NGS’ NG/LNG SNAPSHOT September 1-15, 2026
National News Internatonal News
NATIONAL NEWS
City Gas Distribution & Auto LPG
CNG vehicles won’t get fuel if they don’t have hydro-test certificate: IGL
New Delhi: Owners of CNG-run vehicles will be denied fuel if they don’t have a valid hydro-test certificate, Indraprastha Gas Limited (IGL) said on Wednesday. IGL said it is conducting a special safety drive across all its CNG stations, with staff at fuel pumps verifying the validity of hydro-test certificates before dispensing fuel to ensure compliance with safety requirements.
SHOW MORE
“CNG will not be dispensed if a valid hydro-test certificate is not available in the vehicle. Customers are requested to get their CNG cylinders tested on time and always carry the valid certificate in the vehicle,” the company said in a statement.
The move comes days after the Petroleum and Explosives Safety Organisation (PESO) issued directions in this regard. Under Rule 35(1) of the Gas Cylinder Rules, 2025, every CNG cylinder must undergo a hydrotest once every three years at a PESO-approved cylinder testing centre.
PESO directed stringent safety enforcement at CNG stations across Delhi-NCR following a recent cylinder blast that killed three people and injured two at a retail outlet in the capital last month. The advisory is aimed at preventing untoward incidents by tightening on-ground checks.
PESO has also instructed all city gas distribution companies to prominently display safety signage at CNG outlets and ensure that fuel is dispensed only to cylinders that meet approved standards and have a valid hydro-test certificate.
show less
Indian Army To Transition 41 Stations To Piped Natural Gas
The Indian Army (IA) organised the PNG Transition Webinar-2026 at the Manekshaw Centre, Delhi Cantt, to accelerate transition to Piped Natural Gas (PNG) across feasible Army establishments in line with the Government of India’s vision of a gas-based economy. The event convened ministry and regulatory representatives alongside technical and distribution partners to map a practical adoption timetable. Organisers set out objectives to ensure safety, regulatory compliance and structured implementation.
SHOW MORE
Key stakeholders included the Petroleum and Natural Gas Regulatory Board (PNGRB), the Defence Estates Organisation (DEO), Military Engineer Services (MES) and City Gas Distribution (CGD) entities, which participated in detailed sessions on logistics and coordination. As part of the initiative the IA plans to convert 41 Army Stations to PNG during FY 2026–27, with subsequent expansion to other feasible establishments. The plan and its milestones were described in a press release issued by the Ministry of Defence.
The Indian Army PNG Guide was released at the webinar and serves as a common reference document to facilitate a structured, standardised transition. The guide addresses administrative procedures, technical specifications, safety protocols and implementation requirements to align station-level works with regulatory and policy frameworks. Sessions examined statutory clearances, land and works-related challenges, accounting and reimbursement mechanisms, and practical technical considerations for seamless integration.
Discussions also covered the preparedness of CGD entities and shared station-level implementation experiences to identify replicable approaches and risk mitigations. The IA reaffirmed its commitment to a safe, efficient and sustainable transition to PNG across feasible establishments and outlined a collaborative path with government and distribution partners. The webinar concluded with an emphasis on phased implementation and continuing coordination to monitor progress and address challenges. September 08, 2026
show less
MNGL reaches 9 lakh households in Pune, launches special drive to activate connections by Sept-end
Of 9 lakh households, around 5 lakh home owners have activated their connections but 4 lakh owners are yet to complete the activation process. Maharashtra Natural Gas Limited (MNGL), which provides CNG and piped natural gas (PNG) to customers on Wednesday said the PNG infrastructure has reached to about 9 lakh households in Pune and Pimpri Chinchwad.
SHOW MORE
Of 9 lakh households, around 5 lakh home owners have activated their connections but 4 lakh owners are yet to complete the activation process. MNGL has appealed to all the homeowners who are yet to finish the activation of PNG. Special drive has been taken up till end of Sept to activate the connections, officials from MNGL said.
MNGL has also approached the housing societies to make sure that all PNG connections in all the flats are activated at earliest. Around 6,500 housing societies in Pune and Pimpri Chinchwad are reached with PNG infrastructure. Officials said, “The connections have reached outside every flat.
The role of flat owners is now crucial to activate the connection. We have put the boards outside the housing societies appealing the flat owners to come forward to finish the process. It is important to complete the process before Oct 1,” officials said.
MNGL said that PNG connections are expanding aggressively across Pune and Pimpri Chinchwad though there are some problems in increasing penetration in the city’s core peth areas. The daily activation of new PNG connections has increased significantly in the last six months post Iran-US war.
At least 400 new connections are getting ready on a daily basis. MNGL in last eight months (Jan to Aug) has readied infrastructure for over 95,000 PNG connections in Pune and Pimpri Chinchwad.
49 CNG refilling stations in pipeline
To provide CNG outlet for vehicles, MNGL is looking ahead to commence 49 new refilling stations in next few months. In addition to these, the talks are underway to operationalise more refilling units at the petrol pumps. Around 133 refilling points are operational in the city at present, 100 more points are expected to be added soon.
Expect improvement in CNG supply in next two weeks
MNGL officials said the supply at existing CNG stations is expected to be improved in next two weeks. A plan to increase the capacity of a unit at Talegaon is in the last stages. By mid-Sept, all existing stations are expected to receive the CNG supply at more pressure. This will help reduce long queues of autos and cars at refilling points.
show less
Indian Army, City Gas Distribution industry join hands to accelerate transition to PNG
New Delhi: The Indian Army PNG Transition Webinar 2026 was organised at Manekshaw Centre, New Delhi, on Thursday under the theme “Sena Sampark – Nirantar Urja, Nirantar Suraksha” to accelerate adoption of cleaner and reliable energy solutions across Army establishments. Organised by Bharat Petroleum Corporation Ltd (BPCL) in association with the Indian Army and Petroleum and Natural Gas Regulatory Board (PNGRB), the programme brought together the City Gas Distribution (CGD) industry to create a coordinated roadmap for PNG adoption.
