pipeline, gas condensate field projects in the Bukhara region, construction of an underground gas storage facility, further exploration of new deposits, and training of qualified specialists for the oil and gas sector.
In September of this year, President of Uzbekistan Shavkat Mirziyoyev received CNPC Chairman Dai Houliang, where plans to expand investment participation of the Chinese side in strategic gas industry projects were also discussed. Today, CNPC’s total direct investments in Uzbekistan have exceeded $5 billion.
To note, major natural gas projects in Uzbekistan include Uzbekneftegaz exploration, massive combined-cycle power plants in Sirdarya and Jizzakh, and infrastructure modernization to meet rising imports and local demands.
CNPC stands as a preeminent entity within the global energy sector, executing cutting-edge hydrocarbon extraction and processing initiatives across both domestic and international landscapes.
https://www.trend.az/business/4111775.html
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US: A Company Eyes What Would Be North Carolina’s First Commercial Natural Gas Well
Deep River Data, with ties to cryptocurrency, says it would use the extracted gas to power a data center for “AI workloads,” not crypto mines. A company with connections to the cryptocurrency industry is considering drilling for natural gas near the Deep River north of Sanford in Lee County, North Carolina. If approved, the project would be the first commercial well drilled into the Triassic Basin, a natural gas repository underlying North Carolina and other Eastern Seaboard states.
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Deep River Data, based in Alamance County, is interested in accessing gas from Butler Well No. 3, just south of U.S. Highway 421 near the Lee-Chatham county line, according to emails obtained under public records law.
Company adviser Dan Spuller, who is both a crypto entrepreneur and a natural gas landman, contacted the state Oil & Gas Commission in September about applying for a drilling unit, a parcel of land where drilling would occur. He said the natural gas would be for a data center to power “AI workloads,” not crypto mining. Both applications are energy-intensive, running server farms around the clock to power streams of computer computations.
“We want to submit a packet that is complete on first impression—avoiding delays and making the Commission’s review as straightforward as possible,” Spuller wrote.
Duke Energy recently projected data centers could add nearly 6 gigawatts to demand in North Carolina, which has prompted the construction of new natural gas plants and pipelines, major sources of planet-warming methane and carbon dioxide.
Methane, which leaks upstream from well heads, pipelines and compressor stations, traps 86 times more heat over 20 years than carbon dioxide, the primary greenhouse gas, which power plants emit when burning fossil fuels.
Nationwide, some data centers have not only tapped into the grid but revived shuttered coal and nuclear plants for their power. The Lee County project would tap into the natural gas reserves in the Deep River Basin, which spans 150 miles over 11 counties in central and southern North Carolina.
Spuller told Inside Climate News the company will use conventional drilling, rather than fracking, to produce the gas. Fracking is a particularly destructive type of extraction. It requires horizontal drilling beneath the ground and often uses toxic chemicals mixed with large volumes of water injected at high pressures to crack the shale formations and free the gas trapped within small fissures.
Fracking is legal in North Carolina, but has never been deployed. Lee County enacted two-year fracking moratoria in 2017 and in 2019; both have expired.
“We are evaluating whether the well can safely and efficiently produce gas using conventional methods,” Spuller said. “It remains in a pre-feasibility phase—we are still evaluating whether development is even viable. Nothing has been approved, permitted or built.”
Butler Well No. 3 was drilled vertically in 1998 to a depth of 2,655 feet, according to a 2011 report by the North Carolina Geological Survey. The well lies within a geological region of black shale and old coal deposits, a legacy of the area’s mining history.
“The Oil and Gas Commission must look carefully at this proposal to exploit the gas well near the Deep River, as well as those who want to develop it,” said Therese Vick of the Blue Ridge Environmental Defense League. “It is incumbent on the commission to do its due diligence. Having worked with communities in Lee and Chatham Counties for over a decade, my concerns are many.”
Depending on their size, data centers can also consume enormous amounts of water to cool their computer servers. The project would be less than a tenth of a mile from the Deep River and Patterson Creek.
Spuller said water use “would be minimal” and that “there are no plans to withdraw water from the Deep River.”
The project could tap into groundwater or a public water main that runs along the north side of U.S. Highway 421.
The company is considering closed-loop systems and other sustainable options, he said. Some closed-loop systems, however, use more energy to run the coolers.
The project will likely need standard utility interconnections, Spuller said, such as electricity, fiber and “basic access roads typical of small-scale data facilities. There are no heavy-industrial or extraction components proposed.”
The state Geological Survey noted that Butler Well No. 3 is located within three and a half miles of a 6-inch distribution line to the Sanford Industrial Park, “which has large volume gas users.”
Stephanie Stephens, the Deep River Riverkeeper, said she’s concerned the project could be a harbinger of more data centers along the Carolina Core, an area that includes Sanford and is targeted for economic development.
“We would like to be choosy about the types of industry that come in,” she said.
The proposed data center would also be near the new Boone Trail kayak and canoe access site.
The Deep River is a troubled waterway. Nearly 23 miles are on the federal impaired waters list, and it contains 1,4-Dioxane, a likely carcinogen, discharged from the City of Asheboro’s wastewater treatment plant. Another 131 miles of tributaries to the river are also impaired, state records show.
“We already have a polluted river,” Stephens said.
Lee County records show Butler Well No. 3 is on a 643-acre forested tract owned by Ed Myrick of Pompano Beach, Florida. However, Dan Butler, who lives in Southern Pines, purchased the mineral rights beneath that property in 1975 from the previous land owner, Weyerhauser, the timber company.
Butler owns more than 2,700 acres of mineral rights in Lee County, state records show.
Since 1998, several companies have conducted exploratory drilling of Butler Well No. 3. However, given the comparatively small amount of gas and lack of a pipeline to transport it, they determined it wasn’t economically feasible and abandoned their projects.
Butler is a third-generation oil and gas developer. His grandparents were born in western Pennsylvania, where he owns “oil wells being drilled by the hundreds in the Alleghany State Forest,” according to a transcript of his comments at a 2012 Legislative Research Commission meeting.
Butler’s father, Howard, was the superintendent of the Coal Glen Mine in Chatham County in 1925 when it exploded and killed 53 men.
It’s uncertain whether the property, which currently allows residential and agricultural uses, would need to be rezoned. There are no provisions for data centers in Lee County’s current unified development ordinance, said County Zoning Administrator Thomas Mierisch. The UDO went into effect in 2006, before data centers and cryptomines “were really a thing,” Miersch said.
Spuller became a registered landman in North Carolina in 2021, according to state Department of Environmental Quality records. In this capacity Spuller can negotiate business agreements for exploration or development of natural gas.
Although Deep River Data officials also work for other cryptocurrency interests, Spuller said the project would not be a cryptomine. “It is envisioned as a modular data-infrastructure project” that would include AI workloads and other compute-intensive research, he said.
Deep River Data was incorporated on April 30, according to the North Carolina Secretary of State business registry. The company’s officers work in cryptocurrency: Spuller, Dan Fisher and Gerald Wilkie, Jr. A separate Wilkie-run enterprise, HM Tech, which operates out of a large, blue warehouse on South Maple Street in Graham, is listed as a “managing member” of Deep River Data.
HM Tech is a bitcoin mining facility and repair center. Two other top executives, Alun Williams and Murray Stahl, are with Horizon Kinetics, a New York-based investment firm whose funds include cryptocurrency.
Wilkie was among 55 cryptocurrency company representatives who signed a letter in 2022 to U.S. Environmental Protection Agency Administrator Michael Regan disputing the industry’s environmental harm. Two dozen congressional Democrats had previously sent a letter to Regan expressing their “serious concerns regarding reports that cryptocurrency facilities across the country are polluting communities and are having an outsized contribution to greenhouse gas emissions.”
Wilkie signed the letter in his role as founder and president of HMTech.
“There are no pollutants, including carbon dioxide, released by digital asset mining,” the cryptocurrency companies wrote. “Associated emissions are a function of electricity generation, which is a consequence of policy choices and economic realities shaping the nature of the electrical grid. Digital asset miners simply buy electricity that is made available to them on the open market, just the same as any industrial buyer.
“It is imperative that elected officials in the United States recognize that bitcoin … is the most important financial, economic, and accounting innovation in the history of humanity.”
Wilkie did not respond to an email and voicemail from Inside Climate News requesting an interview.
In addition to Deep River Data, Spuller is the executive vice president of industry affairs for the Blockchain Association, headquartered in Washington, D.C. However, Deep River Data is separate from that work, he said.
Earlier in his career, Spuller worked as the communications director for former Republican Gov. Pat McCrory’s inaugural committee. Spuller parlayed that connection for a marketing position at the state Department of Commerce, according to his LinkedIn page, where he worked closely with the Office of the Commissioner of Banks to help negotiate and pass the North Carolina Money Transmitters Act of 2016.
Former Lt. Gov. Dan Forest appointed Spuller to the North Carolina Blockchain Initiative in 2019, where he was a co-chairman and member until this year. From 2016 to 2020, he led membership and growth at the Chamber of Digital Commerce.
On Oct. 20, Spuller, representing the Blockchain Association, and Eric Peterson, senior government affairs manager at Kraken Digital Assets Exchange, appeared before the first state House Select Committee on Blockchain and Digital Assets.
They were advocating for legislation favorable to stablecoin, which is considered less volatile than other types of cryptocurrency. It can also be used to transfer funds between different crypto tokens.
Spuller was urging the passage of House Bill 92, the North Carolina Digital Assets Investment Act. It would authorize the state treasurer to invest a portion of public funds in the digital assets, study employment employee investment options, and evaluate the creation of a state-level digital asset reserve.
This measure passed the House earlier this year, but is still waiting for Senate approval.
“Hopefully they will pass it because I think that would also send really a fantastic message to the global economy that our state’s open for business,” Spuller said. “There’s no reason not to pass that. That would be on my wish list.”
https://insideclimatenews.org/news/01112025/north-carolina-natural-gas-well-data-center/
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US: APS Unveils 2,000-MW Desert Sun Natural Gas Project in Arizona
Arizona Public Service plans to build the 2,000-MW Desert Sun natural gas plant near Gila Bend to meet growing energy demand from homes, businesses, and data centers while protecting existing customers through a subscription-based funding model.