SHOW MORE
In the first phase, 41 Army establishments have been identified for PNG conversion. Letters of Understanding were signed between 8 Army Stations and 6 CGD entities, covering more than 20,000 households. The entities include BPCL, IGL, Think Gas, Torrent Gas, HPCL and CUGL.
Rahul Tandon, Business Head – Gas, BPCL, said the transition would help build a reliable, continuous and future-ready energy ecosystem. PNG infrastructure and connections are targeted for completion by end-FY27.
show less
Paras Dairy, KIS Group to set up 10 BioCNG plants with ₹1,000 cr investment
Bengaluru-based KIS Group and Paras Dairy will form a joint venture to set up 10 BioCNG plants with an investment of Rs 1,000 crore. According to a joint statement, KIS Group and Paras Dairy have signed a Memorandum of Understanding (MoU) to set up 10 BioCNG (CBG) plants across Uttar Pradesh, Madhya Pradesh, Maharashtra and other states, with an estimated investment of Rs 1,000 crore.
SHOW MORE
They will form a joint venture (JV) for the proposed BioCNG plants.
Under the partnership, KIS Group will be responsible for technology, construction and operation of the plants, while Paras Dairy will be responsible for feedstock arrangement, land and approvals.
The MoU was signed at the IBET Expo here.
Founded in 2006, KIS Group is a clean technology player specialising in Biogas, BioCNG, and BioLNG solutions. Paras Dairy has plants in Sahibabad, Guloathi and Sandila in Uttar Pradesh, Malanpur in Madhya Pradesh and Newasa in Maharashtra.
(Only the headline and picture of this report may have been reworked by the Business Standard staff; the rest of the content is auto-generated from a syndicated feed.)
show less
Natural Gas/ Pipelines/ Company News
Dilip Buildcon surges after securing Rs 1,800 crore contract from PNGRB
Dilip Buildcon (DBL) jumped 5.54% to Rs 414.20 after the company said that it has received a letter of intent from the Petroleum and Natural Gas Regulatory Board (PNGRB) for the development of the Paradip, Odisha-Raipur, Chhattisgarh LPG pipeline. The total value of this contract is Rs 1,800 crore.
SHOW MORE
The project will be implemented through a 100%-owned special purpose vehicle (SPV), with DBL undertaking the design, financing, development, construction, operation and maintenance of the pipeline.
The construction is scheduled over 36 months, followed by a 25-year operating period.
The pipeline will operate as a common carrier, with DBL earning transportation revenue through the applicable PNGRB tariff framework, while remaining outside LPG procurement, trading, distribution and marketing.
Dilip Buildcon (DBL) is a diversified infrastructure company with over three decades of execution experience in large-scale infrastructure development projects across India. The company has a presence in 20 states and one Union Territory, supported by a workforce of 20,581 employees and a fleet of more than 10,275 equipment units.
The company’s consolidated net profit declined 50.67% to Rs 112.95 crore on a 9.26% fall in revenue to Rs 2,377.78 crore in Q1 FY27 as compared with Q1 FY26.
show less
IGL Signs MoU with ITBP to Provide DPNG Connections to 154 Staff Quarters in Kanpur
New Delhi: Indraprastha Gas Limited (IGL) has signed a Memorandum of Understanding (MoU) with the 32nd Battalion of the Irndo-Tibetan Border Police (ITBP), Maharajpur, Kanpur, to provide Domestic Piped Natural Gas (DPNG) connections to 154 staff quarters of the battalion. The initiative strengthens IGL’s association with India’s paramilitary forces while supporting the company’s ongoing expansion of PNG infrastructure across its Kanpur Geographical Area.
SHOW MORE
IGL to Provide DPNG Connections to 154 Quarters
Under the MoU, IGL will provide Domestic Piped Natural Gas (DPNG) connections to 154 staff quarters of the 32nd Battalion, ITBP, at Maharajpur in Kanpur.
The initiative is aimed at providing reliable and convenient gas infrastructure for the personnel and families residing in the staff quarters.
Key Highlights
Partner: 32nd Battalion, ITBP, Maharajpur, Kanpur
DPNG connections: 154 staff quarters
Service: Domestic Piped Natural Gas
Location: Maharajpur, Kanpur
Focus: Reliable and convenient gas infrastructure for paramilitary personnel
Partnership Supports IGL’s PNG Expansion in Kanpur
The MoU is part of IGL’s efforts to expand access to piped natural gas across its Kanpur Geographical Area (GA).
By extending DPNG infrastructure to the ITBP battalion, the initiative will bring piped gas connectivity closer to personnel serving with the paramilitary force.
IGL described the association as a meaningful step towards supporting those who serve the nation and providing them with modern gas infrastructure for everyday needs.
Focus on Reliable and Convenient Gas Infrastructure
The DPNG connections are expected to provide a convenient and reliable household gas supply to the 154 staff quarters.
The partnership also reflects IGL’s engagement with India’s paramilitary forces and its efforts to expand access to PNG infrastructure among institutional and residential consumers.
IGL Strengthens Association with Paramilitary Forces
The MoU represents a collaboration between IGL and the Indo-Tibetan Border Police, with the focus on improving access to modern household gas infrastructure for the battalion’s staff quarters.
IGL said the initiative supports greater everyday convenience for personnel who serve the country while contributing to the expansion of its PNG network in Kanpur.