(P&GJ) — Arizona Public Service (APS) announced plans to build a natural gas-fired power plant west of Gila Bend, Arizona, capable of generating up to 2,000 megawatts (MW) to support the state’s fast-growing power demand.
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The proposed Desert Sun Power Plant would be built in two phases. The first phase would serve existing customers through APS’s competitive procurement process, while the second phase would expand capacity for new, extra-large energy users such as data centers through a subscription-based funding model.
“Arizona’s energy needs are growing faster than at any time in our history,” said Jacob Tetlow, APS Executive Vice President and Chief Operating Officer. “Additional natural gas generation is essential to support our existing customers and to begin addressing unprecedented requests from extra-large energy users, such as data centers. By pursuing a ‘growth pays for growth’ strategy, this project protects customers while supporting data centers needed for the U.S. to compete globally.”
Under the model, extra-large users would pay for the additional capacity through long-term contracts, ensuring costs are not passed to existing residential or small-business customers. The approach, APS said, would accelerate infrastructure investment while maintaining affordability and reliability for all ratepayers.
Phase 1 of the project is expected to begin serving customers by late 2030, with Phase 2’s schedule determined in coordination with participating subscribers. The plant will feature advanced emissions controls and high-efficiency technology to comply with federal and local air quality standards.
APS plans to supply natural gas to the Desert Sun facility via the proposed Transwestern Pipeline Desert Southwest Expansion and connect the plant to the power grid through new transmission infrastructure.
State leaders praised the project for its potential economic and reliability benefits. “Natural gas generation is a critical component of a reliable and affordable grid,” said Representative Gail Griffin, Chairwoman of the Arizona House Natural Resources, Energy and Water Committee. “I applaud APS for its investment in Desert Sun Power Plant which will provide firm, dispatchable energy to support quality service for existing and future customers in Arizona.”
APS said construction of the Desert Sun Power Plant would create hundreds of construction jobs and generate millions in new tax revenue for local and state governments.
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Israel: Energean signs MoU to export Israeli gas to Cyprus
Energean, which operates Israel’s offshore Karish, Tanin and Katlan gas fields, has signed a deal with Cypriot company Cyfield, to supply natural gas via a new pipeline.
Greek energy exploration and production company Energean plc (LSE: ENOG; TASE: ENOG), which operates Israel’s offshore Karish, Tanin and Katlan gas fields, has signed a memorandum of understanding (MoU) with Cypriot company Cyfield, to supply natural gas to a electricity production plant that the company will build near Larnaca. If the project will be approved by the Cypriot government, Cyprus will become the third country to import natural gas from Israel after Egypt and Jordan.
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Energean will finance and build a new underwater pipeline that will connect the Karish platform to Cyprus, at a cost of hundreds of millions of dollars. At this stage, the company declines to specify the quantities and scale, but it is clear that to justify the investment, the expected from the project will have to reach at least hundreds of millions of dollars over the years.
The company’s announcement said, “Energean has proposed to the governments of Cyprus and Israel to export natural gas from Israel to Cyprus via a new gas pipeline, a project with many benefits for both markets, which will promote regional cooperation in the energy sector and contribute to the development of a competitive and interconnected gas market in the Eastern Mediterranean. According to the proposal, Energean will be responsible for the design, construction, and operation of a new underwater gas pipeline owned by the company, which will connect the Karish platform, operating in Israel’s economic waters, directly to Cyprus.” The pipeline will connect directly from the Karish platform to Cyprus, without first passing through Israel.
Government monopoly
Since this is a large-scale infrastructure project, the agreement requires the approval of the Cypriot government. According to media reports in Cyprus, the Cypriot Ministry of Energy is examining the memorandum of understanding signed between Energean and Cyfield, and its official response will be forthcoming. One of the main issues being examined is the status of the state gas monopoly DEFA, which holds exclusive rights to import gas into the country, while Cypriot energy company Cyfield is interested in importing it directly.
Israel’s Minister of Energy and Infrastructure Eli Cohen has already welcomed the proposal. He said, “Israeli gas is a tremendous strategic asset for the State of Israel. Selling gas to Cyprus will strengthen Israel’s political position in the region in general and vis-à-vis European countries, will help increase stability and prosperity in our region, and will bring billions of shekels to the country. I intend to continue working to expand export destinations for Israeli gas.”
Energean CEO Mathios Rigas added, “Promoting the flow of natural gas to Cyprus is a significant step for the benefit of the economy and consumers. Our proposal provides a practical and effective solution to reduce Cyprus’ energy isolation, through direct access to natural gas from a neighboring source.”
Cyfield Group CEO George Chrysochos said, “The collaboration with Energean has the potential to change the future of Cyprus’ energy. We look forward to working closely with the Cypriot and Israeli authorities to bring this important project to fruition, subject to all necessary approvals.”
https://en.globes.co.il/en/article-energean-signs-mou-to-export-israeli-gas-to-cyprus-1001525307
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Australia: ConocoPhillips begins natural gas drilling campaign offshore eastern Australia
PERTH, Australia, Nov 3 (Reuters) – U.S. independent ConocoPhillips (COP.N), b began drilling its first exploration well as part of larger campaign searching for natural gas offshore eastern Australia, 3D Energi (TDO.AX), its junior partner in the project, said on Monday. Work began over the weekend on the Essington-1 well, which will take 32 days to drill down to 2,650 metres (8,694 feet), 3D Energi said in a filing to the ASX.
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The well is the first in the Otway Exploration Drilling Program to develop new gas for Australia’s eastern domestic market, the company said.
Eastern and southern Australia are facing supply shortfalls before the end of the decade, causing tension between gas exporters and domestic manufacturers.
The campaign represents one of the first major offshore exploration campaigns in East Coast waters in almost seven years as the old fields in the Bass Strait offshore the state of Victoria run dry.
Under the Otway program, Conoco will drill two wells this year, out of a total of six planned, and an option for four additional wells if needed.
The tight domestic eastern gas market has been a source of political tension for many years.
An “Australian Domestic Gas Mechanism” trigger was introduced in late 2017, limiting the export of spot cargoes when gas was tight from the three liquefied natural gas consortia in Queensland fed by the state’s onshore coal seam gas fields, with backup from Victorian gas supplies. ConocoPhillips is operator of one, Australia Pacific LNG.
The current Labor government has considered expanding export controls since its first term in 2022. Japan has argued against controls as it is Australia’s largest LNG buyer.
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Natural Gas / LNG Utilization / Bio-LNG
UAE: Sharjah discovers fifth onshore Gas Field at Al Hadiba
Sharjah has taken a decisive step towards energy self-sufficiency with the discovery and appraisal of new gas reserves in the Al Hadiba field. The findings, confirmed through the Hedebah-02 well, mark the emirate’s fifth onshore gas and condensate field, reinforcing Sharjah National Oil Corporation’s (SNOC) growing record of exploration success and its commitment to sustainable energy development.
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A new discovery in Al Hadiba
The Sharjah Petroleum Council (SPC), a government entity, has announced that economically viable gas reserves have been identified in the Al Hadiba field, situated north of the Al Sajaa Industrial Area. The discovery follows a recent drilling campaign conducted by SNOC, which completed the Hedebah-02 well over several months.
The well is set for testing in the coming days to verify the quantities and overall potential of the reserves. Al Hadiba joins four other onshore fields in Sharjah, Al-Saja’a, Kahif, Mahani, and Muayed. Notably, Muayed has been converted into a gas storage facility, highlighting Sharjah’s strategic approach to both production and storage infrastructure.
From discovery to appraisal: Hedebah’s rapid progress
The Hedebah Gas Field first came into focus in 2024 with the drilling of the Hedebah-01 well, which revealed gas and associated liquids within the Thamama geological formations. That initial discovery was swiftly developed, entering production within ten months and contributing directly to the emirate’s energy supply.
Building on this momentum, the 2025 drilling campaign focused on expanding and appraising the field’s potential. The Hedebah-02 well, drilled to a total depth of 13,200 feet, confirmed additional gas-bearing zones. Plans are underway for the well to be connected to production in the coming months, alongside further drilling aimed at assessing the full extent of the field.
Leadership and strategic vision
Khamis Al Mazrouei, CEO of SNOC, emphasised the significance of the latest milestone: “The successful drilling and testing of our second well at the Hedebah Gas Field marks another important milestone in SNOC’s journey to strengthen Sharjah’s energy resilience and long-term security. This achievement reflects our unwavering commitment to operational excellence, innovation, and sustainable growth. By continuing to unlock the emirate’s natural gas potential, we are delivering on our vision to ensure reliable energy for Sharjah today, while building a stronger, more resilient foundation for the future.”
Masoud Al Hamadi, Executive Director of Upstream at SNOC, added: “The successful testing of Hedebah-02 is the result of outstanding teamwork, from geoscience and engineering studies through to planning and execution. It demonstrates SNOC’s ability to efficiently move discoveries toward production.”
Advancing Sharjah’s energy independence
The Hedebah development underscores SNOC’s ongoing commitment to advancing Sharjah’s energy independence. Beyond exploration and production, the corporation continues to enhance its strategic gas storage and processing capabilities, ensuring that the emirate’s growing energy needs are met reliably and sustainably.
With the Al Hadiba field now entering appraisal and Hedebah-02 nearing production, Sharjah is consolidating its position as a regionally significant hub for natural gas, combining resource development with operational excellence and long-term energy planning.
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AD Ports, Nimex to Build $8 Billion LNG, LPG Terminal Hubs at Khalifa Port
AD Ports Group and Nimex Terminals have signed an $8 billion agreement to build LNG and LPG terminal hubs at Khalifa Port. The five-year development will expand storage and export capacity for low-emission fuels, supporting the UAE’s growing role in global energy logistics.
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ABU DHABI (P&GJ) — AD Ports Group has signed two long-term agreements with Nimex Terminals to develop the United Arab Emirates’ first private-sector liquefied natural gas (LNG) and liquefied petroleum gas (LPG) terminal hubs at Khalifa Port, in a deal valued at over AED 30 billion ($8 billion).
The projects are designed to strengthen the UAE’s position as a global energy and logistics hub and support the country’s Net Zero 2050 strategy. Once operational, the LNG and LPG terminals will enable vessel fueling and transshipment, expanding Khalifa Port’s capability to meet growing international demand for cleaner energy.