About Indraprastha Gas Limited
Indraprastha Gas Limited (IGL) is a leading city gas distribution company in India, engaged in supplying compressed natural gas (CNG) and piped natural gas (PNG) to customers. The company operates city gas distribution networks across several geographical areas and focuses on expanding access to cleaner and convenient natural gas solutions.
https://indianmasterminds.com/news/igl-itbp-mou-dpng-connections-154-staff-quarters-kanpur-232260/
show less
Gujarat Gas Hikes Domestic PNG Prices By ₹4.20 To Offset Sourcing Costs
Gujarat Gas has increased its domestic PNG tariff by approximately 8.5% to protect its margins against elevated gas procurement costs. This retail hike is a direct response to a shortfall in cheaper domestic APM gas allocations, necessitating a reliance on higher-priced imported RLNG. The revision occurs shortly after the company’s major corporate reorganization and rebranding.
SHOW MORE
SAHI Markets, Published: 4 Sept 2026, 02:06 PM IST (10 hours ago) | Last Updated: 4 Sept 2026, 02:06 PM IST (10 hours ago) 2 min read
Reviewed by Arpit Seth
Market snapshot: Gujarat Gas (recently rebranded as Gujarat Energy Limited) has announced a revision in its domestic Piped Natural Gas (PNG) prices, raising tariffs by ₹4.19 per Standard Cubic Meter (SCM) (broadly reported as ₹4.20) effective from September 3, 2026. This brings the retail price in Gujarat to ₹53.22 per SCM, inclusive of applicable taxes, compared to the earlier rate of ₹49.03 per SCM.
Data Snapshot
Revised domestic PNG rate including taxes stands at ₹53.22 per SCM, effective September 3, 2026.
The price hike represents a ₹4.19 per SCM increase from the prior base rate of ₹49.03 per SCM.
What’s Changed
Domestic PNG Price (including taxes): Increased from ₹49.03 per SCM to ₹53.22 per SCM, effective September 3, 2026.
Key Takeaways
Retail Margin Buffer: The tariff hike passes on rising input costs to retail consumers, defending the company’s operating EBITDA/scm margin.
APM Allocations Shortfall: Sourcing constraints in domestic Administered Price Mechanism gas require the company to blend costlier imported RLNG.
Unified Structure: This operational change follows the massive consolidation of GSPC, GSPL, and GSPC Energy into Gujarat Gas to form Gujarat Energy Limited.
SAHI Perspective
This price action highlights the persistent challenges city gas distributors face with domestic gas sourcing under the APM framework. By raising domestic PNG tariffs, Gujarat Gas seeks to protect its EBITDA margins from dilution caused by blending expensive imported liquefied natural gas. The hike demonstrates solid pricing power in the residential segment, which is typically less price-sensitive than industrial consumers.
Market Implications
While industrial volume trends in areas like Morbi are highly sensitive to alternative fuels like propane, the residential PNG segment provides stable, higher-margin cash flows. This price revision will help cushion corporate margins against elevated global spot LNG prices. However, excessive price hikes run the risk of slowing new customer connections over the short term.
Trading Signals
Market Bias: Neutral
The price revision protects EBITDA margins for the domestic segment but reflects high underlying sourcing costs. The stock remains balanced due to competitive fuel price dynamics in the industrial segment.
Overweight: Gas Distribution, City Gas Distribution
Trigger Factors:
Volume trends in Morbi industrial segment vs Propane parity pricing
Adoption of domestic connections under the government’s APM gas incentive scheme
Brent crude and global spot LNG pricing trajectory
Time Horizon: Near-term (0-3 months)
Industry Context
The city gas distribution sector is navigating high input costs. To help lower sourcing costs, the central government approved an incentive scheme in August 2026, granting an extra 200 SCM of cheaper APM gas for every new domestic PNG customer. However, structural shortfalls in priority allocations require companies to strategically adjust retail rates to sustain profit margins.
Key Risks to Watch
Alternative Fuel Competition: Lower propane prices in key industrial zones like Morbi could impact industrial PNG volume absorption.
Declining APM Allocations: Continued reduction in domestic gas supply will elevate dependency on volatile spot RLNG.
Regulatory & Public Pushback: Festive season retail price hikes may draw regulatory attention to pricing mechanisms.
Recent Developments
On August 19, 2026, the central government approved a landmark incentive scheme offering an additional 200 SCM of cheaper APM gas for every incremental domestic PNG connection. Separately, effective July 2, 2026, Gujarat Gas demerged its gas transmission business into GSPL Transmission Limited.
Closing Insight
Gujarat Gas’ domestic tariff adjustment is a tactical operational move to shield its balance sheet from domestic sourcing shortfalls. Operating as the newly integrated Gujarat Energy Limited, the company must successfully maintain residential volume growth momentum without triggering client attrition.
show less
ONGC chairman selection: Seven shortlisted candidates to face second round of interviews
New Delhi, Seven candidates shortlisted for the top job at state-run Oil and Natural Gas Corporation (ONGC) are likely to appear before a search-cum-selection committee this week, as the government moves ahead with choosing a successor to Chairman and Managing Director Arun Kumar Singh, people familiar with the selection process said.
SHOW MORE
The second round of interviews comes after 18 applicants were screened on August 18, with the field subsequently narrowed to seven.
The selection process has drawn attention over a one-off relaxation in the age eligibility criterion, allowing candidates up to 59 years of age – a departure from the existing 58-year limit and the recent relaxation to 60 years in the case of state-run power producer NTPC, as well as ONGC, in 2022.
Oil India Ltd Chairman and Managing Director Ranjit Rath, who is seen as a frontrunner, is among those shortlisted. Rath, 54, is making a second attempt at the ONGC top job after being shortlisted last year, when the government opted instead to extend Singh’s tenure.
The other shortlisted candidates include ONGC Videsh Ltd Managing Director Rajarshi Gupta, 59; ONGC Director for Technology and Field Services Vikram Saxena; ONGC Director for Strategy and Corporate Affairs Satyam Kumar; OVL Director for Operations Dulal Halder; MRPL Director (Finance) Devendra Kumar and Indian Oil Corporation Director (Marketing) SP Shrivastava, according to people familiar with the process.