Under the agreements, AD Ports Group will invest up to AED 1.3 billion ($354 million) in dredging and jetty development, while Nimex Terminals will contribute AED 2.6 billion ($700 million) toward storage tanks, regasification units, pipelines, flare structures, and other associated infrastructure.
The LNG terminal will span 130,000 square meters with 400,000 cubic meters of cryogenic storage capacity, while the LPG facility will cover 90,000 square meters with 280,000 cubic meters of total capacity. Both facilities will serve as import, export, and transshipment hubs, targeting growing demand from Asian markets.
Construction will take place in phases over five years, with initial operations expected by mid-2028. The LNG terminal is projected to reach full capacity by 2031, and the LPG terminal by 2033.
“These agreements represent a transformative milestone for Khalifa Port and the UAE’s energy sector,” said Captain Mohamed Juma Al Shamisi, Managing Director and Group CEO of AD Ports Group. “Through our partnership with Nimex Terminals, we will equip Khalifa Port with lower-impact fuel infrastructure that advances our commitment to a more sustainable future.”
Azmat Mahmood, Executive Chairman of Nimex Terminals Ltd., said, “The LNG and LPG infrastructure investments we have agreed upon will further enhance the attractiveness of one of the world’s fastest growing container ports and reaffirm our commitment to driving sustainable economic growth.”
The developments are expected to attract foreign investment, create high-value jobs, and boost regional shipping and logistics activity across the Middle East.
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Powering the Middle East’s low-carbon LNG future through innovation
Arnaud Pieton, CEO of Technip Energies, discusses how the company’s technologies, from electrified LNG to low-carbon ethylene and integrated hydrogen–CCUS systems, are redefining its role in the global energy transition. As the global LNG landscape progresses toward lower-carbon solutions, how does Technip Energies plan to support the Middle East developments?
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LNG remains a cornerstone of the global energy mix and it’s an opportunity for the long term. What we’re seeing today is three strong trends shaping this market: the need for secure and affordable access to energy, a steady increase in global demand, and regional policies driving lower-carbon production. And the Middle East, of course, sits right at the center of this dynamic.
At Technip Energies, we’re helping our clients respond to these trends. Our differentiation lies both in how we execute and how we innovate. Over the past decades, we’ve proven our ability to deliver mid to mega-scale projects, to leverage modular and productised solutions like SnapLNGTM by T.EN, and to advance decarbonisation through electrification and CO₂ capture.
And this know-how is tangible and recognised by the market. You can see it in action with Ruwais LNG, a landmark project with ADNOC that will be the first LNG export facility in the MENA region to run on clean power. In Oman, Marsa LNG will follow the same path, using renewable energy to produce low-carbon LNG for maritime transport.
Today, with more than 35% market share of LNG projects reaching FID since 2020, we’re proud to be shaping the next generation of LNG: modularised, electrified, and designed for lower carbon intensity.
Technip Energies has been advancing technologies in ethylene and refining decarbonisation as well as CCUS. How do you see these innovations reshaping the company’s leadership role in the energy transition over the next decade?
Indeed, beyond LNG, our leadership also extends to industrial decarbonisation, and ethylene is a great example. For more than 50 years, we’ve designed and delivered some of the world’s largest and most complex ethylene facilities. We hold roughly half of the global licensing market, which says a lot about our experience and, more importantly, the trust of our clients.
But leadership also means evolution. Over time, our clients’ priorities have changed and so have we. We’ve reworked our technologies to decarbonise ethylene production and make plants more efficient. Our low-emission cracking furnaces, proprietary equipment, and advanced simulation tools now enable up to 30% CO₂ reduction and around 20% energy efficiency improvement.
In fact, what we’re doing today is connecting the dots across the entire low-carbon value chain, from hydrogen production to carbon management. Our role is to bring proven solutions to our clients at every step of that journey, especially in hard-to-abate industries.
As you mentioned, we have two flagship solutions that make this possible. First, with BlueH₂ by T.EN™, we deliver scalable hydrogen solutions that can capture up to 99% of CO₂ emissions. Then there’s Canopy by T.EN™, our integrated suite of post-combustion carbon capture solutions for any type of emitter, powered by Shell’s proven CANSOLV® CO₂ Capture System.
These solutions, combined with our strong integration and execution know-how, make us a trusted partner for low-carbon projects. Because in the end, what our clients need most are proven technologies, scalable solutions, and the confidence that their projects will be delivered successfully.
This positioning has already led us to two landmarks projects: Net Zero Teesside Power in the UK, the world’s first gas-fired power station with carbon capture, and Blue Point One in the US, the world’s largest low-carbon ammonia plant.
How can an international company such as Technip Energies have a strong local content across the region?
Well, while we’re truly a global company, we’ve always believed that success is built through collaboration and proximity. Understanding our clients’ needs, being close to them, and building trust through everyday teamwork, that’s really what makes the difference.
That’s exactly the spirit behind NT Energies, our joint venture with NMDC Energy based in Abu Dhabi. It brings together strong local execution capabilities with Technip Energies’ global expertise in technology and project management. NT Energies is already delivering real value across the UAE, the wider Middle East, and North Africa, from blue and green hydrogen to CO₂ capture, waste-to-energy, biorefining, and biochemistry.
What I really like about this model is that it creates a true win-win dynamic: developing local talent, supporting regional economies, and building long-term, trust-based partnerships with our clients.
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Uzbekistan and China to build underground gas storage facility
Uzbekistan is set to construct an underground gas storage facility in partnership with China, the Ministry of Energy announced following a high-level meeting. During talks between Uzbekistan’s Minister of Energy, Jurabek Mirzamahmudov, and Dai Houliang, Chairman of the China National Petroleum Corporation (CNPC), both sides discussed expanding energy cooperation and launching new strategic projects.
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The discussions covered several key areas, including the construction of the Central Asia–China gas pipeline, development of gas condensate fields in the Bukhara region, establishment of the underground gas storage facility, commissioning of new energy fields, and training programs for qualified specialists in Uzbekistan’s oil and gas sector.
The planned storage facility is expected to play a critical role in ensuring stable gas supplies and balancing seasonal demand in Uzbekistan and the wider region.
As one of the largest energy consumers globally, China views Central Asia as a priority region for its foreign energy policy. The Central Asia–China gas pipeline, consisting of three operational lines, already delivers billions of cubic meters of natural gas from Turkmenistan, Uzbekistan, and Kazakhstan to China each year. Additionally, the Kazakhstan–China oil pipeline further strengthens Beijing’s energy security network.
Long-standing Uzbekistan–China Partnership
Uzbekistan and China share a deep-rooted relationship that dates back to the Great Silk Road era, when trade routes connected Samarkand and Bukhara with the Chinese heartland.
China officially recognized Uzbekistan’s independence on December 27, 1991, and diplomatic relations were established on January 2, 1992.
Over the past thirty years, relations between the two countries have steadily advanced—from a strategic partnership established in 2012 to a comprehensive strategic partnership in 2016, and, most recently, to a comprehensive strategic partnership for a new era in 2022.
https://daryo.uz/en/2025/11/02/uzbekistan-and-china-to-build-underground-gas-storage-facility/
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Sabah Acquires 25% Ownership In Petronas’ PFLNG 3 Project
KOTA KINABALU, Sabah has officially completed the acquisition of a 25% equity stake in Petronas PFLNG 3 Sdn Bhd, marking a significant step forward in the state’s efforts to strengthen its participation in Malaysia’s oil and gas sector and deepen collaboration with Petroliam Nasional Bhd (Petronas).
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Chief Minister Datuk Seri Hajiji Noor said the move, executed through SMJ Energy Sdn Bhd — Sabah’s state-owned energy company — in partnership with Petronas LNG Sdn Bhd, represents a major milestone in enhancing Sabah’s role in upstream and downstream energy ventures.
“This acquisition not only reinforces the close working relationship between Sabah and Petronas, but also sets the foundation for future strategic collaborations in the oil and gas industry,” Hajiji said in a statement on Friday.
Petronas PFLNG 3 is currently developing a US$3.1 billion (RM13 billion) nearshore floating liquefied natural gas (FLNG) facility located at the Sipitang Oil and Gas Industrial Park (SOGIP). Designed to produce two million tonnes of LNG annually, the project is scheduled to commence operations in the second half of 2027.
Hajiji said the state’s participation in PFLNG 3 aligns with Sabah’s broader ambition to secure a stronger foothold in key energy projects within its borders, ensuring greater revenue generation and long-term sustainability for its energy sector.
The equity acquisition follows the signing of a heads of agreement between SMJ Energy and Petronas LNG Sdn Bhd in July 2025, witnessed by Hajiji and Petronas president and group chief executive officer Tan Sri Tengku Muhammad Taufik in Kuala Lumpur.
“With this partnership, Sabah is taking concrete steps towards becoming a significant player in Malaysia’s LNG industry. It reflects our commitment to developing local capacity, encouraging technology transfer, and ensuring that the people of Sabah benefit directly from the state’s natural resources,” Hajiji said.
The latest acquisition adds to SMJ Energy’s expanding investment portfolio, which already includes a 50% participation interest in the Samarang Production Sharing Contract, a 10% stake in Petronas LNG 9 Sdn Bhd, and 25% equity in Petronas Chemicals Fertiliser Sabah Sdn Bhd (SAMUR).
In addition, SMJ Energy fully owns Sabah International Petroleum Sdn Bhd (SIP), which manages strategic offshore assets such as floating production storage and offloading (FPSO) and floating storage and offloading (FSO) vessels — key infrastructure supporting the state’s growing energy operations.
Hajiji added that the state government will continue exploring new partnerships with Petronas and other major players to advance Sabah’s participation in sustainable energy development, boost industrial activity at SOGIP, and enhance the state’s position as a regional energy hub.
https://theexchangeasia.com/sabah-acquires-25-ownership-in-petronas-pflng-3-project/
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Bangladesh continues on the path of high-cost LNG sourcing
Experts also point out that Bangladesh has not conducted major local gas exploration in the past two decades, nor made significant investments in the sector. Bangladesh continues importing costly liquefied natural gas (LNG) to address the country’s gas shortage. In the current FY 2025–26, Petrobangla plans to import LNG worth around BDT 550 billion. Roughly 29 percent of these cargoes are expected to be sourced from the spot market, where prices are significantly higher than in long-term supply contracts.
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Experts say Bangladesh could have purchased more LNG at lower prices if it had prioritized long-term purchase agreements earlier. That approach would have reduced reliance on the volatile spot market while cutting Petrobangla’s overall spending on LNG.
According to Petrobangla sources, 71 LNG cargoes will arrive in the country this fiscal year under existing and new long-term contracts. Another 33 cargoes are planned from the spot market. Prices for LNG under long-term contracts range from $9 to $11 per million British thermal units (MMBtu), while spot market prices are projected at around $14 per MMBtu. However, Petrobangla’s most recent purchase from MS Aramco Trading Singapore Pte Ltd cost $11.88 per MMBtu.
Energy analysts describe LNG as an extremely expensive fuel for Bangladesh’s energy system, considering the country’s situation and the supply system. They argue that the previous government could have secured cheaper and more stable gas supplies if it had emphasized affordability and long-term contracts. That would have reduced dependence on spot market purchases and saved substantial public funds. Under Petrobangla’s current plan, a large share of LNG imports will come from the spot market, which is an approach experts say could have been avoided if more long-term deals were secured.
Experts also point out that Bangladesh has not conducted major local gas exploration in the past two decades, nor made significant investments in the sector. They note that while the power sector has received generous allocations over the past 15 years, the energy sector’s budget has been minimal. In the current fiscal year, only slightly more than BDT 10 billion has been allocated for well drilling and geological surveys — an amount specialists describe as inadequate for any large-scale exploration effort.
Officials at the Energy Division and Petrobangla say LNG imports from the spot market will gradually decline as cargoes under new long-term contracts increase. LNG trading follows the calendar year, and based on that system, Bangladesh will buy only 17 cargoes from the spot market next year — far fewer than those purchased under long-term contracts. They added that keeping a small window open for spot market purchases mainly allows flexibility in response to price and supply conditions. When prices rise, the government can suspend or reduce spot purchases.
Regarding the issue, Energy and Mineral Resources Secretary Mohammad Saiful Islam told Bonik Barta, “There are some challenges in importing all LNG cargoes under long-term contracts. It’s important to keep at least 10 to 20 percent of cargoes open for purchase from the spot market. Import complications or supply disruptions at terminals can arise during adverse weather. In such cases, the spot market often provides an immediate solution. The option also allows us to take advantage when prices drop. The fiscal year figure may appear higher, but on a calendar-year basis, only 17 cargoes will be bought from the spot market in the next year (2026), which is significantly lower than the number under long-term contracts.”
One major factor driving Petrobangla’s high LNG import costs is the absence of a land-based LNG terminal. The previous Awami League government prioritized floating terminals instead, leaving land-based facilities undeveloped. This has repeatedly exposed Petrobangla’s supply system to operational risks and forced it to bear additional expenses such as regasification charges and terminal shutdown costs. As a result, LNG has become even more expensive.
For FY 2025–26, regasification expenses from the Summit and Excelerate terminals are projected at BDT 22.51 billion. Bangladesh began importing LNG in FY 2018–19. Over the past eight years, the two floating terminals have cost an estimated BDT 160 billion in regasification charges alone, assuming an annual average of around BDT 20 billion. Experts in the energy sector believe that if a land-based terminal had been built in the first year of LNG imports, it could have been constructed with around 70 percent of that total regasification expenditure.
A former senior official of Petrobangla, speaking on condition of anonymity, told Bonik Barta, “Three years ago, proposals were made by Qatar and Oman to sign long-term LNG purchase contracts. But the government at that time didn’t accept those offers. They had sent several letters offering LNG at favorable prices. However, because global gas prices were low at that time, the proposals were ignored. If the opportunity had been taken then, the Energy Division could have signed major long-term deals at much lower prices.”
According to the Rupantarita Prakritik Gas Company Limited (RPGCL), the previous Awami League government initiated a plan back in 2019 to build a land-based LNG terminal with a capacity of 1 billion cubic feet (BCFE) in Matarbari of Moheshkhali, Cox’s Bazar. An Expression of Interest (EOI) was issued for the project, and five companies were shortlisted. However, allegations suggest that the plan did not move forward due to commission-related trading in spot market LNG imports and the involvement of several ministers and bureaucrats of the former government.
Experts say that if the land-based terminal had been constructed, it would have ensured a more reliable gas supply system and reduced operational complexities of floating terminals while creating larger storage capacity. It would also have helped reduce the risk of LNG supply disruptions during natural disasters.
After the interim government assumed office, the initiative to construct the land-based terminal was revived. The project will now proceed under a public-private partnership (PPP) model rather than through a single company. So far, at least six companies have expressed interest to the Energy and Mineral Resources Division (EMRD) in the terminal’s construction.
When asked about the progress of the project, the Energy Division secretary told Bonik Barta, “Progress on the construction of the land-based LNG terminal is satisfactory. After the current government took the initiative, several companies have shown strong interest. The government has decided to build the terminal under the PPP model. The interested companies have already been shortlisted, and a project director (PD) has been appointed. We expect to move forward on a larger scale very soon.”
Officials from the EMRD told Bonik Barta that constructing a land-based LNG terminal is a long-term process. Given the country’s gas supply needs, the project should have been initiated much earlier. Currently, one year has already been spent on the consulting firm for the terminal. Finalizing contracts is expected to take another year. Once fieldwork begins, it will take seven to eight years to become operational. The project also involves an estimated investment of at least BDT 150–200 billion. There was uncertainty over whether the government would fund this entirely, attract foreign investment, or pursue a joint venture. Officials say these factors have been the main reasons for delays in constructing the land-based terminal.
Globally, information from various company websites shows that building a permanent land-based LNG terminal costs at least $500 million to $1 billion, depending on location, capacity, project complexity, and construction timeline. Data show that the projected cost of an onshore LNG terminal in Bangladesh is around $1 billion, while a floating terminal is estimated at $500 million. For comparison, Germany’s Stade land-based terminal was projected to cost $567 million in 2018. On the other hand, India’s Dhamra Port terminal in Odisha was built in 2017 at a cost of $950 million.
Domestic gas production in Bangladesh has been steadily declining each year. A lack of major long-term investment in local gas exploration, combined with an increase in LNG imports, has created a significant supply gap. Currently, the country receives just over 2,750 million cubic feet of gas against a demand of 3,800 million cubic feet of LNG. Experts warn that if local gas supply continues to decline, the situation will worsen. They emphasize that increasing imports without intensifying exploration efforts will raise the country’s energy risk.
Petrobangla sources indicate that a total of 115 LNG cargos are being purchased for FY 2025-26. Under long-term contracts, 40 cargos will be procured from QatarEnergy at a cost of BDT 156.17 billion, and 16 cargos from Oman at BDT 58.32 billion. Under short-term contracts with the same company, 11 cargoes will cost BDT 59.32 billion. Additionally, under new long-term contracts, six cargos from Qatar Energy will cost BDT 23.30 billion, two cargos from OQ Trading will cost BDT 8.22 billion, and seven cargos from the U.S.-based Excelerate Energy are budgeted at BDT 28.22 billion. Spot market purchases of 33 cargoes are projected to cost BDT 181.85 billion.
Energy expert and geologist Professor Badrul Imam told Bonik Barta, “Meeting demand through imports is not a solution given the decline in local gas. In fact, it poses a long-term risk. Increasing LNG imports continues the policies of the previous government. We are not getting large reserves through drilling, this is not believable. Geologically, Bangladesh is a delta, similar to Nigeria and Indonesia. If they can access large gas reserves, why can’t we? They keep saying drilling is ongoing. But we need to see how much is actually being drilled. Compared to other countries, Bangladesh has drilled the fewest wells over recent years. I don’t think the current pace is significantly higher. The real long-term solution is to increase domestic production and conduct extensive exploration and drilling in undiscovered areas.”
EMRD sources said that eight rigs are currently operating for local gas well drilling. Two more rigs are being acquired. In addition to the 50 wells already planned, the current interim government has set a target to drill another 100 wells by 2028.
https://en.bonikbarta.com/business/wEGFZMihm6dGJNiX
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US becomes first country to export 10 million tonnes of LNG in single month
HOUSTON – The U.S. has become the first country to export 10 million metric tonnes (mmt) of liquefied natural gas in a single month, according to preliminary data from financial firm LSEG. The U.S. exported a record 10.1 mmt of the liquid fuel in October, up from a revised figure of 9.1 mmt in September, LSEG data showed.
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Already the world’s largest LNG exporter, the U.S. has been ramping up sales with four record-setting months in 2025. The surge was led by the start-up of Venture Global’s (VG.N), Plaquemines export plant and the ramp-up of Cheniere’s (LNG.N), Corpus Christi Stage 3 project, the data showed.
The Plaquemines facility, located in Louisiana, sold 2.2 mmt last month, surpassing its previous high of 1.6 mmt in September, the data showed.
Cheniere’s Corpus Christi export facility exported 1.6 mmt, also a record for the plant. With Sabine Pass exporting 2.6 mmt in October, the company sold a combined 4.2 mmt, or 42% of all of the LNG exported by the U.S.
When completed, the Corpus Christi Stage 3 operation will allow Cheniere to export more than 50 million metric tonnes per year starting in 2026, CEO Jack Fusco said in a recent earnings call.
Venture Global and Cheniere were responsible for 72% of the country’s total exports in October, LSEG data showed.
EUROPE IS THE BIGGEST CUSTOMER
Europe remained the prime destination for U.S. LNG, with 6.9 mmt, or nearly 69% of total exports, heading to the continent last month. That figure compares with 6.22 mmt in September, as Europe continued to fill storage ahead of the winter, LSEG ship tracking data showed.
U.S. LNG exports to Asia last month stood at 1.96 mmt compared to 1.63 mmt in September, the ship tracking data showed.
U.S. LNG exports to Latin America fell in October to 0.57 mmt, down from September’s 0.63 mmt, as the South American continent prepares to enter warmer summer months, LSEG ship-tracking data show.