The government earlier relaxed the age criterion for the ONGC appointment, allowing applications from candidates who had not attained 59 years on the date of occurrence of the vacancy – December 7, 2026, when Singh’s extended tenure ends.
Under the existing norms, the upper age limit is generally 58 years for internal candidates and 57 years for external candidates, while the superannuation age for public-sector executives is 60.
Gupta’s shortlisting has raised questions because he will be about 59 years and five months old on December 7, making him ineligible under a literal reading of the 59-year condition in the advertisement. Candidates who chose not to apply because they would cross the age limit by the date of vacancy could challenge the selection process if Gupta is ultimately appointed, the people said.
The advertisement states that “the maximum age of an applicant should be 59 years on the date of vacancy” and that “any employment or extension beyond 60 years would be on a contractual basis”.
The selection will be made by a three-member search-cum-selection committee comprising the chairperson of the Public Enterprises Selection Board (PESB), the oil secretary and a former Indian Oil chairman as an outside expert.
The government also modified the educational qualification criteria through an addendum, specifying that applicants should be first-class graduates with degrees in engineering, chartered accountancy, or cost accountancy, or postgraduates or graduates with a full-time MBA/PGDIM from a leading institute.
Rath has headed Oil India, India’s second-largest state-run oil and gas explorer, since August 2022. He had applied for the top job at ONGC last year also, but the government chose to give Singh another one year at the helm.
The latest selection process follows a series of changes at the top of ONGC. The company was without a full-time chief between April 2021 and December 2022, and was led by three interim chairmen before Singh was appointed.
The government had also relaxed eligibility rules when Singh was selected in 2022. The search committee picked him in August that year, when he was less than four months short of 60. He took charge of ONGC in December 2022 after retiring as chairman and managing director of Bharat Petroleum Corporation Ltd.
Singh was granted a rare one-year extension last year, allowing him to remain at the helm until December 2026. He will be more than 64 years old when his extended tenure ends
The ONGC chairman will be responsible for the overall management and strategic direction of the country’s largest oil and gas producer, including boosting revenue and profitability, driving exploration and production, expanding into new energy and petrochemicals through acquisitions and joint ventures, and overseeing technology adoption.
show less
ONGC chairman selection: Seven shortlisted candidates to face second round of interviews
New Delhi, Seven candidates shortlisted for the top job at state-run Oil and Natural Gas Corporation (ONGC) are likely to appear before a search-cum-selection committee this week, as the government moves ahead with choosing a successor to Chairman and Managing Director Arun Kumar Singh, people familiar with the selection process said. The second round of interviews comes after 18 applicants were screened on August 18, with the field subsequently narrowed to seven.
SHOW MORE
The selection process has drawn attention over a one-off relaxation in the age eligibility criterion, allowing candidates up to 59 years of age – a departure from the existing 58-year limit and the recent relaxation to 60 years in the case of state-run power producer NTPC, as well as ONGC, in 2022.
Oil India Ltd Chairman and Managing Director Ranjit Rath, who is seen as a frontrunner, is among those shortlisted. Rath, 54, is making a second attempt at the ONGC top job after being shortlisted last year, when the government opted instead to extend Singh’s tenure.
The other shortlisted candidates include ONGC Videsh Ltd Managing Director Rajarshi Gupta, 59; ONGC Director for Technology and Field Services Vikram Saxena; ONGC Director for Strategy and Corporate Affairs Satyam Kumar; OVL Director for Operations Dulal Halder; MRPL Director (Finance) Devendra Kumar and Indian Oil Corporation Director (Marketing) SP Shrivastava, according to people familiar with the process.
The government earlier relaxed the age criterion for the ONGC appointment, allowing applications from candidates who had not attained 59 years on the date of occurrence of the vacancy – December 7, 2026, when Singh’s extended tenure ends.
Under the existing norms, the upper age limit is generally 58 years for internal candidates and 57 years for external candidates, while the superannuation age for public-sector executives is 60.
Gupta’s shortlisting has raised questions because he will be about 59 years and five months old on December 7, making him ineligible under a literal reading of the 59-year condition in the advertisement. Candidates who chose not to apply because they would cross the age limit by the date of vacancy could challenge the selection process if Gupta is ultimately appointed, the people said.
The advertisement states that “the maximum age of an applicant should be 59 years on the date of vacancy” and that “any employment or extension beyond 60 years would be on a contractual basis”.
The selection will be made by a three-member search-cum-selection committee comprising the chairperson of the Public Enterprises Selection Board (PESB), the oil secretary and a former Indian Oil chairman as an outside expert.
The government also modified the educational qualification criteria through an addendum, specifying that applicants should be first-class graduates with degrees in engineering, chartered accountancy, or cost accountancy, or postgraduates or graduates with a full-time MBA/PGDIM from a leading institute.
Rath has headed Oil India, India’s second-largest state-run oil and gas explorer, since August 2022. He had applied for the top job at ONGC last year also, but the government chose to give Singh another one year at the helm.
The latest selection process follows a series of changes at the top of ONGC. The company was without a full-time chief between April 2021 and December 2022, and was led by three interim chairmen before Singh was appointed.
The government had also relaxed eligibility rules when Singh was selected in 2022. The search committee picked him in August that year, when he was less than four months short of 60. He took charge of ONGC in December 2022 after retiring as chairman and managing director of Bharat Petroleum Corporation Ltd.
Singh was granted a rare one-year extension last year, allowing him to remain at the helm until December 2026. He will be more than 64 years old when his extended tenure ends
The ONGC chairman will be responsible for the overall management and strategic direction of the country’s largest oil and gas producer, including boosting revenue and profitability, driving exploration and production, expanding into new energy and petrochemicals through acquisitions and joint ventures, and overseeing technology adoption.
show less
GAIL, Petronet LNG join hands with IIT Hyderabad to drive digital innovation in energy sector
New Delhi: GAIL (India) Limited and Petronet LNG Limited have joined hands with the MC² Foundation and the iTIC Incubator of IIT Hyderabad to accelerate startup-led innovation in India’s energy sector, with a focus on deploying digital technologies to improve asset performance, operational efficiency and sustainability. The organisations hosted the MC² Plus IGNITE Hyderabad Connect at IIT Hyderabad, bringing together energy-sector leaders, academia, startups, entrepreneurs and technology experts to explore solutions for emerging challenges across the energy value chain.