Egypt, meanwhile, bought five cargoes for a total of 0.43 mmt, less than the 0.5 mmt it purchased in September, the data showed.
There were two cargoes that went to Senegal for a total of 0.1 mmt, and two that were seeking orders from customers for another 0.1 mmt, according to LSEG ship-tracking data.
In October, gas traded at $10.88 per million British thermal units at the European benchmark Dutch Title Transfer Facility , down from $11.13 in September. At the Japan Korea Marker benchmark in Asia, October’s average price was $11.11, compared to $11.32 in September.
The TTF and JKM prices were so close that they provided little incentive for U.S. LNG exporters to shift from selling to the European market to the more distant Asian market.
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Oman: IGC signs 19 gas agreements worth $8.8bln
The Integrated Gas Company (IGC) – the sole aggregator and supplier of natural gas in the Sultanate of Oman – signed a series of strategic gas agreements with local and international companies at a ceremony held under the auspices of Sultan bin Salim Al Habsi, Minister of Finance, here on Sunday, November 2, 2025. The event, held at the Mandarin Oriental Hotel, brought together key stakeholders from the industrial sector to strengthen the integration of the gas value chain and ensure the sustainable management of natural gas resources in Oman.
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During the ceremony, 14 gas sales agreements were signed with local and international companies worth more than RO 3.4 billion, extending over a ten-year investment period. Additionally, three gas purchase agreements were concluded with major producers — Occidental of Oman Inc (OXY) and Energy Development Oman (EDO) — along with two memoranda of understanding with companies and projects under the OQ Group, including the Duqm Petrochemical Complex and OQ Alternative Energy, to enhance joint cooperation.
The agreements involved partnerships with investors from India, China, the United States, France, Kuwait, and the United Arab Emirates, in addition to active participation from Omani firms engaged in energy, petrochemicals, cement, mining, healthcare, and manufacturing.
Dr Musallam Mahad Qatan, Chairman of the Board for Integrated Gas Company (IGC) and Director General of the Directorate General of Revenues at the Ministry of Finance, explained that IGC is implementing the government’s gas allocation policy and contract management strategy between producers and private sector investors, while enhancing coordination with relevant government institutions.
He emphasized that the signed agreements — covering major industrial and free zones such as Duqm, Suhar, Salalah, Nizwa, and Sur — aim to enhance local industrial value and competitiveness across Oman’s governorates. He added that these efforts reflect the government’s and private sector’s shared commitment to building a partnership-based economy that ensures the optimal use of national and human resources.
Abdulrahman bin Humaid Al-Yahyaei, Chief Executive Officer of the Integrated Gas Company (IGC), stated that the ceremony marked a turning point for both the company and Oman’s gas sector. He said the agreements would strengthen investor confidence in Oman’s integrated gas system — both upstream and downstream — encouraging greater global investment in gas exploration and production.
He added that the average gas volume allocated to end consumers will exceed 27.9 million cubic meters per day once all projects are operational. Al-Yahyaei noted that the agreements reflect Oman’s commitment to energy security, sustainable industrial growth, and economic diversification in line with Oman Vision 2040.
He further highlighted that the initiatives promote environmental sustainability by using gas to power industries and transitioning gradually toward alternative energy and hydrogen, while also utilizing associated gas for industrial use instead of flaring during oil production.
https://www.zawya.com/en/economy/gcc/oman-igc-signs-19-gas-agreements-worth-88bln-pyu8peu3
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Greece: New Gas Compression Station Opens in Northern Greece
The €134 million Komotini facility boosts Greece’s role as an energy hub for Southeast Europe, expanding gas exports to the Balkans and beyond amid Europe’s efforts to move away from Russian energy Anew natural gas compression station inaugurated today in Komotini is the latest addition to Greece’s expanding energy infrastructure, underscoring the country’s ambitions to serve as a key transit point for natural gas to Southeastern Europe. Operated by DESFA, the €134 million project aims to boost gas exports to neighboring countries including Bulgaria, Romania, Moldova, and Ukraine.
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During the opening ceremony, Deputy Minister of Energy Nikos Tsafos described the project as “pivotal not only for Greece, but for all of Europe,” noting that Eastern Macedonia and Thrace are emerging as a crossroads of energy flows. The region already hosts critical infrastructure linking Europe to alternative gas sources, from Azerbaijan via the Trans Adriatic Pipeline (TAP) to U.S. LNG through the Alexandroupolis floating terminal.
The new natural gas compression station is expected to support new natural gas–fired power plants that help balance Greece’s electricity system when renewable output is low. It also contributes to the so-called “vertical corridor”, designed to channel gas north through Greece toward Central and Eastern Europe. Together with a new station in Ampelia, it could allow exports of up to 8.5 billion cubic meters annually.
The Komotini project was completed in what officials called “record time” for European standards, following a final investment decision in late 2022, months after Russia’s invasion of Ukraine upended regional energy planning. The new infrastructure reflects how Greece, once a net gas importer, now re-exports significant volumes: about 11 of the 17 billion cubic meters that entered its system in 2023 were sent to neighboring markets.
While government officials emphasize the project’s strategic value, the broader question remains how such investments fit within Europe’s longer-term transition to renewables. Tsafos noted that the region is also attracting clean-energy projects, including wind power and a planned carbon-capture facility. For now, Komotini’s new station reinforces Greece’s growing presence in Europe’s reshaped energy landscape.
https://www.tovima.com/finance/new-gas-compression-station-opens-in-northern-greece/
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ABB to support ADNOC’s all-electric Ruwais LNG facility
ABB has been selected to provide advanced automation, electrical, and digital solutions for ADNOC’s Ruwais LNG facility, 230 km west of Abu Dhabi in the UAE. Once operational it will be the region’s first all-electric LNG plant, using electric-driven motors instead of conventional gas turbines. ABB will provide its microcontroller-based Electrical Control and Monitoring (ECM) system, a module of ABB AbilityTM System 800xA® distributed control system to increase operational efficiency and safety at the facility.
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As part of the contract – awarded by TJN, an engineering, procurement and construction joint venture involving Technip Energies, JGC Corp. and NMDC Group – ABB will supply its ECM system to provide real-time visibility and control of all electrical assets, enabling rapid fault detection, load optimisation, and power management to be achieved safely and reliably, while reducing downtime.
By using electric motors for its two liquefaction trains, the Ruwais LNG project can support emissions reduction efforts. According to the International Energy Agency (IEA), electrification of existing LNG terminals, and the use of low-emissions electricity to power these, could significantly reduce the greenhouse gas emissions associated with production, by around 60 million tpy of CO2-e.
Global LNG supply has grown faster than overall natural gas demand in recent years, with this trend set to continue with the delivery of nearly 300 billion m3 of new annual LNG supply capacity between 2025 – 2030.
“Electrification unlocks the full potential of LNG as a transition fuel to support decarbonisation efforts and meet growing energy demands by providing reliable, abundant and affordable natural gas around the world,” said Bjarte Pedersen, Senior Vice President IMEA at ABB’s Energy Industries division. “By improving operational efficiency, preventing fault downtime and optimising distribution, ABB’s ECM system safeguards production and extends asset life and we are pleased to support ADNOC’s Ruwais LNG facility with our integrated solutions.”
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Asia’s first physical bio-LNG supply deal signed under Singapore’s biomethane pilot
Singapore’s YTL PowerSeraya has signed a sales and purchase agreement with Malaysia’s BAC Renewable Energy (BACRE) for the supply of bio-LNG – marking the first physical bio-LNG deal in Asia, the companies confirmed on 4 November. The agreement, concluded under Singapore’s new ‘biomethane sandbox’ launched by the Energy Market Authority and the Economic Development Board on 27 October, is designed to pilot biomethane imports for power generation and industrial use.
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“This deal represents the first physical bio-LNG contract in Asia,” said Norzaifizy Khalid Nordin, BACRE’s business development director.
The Malaysian company will produce and aggregate bio-LNG across the ASEAN region and develop the associated logistics chain for delivery.
BACRE is advancing renewable gas projects in Malaysia and neighbouring markets, and plans to establish small-scale liquefaction plants across Southeast Asia.
It also intends to charter a small-scale LNG carrier to transport bio-LNG, including for marine bunkering applications.
YTL PowerSeraya, one of Singapore’s largest electricity producers with 3,100 MW of licensed generation capacity – roughly 30 % of the national total – said the move aligns with Singapore’s ambition to diversify its low-carbon energy mix.
The deal follows a series of biomethane-related announcements during Singapore International Energy Week 2025, signalling the city-state’s readiness to integrate renewable gases into its supply chain.
As a price benchmark, Platts assessed the Rotterdam subsidised bio-LNG bunker price on 4 November at €23.45/MMBtu, a premium of €13.83/MMBtu over conventional Northwest Europe LNG prices.
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Global LNG Development
Oman LNG renews long-term agreement with Baker Hughes
Muscat – Oman LNG has renewed its long-term services agreement with Baker Hughes, marking a new chapter in a partnership that has successfully spanned nearly two decades. Awarded in the second quarter of 2025, the 10-year extension reinforces the two companies’ shared commitment to operational excellence, reliability, and the continued advancement of sustainable LNG production in Oman.
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Under the renewed agreement, Baker Hughes will continue to support the availability and reliability of critical rotating equipment across Oman LNG’s three liquefied natural gas (LNG) trains, ensuring safe, efficient, and uninterrupted production.
A key highlight of this milestone is the establishment of the Oman iCenter, powered by Cordant – a major step forward in localising digital expertise and enabling future innovation. The Oman iCenter will serve as a hub for 24/7 monitoring of critical equipment, offering actionable digital insights and proactive solutions to enhance performance, improve efficiency, and support Oman LNG’s sustainability goals.
Beyond supporting Oman LNG’s operations, the iCenter is expected to serve Omani customers across the energy sector, expand its digital services footprint, develop skills for Omani professionals, and ultimately support global customers from Oman.
In alignment with Oman Vision 2040 and the company’s In-Country Value (ICV) objectives, Baker Hughes has committed resources to Omani workforce development, including specialised training and capability-building initiatives linked to the iCenter.