SHOW MORE
The Hyderabad edition focused on Digital Asset Management, with discussions centred on the use of artificial intelligence (AI), machine learning, advanced analytics, sensors, robotics, drones and digital twins to transform conventional infrastructure into intelligent assets.
GAIL CMD Deepak Gupta said India was at a “remarkable inflection point”, with rapidly rising energy requirements coinciding with its ambition to become a developed economy while ensuring affordable and reliable energy and meeting climate commitments.
He said the energy sector faces the challenge of balancing rising demand with the transition towards cleaner energy, greater energy security, smarter and more resilient infrastructure and reduced dependence on imported technologies and critical systems.
Gupta said MC² Plus IGNITE aims to bring startups, academia, research institutions and the oil and gas industry onto a common platform, enabling innovative ideas to progress from laboratory research to prototypes, pilots, deployment and commercial scale. He emphasised that innovation should ultimately be measured by successful implementation and real-world impact.
On digital asset management, Gupta highlighted the potential to move the industry beyond preventive and predictive maintenance towards prescriptive maintenance, where technology can anticipate equipment failures and recommend appropriate interventions.
He outlined five key imperatives for the energy sector — efficiency, technology self-reliance, net-zero, self-sustaining energy systems and technological self-reliance. He also called for greater emphasis on “Make in India” and “Invent in India”, with the long-term objective of innovating and deploying technologies domestically and exporting them globally.
Akshay Kumar Singh, MD & CEO, Petronet LNG, said MC² Plus IGNITE was connecting the energy industry with India’s startup and innovation ecosystem, particularly in areas such as AI, advanced sensors, robotics and digital twins.
He said these technologies could make LNG infrastructure smarter, safer, more reliable and efficient, while creating opportunities for innovation across the LNG value chain.
Singh also pointed to the commercial potential of cold energy generated during the LNG regasification process, which could be utilised in sectors such as data centres, cold storage and air separation units. He also highlighted opportunities to improve CBG yields and optimise value-added byproducts, potentially contributing to import substitution.
Prof. B. S. Murty, Director, IIT Hyderabad, said the institute’s collaboration with MC² Foundation would help bring together industry, academia and startups to address critical challenges in the energy sector. He said the partnership would leverage faculty expertise, research capabilities and infrastructure to help promising technologies move closer to real-world deployment.
Ayush Gupta, Director (HR), GAIL, said MC² Plus IGNITE would provide innovators with access to mentors and support to convert real-life industry challenges into scalable solutions. He urged students and startup founders to challenge conventional approaches and develop solutions that can contribute to affordable, sustainable and energy-secure growth.
MC² Plus is positioned as an energy innovation accelerator envisioned by the Ministry of Petroleum and Natural Gas in collaboration with leading energy-sector organisations. The programme covers seven priority themes — Digital Asset Management; AI-Driven Subsurface Intelligence; Next-Generation Drilling & Well Completion; Refinery Process Intensification & Catalysis; Bio-Energy with a focus on Compressed Biogas; Hydrogen & Mobility; and other energy-sector innovations.
Under the programme, selected startups can receive convertible funding of up to Rs 50 lakh and milestone-based funding of up to Rs 1.5 crore. The accelerator aims to support 30 high-potential early-stage startups through mentorship, technical expertise, pilot opportunities, funding and industry networks.
The Hyderabad Connect also featured a panel discussion on innovation and the startup ecosystem, bringing together representatives from startups working in areas including energy technology, pipeline integrity, robotics, artificial intelligence and digital solutions.
An IIT Hyderabad session on innovation and entrepreneurship and a presentation by the Federation of Indian Petroleum Industry (FIPI) on Avinya’27, its energy startup challenge and India Energy Week 2027 were also part of the programme.
The event was attended by senior officials and industry leaders, including GAIL CMD Deepak Gupta, Petronet LNG MD & CEO Akshay Kumar Singh, IIT Hyderabad Director Prof. B. S. Murty and GAIL Director (HR) Ayush Gupta.
show less
Viability issues: Think Gas seeks 30% reduction in LNG terminal charges
City gas distributor Think Gas urges a thirty percent reduction in LNG terminal usage charges. High regasification and truck loading fees currently hinder third-party LNG terminal use. The company also highlighted unreasonable boil-off gas charges imposed by terminal operators. These costs artificially inflate prices and impede natural gas market growth. Think Gas seeks moderation of charges for the proposed Indian Gas Exchange platform.
SHOW MORE
New Delhi: City gas distributor Think Gas has told the downstream regulator that “prohibitive terminal economics currently undermine the viability of third-party usage” of LNG terminals and called for a 30% reduction in usage charges at all LNG terminals.
Think Gas, backed by I Squared Capital, Osaka Gas and Sumitomo Corporation, has distribution licences for 19 city gas areas, covering 49 districts across the country.
“High regasification charges across LNG terminals ( ’73-104/MMBTU) and truck loading charges (’81-120/MMBTU), burdened with annual escalation of 5% per annum, require a mandatory moderation of these charges by at least 30% across all LNG Terminals,” Think Gas wrote to the Petroleum and Natural Gas Regulatory Board (PNGRB) during a consultation process on the Indian Gas Exchange proposal to set up a platform to book LNG terminal capacity.
PNGRB doesn’t regulate regasification fees charged by terminals.
India has eight operating LNG terminals with a total capacity of about 58.5 million tonnes per annum. More than half of the import capacity remains underutilised due to weak demand.
Think Gas said LNG terminal operators impose “unreasonably high” boil-off gas charges despite there being no actual boil-off during continuous LNG operations. This imposes “an artificial cost burden on end consumers and hinders the development of the natural gas market”, Think Gas said.
The city gas distributor cited lower terminal fees, quick connectivity of all trunk pipelines to the national gas grid system and an extended period for evacuation of LNG cargo at terminals as critical enablers for the proposed IGX platform to take off.
show less
Policy Matters/ Gas Pricing/ Others
No refuelling: Govt gets strict on hydro test of cylinders in CNG vehicles
New Delhi: Delhi govt will strictly enforce the mandatory hydro-test requirement for CNG vehicles and won’t allow refuelling if the certificate has expired or can’t be shown, senior officials said. The hydro test, required to be carried out every three years as per Rule 35(1) of Gas Cylinder Rules (2025 Amendment), checks whether a cylinder can safely withstand the high pressure at which CNG is stored in it. During the test, the cylinder is emptied, filled with water and subjected to very high pressure to check for leaks, cracks or swelling.
SHOW MORE
In CNG vehicles, gas is stored in cylinders at 200-250 bar pressure. Regular use, pressure changes and exposure to road vibrations can affect the cylinder over time, making periodic testing important for detecting structural damage that may not be visible during a routine inspection, said an official.
The hydro-test certificate serves as an official document confirming that the cylinder has passed the prescribed high-pressure water test and is considered safe for use.
The move follows the explosion of a truck’s CNG cylinder during refuelling on Aug 19, killing three pump workers and seriously injuring three others.
Indraprastha Gas Limited (IGL) has already launched a special drive at its CNG stations and asked personnel to verify the validity of hydro-test certificates before refuelling, said the official. The periodic test is essential for every safe journey, said an IGL official, urging vehicle owners to get their cylinders tested on time and keep the certificate in the vehicle. Vehicle owners have been asked to get their cylinders tested at a centre approved by Petroleum and Explosives Safety Organisation as per the Rules.
show less
Supreme Court allows Oil India to file plea on rejection of drilling proposal at Assam’s Dibru-Saikhowa National Park
The Supreme Court on Wednesday (September 2, 2026) permitted Oil India to withdraw an interlocutory application and file a fresh plea seeking to overturn the rejection of its proposal by the Centre for Extended Reach Drilling (ERD) linked to hydrocarbon extraction beneath Assam’s Dibru-Saikhowa National Park. A Bench comprising Chief Justice Surya Kant and justices Joymalya Bagchi and V. Mohana was urged by senior advocate Rakesh Dwivedi, appearing for Oil India, that the plea was extremely urgent and be listed for hearing.
SHOW MORE
“This is extremely urgent because the area is on the fringes of a national park. All permissions have been granted, but the government considers itself bound by a 2023 order of this court banning mining. This is not mining. The pipeline is being laid outside the park. It goes 4,000 metres underground and then proceeds horizontally,” Mr. Dwivedi said.
He said the application has been filed in a pending case titled T.N. Godavarman Thirumulpad vs Union of India of 1995, a landmark piece of litigation that has played a pivotal role in shaping forest conservation and environmental jurisprudence.
Mr. Dwivedi highlighted the urgency of the matter and said the proposed project was crucial to the country’s energy requirements.
He told the Bench that the registry was not numbering the interlocutory application because of an earlier direction that no such applications would be taken on board in the pending matter.
The CJI said that if there was a fresh cause of action, the applicant could file a new petition.
“We wanted to close that entire matter. If there is a fresh cause, file a fresh petition and we will entertain it. The registry cannot list the interlocutory application because there is an order to that effect,” the CJI said.
Mr. Dwivedi stressed the importance of the project, submitting that it concerned nearly three per cent of the country’s oil requirement.
He requested the Bench to permit withdrawal of the interlocutory application with liberty to institute a fresh petition, adding that the matter could be taken up either at the beginning or the end of the day’s proceedings.
“The interlocutory application, as requested, is allowed to be withdrawn with liberty to file a fresh petition,” the Bench said.
The PSU, in its plea, has challenged the Forest Advisory Committee’s decision and the subsequent action of the Ministry of Environment, Forest and Climate Change (MoEFCC) refusing approval for the diversion of 0.069 hectares of forest land for the project in Tinsukia district.
The company said that the authorities wrongly applied the Supreme Court’s April 26, 2023 judgment prohibiting mining within national parks and wildlife sanctuaries and within one kilometre of their boundaries.
According to OIL, hydrocarbon exploration and production through Extended Reach Drilling cannot be equated with conventional mining.
The company has submitted that oil and gas operations are governed by a separate legal and regulatory framework and that ERD involves drilling from pads located outside the protected area to access hydrocarbon reservoirs several kilometres below the surface.
OIL said that the proposed drilling would target hydrocarbon deposits at depths of around 3,500 to 4,000 metres beneath the Dibru-Saikhowa National Park, while the drilling infrastructure would remain outside the park boundary.
The company has also relied on earlier orders of the top court in 2017, when it was permitted, subject to conditions and safeguards, to extract hydrocarbons beneath the national park using ERD technology.
It said the Standing Committee of the National Board for Wildlife had recommended the proposal and that the top court subsequently allowed sub-surface hydrocarbon extraction, subject to compliance with environmental and wildlife protection conditions.
The application further referred to the Eco-Sensitive Zone notification issued for Dibru-Saikhowa National Park in January 2020, under which the eco-sensitive zone extends from zero to 8.7 kilometres around parts of the park’s boundary.
OIL said it had also received environmental clearance in May 2020 for extension drilling and testing of hydrocarbons at seven locations beneath the national park, although drilling in forest areas required separate prior approval.
It sought setting aside the order of August 02, 2024 passed by the MoEFCC and also minutes of the meeting of the Forest Advisory Committee of the MoEFCC on July 4, 2024.