“This renewal marks an important milestone in our journey with Baker Hughes, reflecting a partnership built on trust, performance, and shared aspirations for sustainability and innovation,” said Hamad al Nu’amani, Chief Executive Officer of Oman LNG. “The establishment of the Oman iCenter represents a forward-looking investment in our people and in Oman’s digital future – strengthening our ability to deliver reliable and efficient energy while creating long-term value for the nation.”
Through this renewed agreement and the creation of the Oman iCenter, Oman LNG continues to advance its mission to deliver cleaner energy responsibly, while supporting the development of national talent and contributing to Oman’s transition towards a knowledge-based and sustainable economy.
https://www.muscatdaily.com/2025/11/01/oman-lng-renews-long-term-agreement-with-baker-hughes/
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Mozambique yet to decide on revised budget for TotalEnergies-led LNG project
Mozambique’s cabinet has yet to take a decision on the revised budget and schedule for the USD 20 billion liquefied natural gas (LNG) project led by TotalEnergies. The project, suspended since 2021 following militant attacks in Cabo Delgado province, has seen its estimated cost rise by about USD 4.5 billion. TotalEnergies and its consortium partners have requested a 10-year extension of the development and production period to offset delays. Government officials said the LNG sector remains a national priority, but no date has been set for formal approval.
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Mozambique’s government is still reviewing the revised budget and timeline for the large-scale liquefied natural gas (LNG) project being developed by TotalEnergies and its consortium partners. A spokesperson confirmed after the recent cabinet meeting that the government has not yet taken a position on the updated proposal and will issue its view once the assessment is complete.
TotalEnergies, the French energy company leading the project, informed Mozambique’s president that costs have risen by around USD 4.5 billion over the four years the project has been suspended. The LNG development was originally estimated at about USD 20 billion, making it one of the largest energy investments in sub-Saharan Africa.
The project was halted in 2021 after an Islamist militant attack in Cabo Delgado province forced the company to declare force majeure and withdraw staff from the site. Although security in the region has improved since then, the long suspension has resulted in cost escalations and logistical setbacks.
To recover from the delays, TotalEnergies and its partners are seeking an extension of the development and production period by 10 years. The request forms part of the revised budget plan now under cabinet review. According to reports, if the government approves the updated terms, the consortium will resume full construction at the Afungi LNG site, where partial works have already been completed.
The government spokesperson said that restarting major gas projects is a priority for Mozambique’s economic growth and energy ambitions, but no specific date has been shared for when the cabinet will make a final decision. The review process will weigh cost implications, project feasibility, and the country’s security and infrastructure readiness before approval is granted.
TotalEnergies has continued to engage with both the government and local stakeholders to ensure that community resettlement and security measures are in place before resuming full operations. The project is expected to significantly boost Mozambique’s LNG export capacity and generate revenue once completed.
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Argentina: YPF, Eni sign agreement with ADNOC’s XRG to develop Argentina LNG project
BUENOS AIRES, Nov 4 (Reuters) – Argentina’s YPF (YPFDm.BA), and Italy’s Eni (ENI.MI), have reached an agreement with the Abu Dhabi National Oil Company’s XRG investment arm for it to join a liquefied natural gas project linked to Argentina’s Vaca Muerta field, YPF said on Tuesday.
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In a statement released during the Abu Dhabi International Petroleum Exhibition and Conference, YPF CEO Horacio Marin said XRG’s incorporation “strengthens a key initiative for the energy future of the country,” and will allow Argentina to turn into a “world-class” exporter of LNG.
The project is seeking financing of at least $12.5 billion, a person close to YPF told Reuters. The companies are expected to sign a technical agreement within a month, that person added.
Eni and Argentine state-controlled oil company YPF signed a final engineering agreement in October to export gas from the Vaca Muerta formation, the world’s second-largest unconventional natural gas reserve.
YPF is leading the project, which involves installing floating liquefaction units at a port in the Patagonian province of Rio Negro. Gas will arrive from Vaca Muerta, in the province of Neuquen, via a pipeline.
Argentina, which is seeking to increase its foreign exchange reserves, could earn at least $10 billion annually if it exports 12 million tons of LNG a year, YPF said on Tuesday afternoon. Exports of LNG are expected to start by mid-2030.
As part of the project, YPF expects to export 50 million cubic meters of natural gas per day, 100,000 barrels of oil and 150,000 barrels of liquefied petroleum gas.
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Adnoc signs 15-year LNG supply deal with Shell for up to 1 million tonnes a year
Abu Dhabi’s Adnoc has signed a long-term sales and purchase agreement with a unit of British energy major Shell for its Ruwais liquefied natural gas project. The 15-year deal signed during the Adipec conference in Abu Dhabi on Tuesday, will be the Abu Dhabi oil company’s first long-term agreement with Shell, for the delivery of up to one million tonnes per annum (mtpa) of LNG, Adnoc said in a statement.
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The LNG will be primarily sourced from the Ruwais LNG project, currently under development in Al Ruwais Industrial City and the first LNG export facility in the Middle East and Africa region to operate on clean power.
Shell holds a 10 per cent stake in the project through its subsidiary, Shell Overseas Holdings.
Following the agreement, more than 8 mtpa of the Ruwais project’s planned 9.6 mtpa capacity has been secured through long-term deals with customers across Asia and Europe, just 16 months after the project’s final investment decision in July 2024, the company said.
This also sets a “new benchmark” for large-scale LNG projects globally, said Fatema Al Nuaimi, chief executive of Adnoc Gas.
“While the industry can take up to four or five years to market such volumes, Ruwais is advancing at record pace,” she said.
“This agreement with Shell marks a significant milestone that reinforces Adnoc’s position as a reliable global supplier of lower-carbon LNG.”
The agreement also marks Adnoc’s eighth long-term offtake deal for the Ruwais LNG project. The first sales and purchase agreement was announced at last year’s Adipec.
The latest SPA converts a previous heads of agreement into a definitive agreement, marking a “significant step” in Adnoc’s efforts to rapidly commercialise the Ruwais LNG project.
“In parallel, construction, contractor mobilisation and site works are all on track for commissioning by the end of 2028,” Ms Al Nuaimi said.
The Ruwais LNG plant, intended to be one of the lowest-carbon intensity LNG projects in the world, will leverage artificial intelligence and the latest technology to enhance safety, operational efficiency and emissions performance.
With two 4.8 mtpa liquefaction trains, the facility will more than double the LNG production capacity of Adnoc Gas to approximately 15 mtpa, supporting its LNG expansion strategy to meet rising global demand.
London-based Shell, which has been Adnoc’s partner for more than 50 years, “shares a vision of strengthening global energy security through strategic collaboration”, said Tom Summers, executive vice president of Shell LNG Marketing and Trading.
“This agreement is a significant milestone in our partnership with Adnoc and supports Shell’s strategy of expanding our LNG portfolio,” he said.
Adnoc Gas is a key player in parent company Adnoc’s strategy to enhance its natural gas production capacity and expand global LNG exports. It supplies about 60 per cent of the UAE’s gas sales needs and supplies end-customers in more than 20 countries.
The company, which has access to 95 per cent of the UAE’s natural gas reserves, is looking to boost exports of products such as LNG, liquefied petroleum gas and naphtha.
https://www.thenationalnews.com/business/energy/2025/11/04/adnoc-gas-shell-ruwais-lng/
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Malaysia: Petronas inks 20-year agreement for transportation and liquefaction of natural gas in Canada
KUALA LUMPUR (Nov 5): Petroliam Nasional Bhd (Petronas) said it has signed a 20-year agreement with Canada’s Pembina Pipeline Corp to transport and liquefy the national oil company’s natural gas in Canada. The agreement, signed through their subsidiaries, gives Petronas additional export capacity for its Canadian gas reserves, utilising the one million tonnes per annum of liquefaction capacity at the Cedar LNG project, said Petronas in a statement on Wednesday. The value of the agreement, however, was not disclosed.
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Cedar LNG, a partnership between the Haisla Nation and Pembina Pipeline, is a proposed floating liquefied natural gas (LNG) facility in Kitimat, British Columbia that will export natural gas to global markets.
The project, estimated to cost US$4 billion (RM16.79 billion), remains on schedule and within budget, with commercial operations expected to begin in late 2028, according to Petronas.
It is worth noting that in July 2017, Petronas and its partners decided not to proceed with the Pacific NorthWest LNG project at Port Edward, British Columbia, citing market conditions at the time.
Petronas said the partnership with Pembina underscores its long-standing commitment to its investment in Canada and demonstrates its dedication to “responsibly monetise” its gas resources.
“This milestone reflects Petronas’ long-standing commitment to our investment in Canada and our continued effort to fortify our global LNG supply portfolio,” said Shamsairi M Ibrahim, vice-president of LNG marketing and trading of Petronas Gas and Maritime Business.
“This arrangement improves supply diversity and enhances reliability of supply for customers, while reinforcing our steadfast commitment to deliver reliable, lower-carbon energy solutions to meet Asia’s growing energy needs,” he added.
Pembina, which is listed on both the Toronto and New York stock exchanges, had earlier secured a 20-year take-or-pay tolling service agreement for 1.5 million tonnes per annum, to support the project’s final investment decision in June 2024.
Pembina’s senior vice-president and corporate development officer Stu Taylor said the deal extends the company’s existing relationship with Petronas and validates the long-term potential of Canadian West Coast LNG exports.
“This agreement further validates Cedar LNG and highlights the strong demand for global export capacity given the clear advantages of Canadian West Coast LNG, including competitively priced feedstock and advantaged shipping distances to Asian markets,” Taylor said.
Petronas’ latest move adds to its growing presence in Canada, where it holds an estimated 50 trillion cubic feet of gas reserves. The state-owned energy company operates the North Montney Joint Venture upstream project and is a major equity partner in the US$40 billion LNG Canada project in Kitimat, which shipped its first cargo in July.
It owns a 25% stake in LNG Canada alongside Shell plc (40%), PetroChina Co Ltd (15%), Mitsubishi Corp (15%) and Korea Gas Corp (5%). When fully operational, the facility will have the capacity to export up to 14 million tonnes of LNG annually.