“Direct the Respondent No.1 to grant approval under section 2(1)(ii) of the Van (Sanrakshan Evam Samvardhan) Adhiniyam, 1980 for non-forestry use of 0.069 Hectare of forest land for Extended Reach Drilling under Dibru Saikhowa National Park from Baghjan PML in Tinsukia Wildlife Division, Tinsukia in the State of Assam,” the plea said.
show less
West Bengal Transport Minister warns Bengal Gas over CNG supply
The direction came during a meeting with representatives of app-cab operators, aggregators, BGCL and senior transport officials on Tuesday. West Bengal Transport minister Arjun Singh has asked Bengal Gas Co Ltd to ensure uninterrupted CNG supply to the transport sector, warning alternative suppliers could be explored if the shortage was not addressed promptly.
SHOW MORE
The direction came during a meeting with representatives of app-cab operators, aggregators, BGCL and senior transport officials on Tuesday.
The participants discussed a range of issues affecting app-cabs, including fares, airport and station pick-ups, EV charging facilities and driver grievances.
show less
Govt tweaks HPHT gas allocation formula for distribution firms
The government has changed the allocation formula for natural gas produced from high-pressure, high-temperature (HPHT) fields to city gas distribution (CGD) companies. Supplies of HPHT gas for the CNG transport (CNG-T) and domestic PNG (PNG-D) segments will now be distributed based on each company’s shortfall after accounting for its allocations of APM, NAPM and New Well Gas (NWG).
SHOW MORE
The move will give a larger share of HPHT gas to CGD companies unable to meet demand from protected CNG and PNG segments through standard domestic allocations under the administered price mechanism (APM), non-APM (NAPM) or NWG.
CLARIFICATION ISSUED
The Ministry of Petroleum & Natural Gas (MoPNG) issued a clarification on the proportionate distribution of gas produced from discoveries in deepwater, ultradeepwater and HPHT areas to CGD entities serving the CNG-T and PNG-D segments.
The Ministry said it had examined the matter to ensure that available HPHT gas is distributed based on the requirements of CGD entities whose demand is not already being met through APM, NAPM and NWG gas.
For proportionate distribution among CGD bidders serving the CNG-T and PNG-D categories, the requirement of each company will be determined using a formula.
The formula calculates the dierence between a company’s natural gas consumption in the CNG-T and PNG-D segments and its
utilisation of APM, NAPM and NWG gas during the immediately preceding quarter or the latest available quarter.
These details will be provided by the Petroleum Planning & Analysis Cell (PPAC). The Ministry’s data dissemination arm will collate and provide companywise details to PNGRB-authorised gas exchanges, contractors and the bidding agency, as applicable from time to time, it said in an order.
PNGRB DATA
According to PNGRB data, India had 1.74 crore domestic PNG connections as of June 2026, against a prorata target of 4.41 crore, representing 39 per cent achievement. Around 1.50 lakh connections were added during the month.
India had 9,026 CNG stations as of June, against a pro-rata target of 7,328. Forty-six new CNG stations were commissioned during the month.
Cumulative CGD gas sales rose from 983 million standard cubic metres (MSCM) in July 2025 to 1,120 MSCM in June 2026, an increase of around 14 per cent over the period.
The month of June 2026 also recorded the highest total CGD sales of 1,773 MSCM, driven mainly by higher CNG and PNG industrial sales.
https://www.pressreader.com/india/businessline-delhi-9wvw/20260905/281956024659111
show less
Ministry of Petroleum and Natural Gas (MoPNG), aims to support 30 early-stage startups
Hyderabad (Telangana) [India], September 7 (ANI): The MC² Plus energy innovation accelerator, envisioned by the Ministry of Petroleum and Natural Gas (MoPNG), aims to support 30 early-stage startups with funding, mentorship, technical expertise and opportunities to pilot their technologies with the energy industry, according to a press release issued on Monday.
SHOW MORE
Selected startups will be eligible for convertible funding of up to Rs 50 lakh and milestone-based funding of up to Rs 1.5 crore, the release said.
“The programme aims to support 30 high-potential early-stage start-ups through mentorship, technical expertise, pilot opportunities, funding and industry networks,” the press release said.
MC² Plus brings together energy companies, startups, research institutions and academia, with GAIL (India) Limited and Petronet LNG Limited among the participating energy-sector organisations.
Sandeep Maheshwari, CEO of MC² Foundation, said the programme focuses on seven areas, including digital asset management, AI-driven subsurface intelligence, next-generation drilling and well completion, refinery process technology, compressed biogas, hydrogen and mobility.
The latest MC² Plus IGNITE Connect was held at IIT Hyderabad in association with the institute’s iTIC Incubator, with the Hyderabad edition focusing on digital asset management.
GAIL Chairman and Managing Director Deepak Gupta said the programme is intended to help move technologies beyond the research stage and towards commercial use.
“The initiative seeks to bring together startups, academia, research institutions and the Oil & Gas industry on a common platform, enabling ideas to move from the laboratory to prototype, pilot, deployment and scale,” Gupta said, according to the release.
He said the sector needs greater use of artificial intelligence, machine learning, advanced analytics, sensors, robotics, drones and digital twins to improve the management of energy infrastructure.
Petronet LNG Managing Director and CEO Akshay Kumar Singh also highlighted potential areas where startups could work with the LNG industry, including the commercial use of cold energy generated during the regasification process.
The release said such cold energy could potentially be used in sectors including data centres, cold storage and air separation units. Singh also pointed to scope for improving compressed biogas yields and developing value-added by-products that could help reduce imports.
“MC²+ Ignite [is] connecting India’s energy industry with the startup and innovation ecosystem, with a focus on leveraging digital technologies such as AI, advanced sensors, robotics and digital twins to make LNG infrastructure smarter, safer, more reliable and efficient,” Singh said.