Petronas has previously indicated the company’s intention to pursue multiple LNG developments in Canada.
https://theedgemalaysia.com/node/777704
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IRH, Delfin LNG, and Vitol sign 20-year LNG SPA
International Resources Holding RSC Ltd (IRH), a leading mine-to-market platform and subsidiary of ePointZero, has signed a 20-year heads of agreement (HoA) with Delfin LNG LLC and Vitol Inc. for the purchase and sale of 1 million tpy of LNG from Delfin’s export facility in the US.
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Under the agreement, Delfin LNG, a leading US-based export infrastructure company, will supply LNG on a free-on-board (FOB) basis to Vitol, one of the world’s largest independent energy traders, which will act as the offtaker and deliver the volumes to IRH Global Trading (IRHGT), IRH’s global trading arm, for a period of 20 years. Definitive agreements are expected to be concluded in the coming weeks.
This long-term partnership represents a major step in IRH’s energy expansion strategy under ePointZero, a diversified investment platform focused on sustainable energy, technology, and resources. By leveraging synergies across the ePointZero ecosystem, IRH aims to build a fully integrated energy and commodities platform that enhances the resilience of supply chains and supports the global energy transition.
Ali Rashed AlRashdi, CEO of IRH, said: “This transaction is a major milestone in the development of IRHGT’s global LNG portfolio. We are pleased to collaborate with Delfin and Vitol to help bring the project to final investment decision soon. As part of our vision to build an integrated global trading platform headquartered in Abu Dhabi, IRHGT is actively expanding its presence across physical and financial markets in natural gas, power, crude oil, refined products, metals, and equities. This agreement sets us on the path to be a reliable supplier of LNG to our valued clients worldwide.”
Mohamed Hesham, CEO of ePointZero, commented: “This agreement represents another step forward in building an integrated, future-ready energy platform. By securing reliable resources through long-term partnerships, we secure the downstream operations of ePointZero Group and ensure energy resilience for our ecosystem. This collaboration reinforces our commitment to delivering diversified, efficient, and reliable energy solutions that power economies and communities across regions.”
Dudley Poston, CEO of Delfin, added: “It’s an honour to have been selected by IRHGT and Vitol as a long-term LNG supplier, and we look forward to working together as we make Final Investment Decision on the first FLNG vessel in the coming weeks. We are pleased to continue our very strong relationship with Vitol and add another world-class trading organisation such as IRHGT to our growing list of strategic partners.”
Pablo Galante Escobar, Global Head of LNG and European Gas & Power at Vitol, highlighted: “We are excited to conclude this agreement with IRHGT and Delfin. Vitol continues to strengthen its position to safely and reliably deliver cost effective, flexible LNG solutions to our customers around the world and we look forward to continuing to expand on our relationship with both IRHGT and Delfin. Vitol’s offtake commitments and investment grade rating will help Delfin on its path to financial close.”
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LNG as a Marine Fuel/Shipping
Bangladesh: 9 LNG cargos received in Oct to meet growing energy demand
DHAKA, Nov 6, 2025 (BSS) – The government has received nine cargos of Liquefied Natural Gas (LNG) having around 2.88 crore MMBTu in October to meet the growing energy demand in the country, an official said today. “We are importing LNG regularly under long-term, short-term agreements as well as from spot markets to meet the increasing energy demand,” General Manager (LNG) of Rupantarita Prakritik Gas Company Limited (RPGCL) Engineer Md Shah Alam told BSS.
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He said the government received 10 cargos of LNG having 3.20 crore MMBTu in September and 11 cargos with around 3.65 crore MMBTu in August to ensure the country’s energy security.
On average, each cargo contained around 32 lakh MMBTu of LNG, Alam added.
Of the cargos received in October, QatarEnergy supplied two cargos, each containing about 32 lakh MMBTu, while Oman’s OQ Trading (OQT) provided two cargos under long-term arrangements and another one under a short-term deal.
In addition, the government procured four cargos of LNG from the spot market to maintain uninterrupted energy supply, Director of Petrobangla AKM Mizanur Rahman told BSS.
According to the Purchase Committee, the Cabinet Committee on Government Purchase (CCGP) earlier approved separate proposals for importing LNG to meet the country’s gas demand.
The purchase committee usually approves procurement of LNG to meet gas demand through its regular weekly meeting.
https://www.bssnews.net/news/329189
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Daphne, Maran Gas complete plasma-catalytic methane abatement trial on LNG carrier
The pilot project involved installing Daphne’s SlipPure onto the vessel’s exhaust to evaluate its effectiveness in reducing methane emissions during real-world operations. Daphne Technology and Angelicoussis Group’s business unit Maran Gas have completed a pilot project to test plasma-catalytic methane abatement technology on board the Maran Gas Chios liquefied natural gas (LNG) carrier.
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According to Daphne, this is the first time the SlipPure Plasma-Catalytic Methane Slip Aftertreatment system has been deployed in commercial maritime operations.
The initiative is said to address the challenge of methane slip, which refers to unburned methane emitted from dual fuel marine engines and remains an operational issue for LNG fuelled vessels.
The pilot involved retrofitting Daphne’s SlipPure system to the vessel’s exhaust to assess its ability to mitigate methane emissions under actual operating conditions.
During the trial, Daphne recorded reductions in methane slip of up to 4 ± 2 g/kWh.
The company stated that these results mark an initial step in validating the technology at sea and offer valuable insights to guide the next phase of development.
Daphne Switzerland managing director Ivan Raleff said: “This was the first time SilpPure Plasma-Catalytic system has been deployed on a ship. It represented a bold step into uncharted territory, and the opportunity to conduct the trial has given us invaluable insights into how methane abatement systems behave in real-life maritime environments.”
Both companies emphasised that the data generated from this pilot will inform future technological improvements and support efforts to reduce methane emissions across the shipping sector.
Maran Gas facilitated installation and operation of this first-of-a-kind technology on a vessel in active service, demonstrating willingness to support early-stage maritime decarbonisation technologies.
Maran Gas Maritime technical director Andreas Spertos said: “Methane slip reduction is an inherent challenge for engines running on gas. When combined with the adversities of the marine environment, the challenge becomes exponentially more difficult.
“The successful demonstration onboard Maran Gas Chios is a landmark methane abatement technology trial.”
Daphne continues to develop its methane abatement platform, alongside its PureMetrics emissions monitoring system, with plans to extend applications across both maritime and land-based settings.
In 2022, South Korean shipbuilder Daewoo Shipbuilding & Marine Engineering (DSME) received an order from Maran Gas to construct two additional LNG carriers.
https://www.ship-technology.com/news/daphne-maran-abatement-trial-lng-carrier/
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Marinakis’ Capital Gas to partner with CMA CGM, TotalEnergies on LNG bunker vessel newbuilds
Evangelos Marinakis-led Capital Gas is forming an LNG bunker vessel joint venture with French liner giant CMA CGM and energy major TotalEnergies, following the growing momentum within the segment. Shipbroking sources noted the three partners are looking to place an order for LNG bunker vessels in China, though details on the number of ships and the chosen shipyard have yet to emerge.
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The formation of joint ventures in the LNG bunker vessel market has become increasingly common in recent months, as established shipping players seek collaborations to support market growth. Despite ongoing debates over the alternative fuel of the future, LNG remains central to the energy transition, with Greek stakeholders already urging regulatory bodies to further highlight its importance.
All three companies are firm supporters of the LNG market. Capital Gas is a shipmanagement service provider, currently operating a fleet of 18 modern LNG carriers, including vessels under construction, according to its website.
CMA CGM has placed multiple orders for LNG-powered vessels and recently entered a 50-50 joint venture with TotalEnergies to develop and operate an LNG bunkering platform at the Port of Rotterdam.
The planned joint venture aims to deploy, by the end of 2028, a 20,000-m³ LNG bunker vessel to supply fuel to CMA CGM ships and other carriers operating in the area.
Notably, TotalEnergies has also been tied to charters for two 18,600-m³ vessels that Spanish shipowner Ibaizabal has ordered at Hudong-Zhonghua Shipbuilding in China.
Growing momentum in LNG bunkering
The LNG bunker vessel sector has seen heightened interest in newbuilding investments over the past few months.
Among recent deals, Chinese shipbuilder Nantong CIMC Sinopacific Offshore & Engineering secured contracts for up to six vessels – four for GSX Energy and two for Purus.
Celsius Tankers and The Caravel Group also established a joint venture, placing a two-vessel order at China Merchants Industry Holdings and China Merchants Heavy Industry Jiangsu.
Other players reportedly contracting vessels this year include Ibaizabal, H-Line, Evalend Shipping, Somtrans, Shanghai International Port Group, and China Bunker.
Analysts attribute this surge to anticipated growth in the LNG dual-fuel fleet. Observers note that over 1,150 LNG dual-fuel vessels are expected to be in operation by 2028, with LNG bunkering demand projected to surpass 50M tonnes annually by 2045. This underscores the urgent need for modern, compliant bunkering infrastructure.
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Technological Development for Cleaner and Greener Environment Hydrogen & Bio-Methane
Canada: Ontario doubles Hydrogen Innovation Fund to $30 million
The Ontario government is investing $30 million to launch a new round of the Hydrogen Innovation Fund, supporting projects aimed at unlocking hydrogen’s potential to drive economic growth, create good-paying jobs and strengthen the province’s position as a world leader in the clean energy economy.
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This investment doubles the funding from the previous round and expands eligibility criteria under Energy for Generations, Ontario’s long-term energy roadmap designed to build a resilient, secure and self-reliant energy sector capable of powering the most competitive economy in the G7.
“By expanding the Hydrogen Innovation Fund, our government is making a strategic investment as part of our plan to protect Ontario’s economy and energy independence,” said Sam Oosterhoff, Associate Minister of Energy-Intensive Industries. “Hydrogen technologies are already unlocking new opportunities for private sector investment and creating good-paying jobs, all while enhancing our competitive edge and making Ontario a world leader in the hydrogen sector as we build a more competitive, resilient economy.”
The expanded fund includes two streams: one for projects integrating low-carbon hydrogen into Ontario’s electricity grid, and another supporting broader sector applications of hydrogen across transportation, manufacturing and heavy industry. The fund will also help create hydrogen hubs, connect producers with end-users, and encourage the use of made-in-Ontario hydrogen.
The updated criteria will promote projects developed by Canadian companies to help strengthen Ontario’s economy and energy security. The expanded fund responds to industry feedback for increased government support and reaffirms Ontario’s commitment to advancing a low-carbon hydrogen economy.
“Hydrogen has potential as both a clean energy resource and a major economic play that can create tens of thousands of jobs,” said Stephen Lecce, Minister of Energy and Mines. “Our government’s focus is on delivering affordable energy to families, along with creating good-paying jobs as we build-up Ontario’s low-carbon future.”
Hydrogen technologies are seen as uniquely suited to fill gaps in the energy system that are difficult or costly to address through electrification alone. The province said hydrogen can help manage peak electricity demand, provide long-duration energy storage and reduce emissions in sectors such as steel, cement and refining.
“Ontario’s Hydrogen Hub in Sarnia-Lambton applauds the leadership of the Ontario government – and especially Minister Oosterhoff – as the build out of the low-carbon hydrogen economy and establishment of defined hydrogen hubs stand to benefit significantly from the support of the Hydrogen Innovation Fund,” said Matthew Slotwinski, CEO of the Sarnia-Lambton Economic Partnership. “The development of the at-scale low-carbon hydrogen economy starts with leveraging innovation to connect hydrogen producers and users, setting the stage for long-term economic growth, job creation, clean energy integration, and low-carbon diversification.”
According to a 2023 study commissioned by Natural Resources Canada, a robust hydrogen economy could create up to 70,000 jobs across Canada by 2050, including in Ontario, in areas such as production, infrastructure, storage and clean technology development, while helping to reduce greenhouse gas emissions.
Supporting hydrogen innovation helps deliver on the goals of Energy for Generations, Ontario’s first integrated energy plan, which identifies hydrogen as a strategic resource that complements other fuels and technologies to meet growing demand and support industry, heavy transportation and reliable energy generation.
https://sydenhamcurrent.ca/2025/11/02/ontario-doubles-hydrogen-innovation-fund-to-30-million/
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Siemens and RIC Energy join forces to accelerate renewable hydrogen in Spain
RIC Energy and Siemens have signed a strategic agreement to develop industrial projects in renewable hydrogen, sustainable aviation fuel, and green ammonia, focusing on two key sites in Spain.
Siemens Group and RIC Energy have signed a memorandum of understanding to jointly develop projects related to renewable hydrogen, green ammonia, and synthetic fuels in Spain. The agreement is part of the Compostilla Green project, located in Cubillos del Sil, which was ranked as the top initiative under the Hydrogen Valleys programme.
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A cross-sector partnership structured around technology and financing
The agreement involves several Siemens Group entities, including Siemens S.A., Siemens Industry Software, Siemens Financial Services, and Siemens Innovation Strategies. The partnership covers both technical and financial aspects, with a particular focus on developing joint solutions and exploring structured financing mechanisms for the projects.
The two companies aim to improve operational efficiency, industrial decarbonisation, site safety, and the advanced digitalisation of infrastructure. These priorities form part of a long-term industrial deployment strategy supported by digital technologies and integrated financial approaches.
Large-scale projects across two Spanish industrial regions
In addition to Compostilla Green, the agreement also includes the Besaya project, located in Torrelavega in the Cantabria region. This second site is aligned with the development of sustainable industrial fuels and aims to mobilise new technological and logistical capacities in the region.
Both partners plan to implement a joint communication strategy to highlight the economic impact of these projects on the regions involved. They are also considering the establishment of vertically integrated consortiums to facilitate execution of the planned initiatives.
Strengthening industrial cooperation in alternative fuels
The leaders of both companies welcomed the formalisation of this alliance. José Luis Moya, Chief Executive Officer of RIC Energy, described the agreement as an opportunity to “accelerate the deployment of transformative projects in the field of hydrogen and its derivatives”.
Fernando Silva, Chief Executive Officer of Siemens Spain, stated that the partnership confirmed the group’s commitment to “supporting large-scale industrial initiatives in Spain within the sustainable fuels sector”. Discussions are ongoing to define the next steps in operational development and institutional structuring.
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Siemens and RIC Energy join forces to accelerate renewable hydrogen in Spain
RIC Energy and Siemens have signed a strategic agreement to develop industrial projects in renewable hydrogen, sustainable aviation fuel, and green ammonia, focusing on two key sites in Spain. Siemens Group and RIC Energy have signed a memorandum of understanding to jointly develop projects related to renewable hydrogen, green ammonia, and synthetic fuels in Spain. The agreement is part of the Compostilla Green project, located in Cubillos del Sil, which was ranked as the top initiative under the Hydrogen Valleys programme.
SHOW MORE
A cross-sector partnership structured around technology and financing
The agreement involves several Siemens Group entities, including Siemens S.A., Siemens Industry Software, Siemens Financial Services, and Siemens Innovation Strategies. The partnership covers both technical and financial aspects, with a particular focus on developing joint solutions and exploring structured financing mechanisms for the projects.
The two companies aim to improve operational efficiency, industrial decarbonisation, site safety, and the advanced digitalisation of infrastructure. These priorities form part of a long-term industrial deployment strategy supported by digital technologies and integrated financial approaches.
Large-scale projects across two Spanish industrial regions
In addition to Compostilla Green, the agreement also includes the Besaya project, located in Torrelavega in the Cantabria region. This second site is aligned with the development of sustainable industrial fuels and aims to mobilise new technological and logistical capacities in the region.
Both partners plan to implement a joint communication strategy to highlight the economic impact of these projects on the regions involved. They are also considering the establishment of vertically integrated consortiums to facilitate execution of the planned initiatives.
Strengthening industrial cooperation in alternative fuels
The leaders of both companies welcomed the formalisation of this alliance. José Luis Moya, Chief Executive Officer of RIC Energy, described the agreement as an opportunity to “accelerate the deployment of transformative projects in the field of hydrogen and its derivatives”.
Fernando Silva, Chief Executive Officer of Siemens Spain, stated that the partnership confirmed the group’s commitment to “supporting large-scale industrial initiatives in Spain within the sustainable fuels sector”. Discussions are ongoing to define the next steps in operational development and institutional structuring.
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World’s first hydrogen solar farm to open in Namur in 2026
The world’s first hydrogen solar park is set to open near Namur next year. As well as generating electricity from solar panels, the site will produce hydrogen using so-called hydrogen panels. On Wednesday, four companies formalised their cooperation on the project.
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The technology that allows hydrogen to be produced from nothing more than sunlight and moisture in the air was developed at KU Leuven more than a decade ago. The Leuven start-up Solhyd, founded by researchers involved in that work, has since transformed the concept into a working hydrogen panel.
Each panel contains cylinders with materials that extract water vapour from the air and split it into hydrogen and oxygen using a membrane. The hydrogen is collected, while the oxygen is released back into the atmosphere. The process is entirely free from fossil fuels and requires no rare materials or conventional electrolysers, making it a fully “green” technology.
World first in Namur
The hydrogen solar park near Namur marks the first commercial-scale deployment of the technology. It will initially have a capacity of 50 kilowatts, with plans to expand to 2 megawatts in the coming years. Commissioning is expected in 2026.
Under the partnership, Solhyd will supply and maintain the hydrogen panels, while Nippon Gases will capture and store the hydrogen. Ether Energy will act as project owner and operator, and SunBuild will install the solar panels and battery systems. The cooperation agreement was signed on Wednesday at TRANSfarm in Bierbeek, where Solhyd is based.
“If we want to reach our climate goals, greening hydrogen production is essential”
The hydrogen produced will be marketed primarily to industrial clients, such as those in the steel, aviation and shipping sectors. “These are the most logical applications,” explained Jan Rongé, co-founder and CEO of Solhyd. “For households, hydrogen is too complex. Heating and transport can be made more sustainable through electrification.”
Currently, around 2 per cent of global CO2 emissions come from hydrogen production, which typically relies on fossil fuels. “That may not sound like much, but it’s equivalent to the emissions of the entire aviation sector,” Rongé said. “If we want to reach our climate goals, greening hydrogen production is essential.”
https://www.belganewsagency.eu/worlds-first-hydrogen-solar-farm-to-open-in-namur-in-2026
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Masdar buys stake in Austria’s largest green hydrogen project
UAE energy firm Masdar is raising its profile in Europe after buying a 49% stake in Austria’s largest green hydrogen project, according to agency reports. Austrian integrated energy and petrochemicals company OMV is building a 140MW electrolyser which is expected to produce up to 23,000 tonnes of green hydrogen annually, once it opens at the end of 2027, if all goes to plan. The hydrogen will be used to decarbonise the nearby OMV Schwechat refinery by replacing hydrogen currently derived from natural gas.
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The investment shows how global partnerships are trying to deliver green hydrogen. Masdar, which has been working on green hydrogen since 2008, aims to be a leading producer by 2030.
Austria, targeting climate neutrality by 2040, is striving to install 1GW of electrolysis capacity by 2030 and to replace 80% of grey (fossil-based) hydrogen in industry by the same year.
The strategy also involves a mandatory green gas quota for suppliers, reaching 9.75% (or 7.5 TWh) by 2030. These targets are supported by the Hydrogen Strategy for Austria and initiatives like the country’s Renewable Gases Act, along with funding of up to €400m.
Last month Masdar signed a memorandum of understanding with Etihad Rail, the developer and operator of the UAE’s national railway network, to explore transport solutions for the green hydrogen value chain.
The companies will assess opportunities to transport feedstocks and products along the green hydrogen and derivatives value chain, including hydrogen, ammonia, methanol and sustainable aviation fuel.
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Bosch starts up 2.5 MW hydrogen electrolyzer in Germany
German industrial group Bosch says the Bamberg facility complies with European Union renewable hydrogen rules and will produce over one ton of green hydrogen daily. German manufacturer Bosch has commissioned its first self-operated hydrogen electrolyzer, comprising two proton exchange membrane (PEM) electrolysis stacks with a combined capacity of 2.5 MW, at its Bamberg site in southern Germany.
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Bosch said the new in-house system produces renewable hydrogen in line with European Union requirements, which mandate simultaneous generation of renewable electricity and proximity between energy source and electrolyzer within the same price zone.
https://hydrogeneurope.eu/bosch-starts-up-2-5-mw-hydrogen-electrolyzer-in-germany/
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