The programme is aimed at helping startups test and scale technologies that address operational challenges across India’s energy sector, according to the release. (ANI)
(This content is sourced from a syndicated feed and is published as received. The Tribune assumes no responsibility or liability for its accuracy, completeness, or content.)
show less
PNGRB-EESL MoU to drive smart PNG metering
The MoU signed by the Petroleum & Natural Gas Regulatory Board (PNGRB) and Energy Efficiency Services Limited (EESL) recently is set to give a major technology push to India’s City Gas Distribution (CGD) sector through large-scale deployment of Smart Domestic Piped Natural Gas Meters, an official release said here on Sunday (September 6, 2026).
SHOW MORE
The initiative is expected to usher in a new generation of gas metering with advanced features including digital monitoring, tamper alerts, leak detection, remote operations and cyber-security safeguards, making the PNG ecosystem not only more efficient and transparent but also safer and more secure for millions of consumers, the release added.
The partnership brings together PNGRB’s regulatory expertise and EESL’s experience in demand aggregation and large-scale smart-metering programmes. With PNG connections expanding rapidly across urban and semi-urban areas, traditional manual metre reading and periodic billing systems could face growing challenges relating to accuracy, revenue assurance and safety monitoring and customer service.
The initiative is expected to benefit the stakeholders of all States including Andhra Pradesh, Telangana, Kerala, Tamil Nadu and Karnataka.
show less
PNG push sputters in Chandigarh, UT plans VAT cut to 5%
Chandigarh: The city’s push to wean households off LPG and shift them to piped natural gas (PNG) has made little headway, with just one in five targeted households opting for the fuel. The UT administration now plans to slash VAT on PNG from 12% to 5% to make the cleaner cooking fuel more affordable and boost adoption. Data placed before Parliament shows Chandigarh had only 34,175 domestic PNG connections as on May 31, 2026, against a target of 1.7 lakh connections. In contrast, the city has nearly 3.08 lakh LPG connections. The figures highlight the uphill task before the administration.
SHOW MORE
A UT official said the proposed tax cut would significantly reduce the cost of PNG for consumers and could help accelerate the shift from LPG.
Network ready, consumers slow to switch
PNG was introduced in Chandigarh in 2016 by Indian Oil-Adani Gas Pvt Ltd (IOAGPL). Its pipeline network now covers several areas, including sectors 32-38, 40-51, Industrial Area Phases I and II and Manimajra — around 30% of the city.
Despite infrastructure being in place for years, consumer uptake has remained limited. The administration has now intensified efforts through door-to-door awareness drives, registration camps in group housing societies and coordination with resident welfare associations.
The food and supplies department has been directed to organise two camps daily in housing societies to facilitate on-the-spot registrations and address residents’ concerns.
No cylinders, booking hassles
Officials are pitching PNG as a more convenient alternative to LPG, with uninterrupted supply through pipelines eliminating the need to book, transport and replace cylinders.
PNG also operates at lower pressure and, being lighter than air, disperses faster in case of a leak. The absence of bulky cylinders is another advantage, particularly for elderly residents and apartment dwellers.
The administration is also targeting hotels, restaurants and other commercial establishments, where higher fuel consumption could make the switch more significant.
With the proposed VAT cut and intensified outreach, the UT administration is hoping to bridge the wide gap between its ambitious PNG target and the city’s current consumer base.
Slow on uptake
Chandigarh has achieved only 34,175 domestic PNG connections against a target of 1.7 lakh households, with LPG continuing to dominate at 3.08 lakh connections
To boost adoption of piped natural gas, UT plans to cut VAT from 12% to 5%, making PNG cheaper for consumers
Despite PNG infrastructure covering about 30% of the city, including several sectors, Industrial Area and Manimajra, consumer response has remained limited
The administration has launched door-to-door awareness campaigns, registration camps and RWA outreach to encourage households to switch from LPG
Officials are promoting PNG as a safer and more convenient alternative, offering uninterrupted supply without cylinder
show less
LNG Use / LNG Development and Shipping
LNG prices surge to multiyear highs as West Asia war squeezes supplies
“Winter is coming,” a metaphor that lit up “Game of Thrones”, portending impending gloom, may as well apply to India’s liquefied natural gas (LNG) importers as they prepare for a surge in prices of the fuel, already at a multiyear high. A perfect storm is brewing: Europe is staring at low natural gas storage levels; the West Asian war shows no signs of ending, crippling a fifth of global LNG supplies; and Asian nations are frantically seeking alternative sources.
SHOW MORE
Taken together, prices of LNG — natural gas cooled to ultra-low temperatures to turn it into a liquid for sea transport — have soared to multiyear highs. The impact is felt globally, especially by Indian city gas utilities, as they will compete with Europe for supplies from America and West Africa, areas in proximity to Europe. For instance, the spread between Asian LNG benchmark JKM and European benchmark TTF halved to just $1 per million British thermal units (MMBtu) in August from previous months, highlighting increasingly fierce competition between Asia and Europe for flexible LNG cargoes, said Greg Molnar, a gas analyst at the Paris-based International Energy Agency, on LinkedIn.
The war in West Asia has sent prices of LNG soaring. Rates got dearer after the US and Iran re-engaged in hostilities after a lull in July, with the pricing tremors felt in India — IGL, India’s biggest city gas utility, took its biggest single-day hike for compressed natural gas (CNG), a transport fuel, a few days ago by increasing its price in Delhi by Rs 3.9/kg. Cumulatively, this brings IGL’s CNG price hike since the start of the year to Rs 9.9/kg — the highest among the CGD companies. “This is one of the most aggressive stances we have seen by IGL in recent times,” said Mumbai-based DAM Capital in a note. “The hike is also driven by the fact that IGL has seen the highest cost increase and consequently highest margin compression.”
In Europe, benchmark TTF month-ahead gas prices rose by almost 90 per cent year-on-year in August to an average of $21/MMBtu — their highest level since December 2023; in Asia, S&P Platts’ Japan Korea Marker (JKM) prices moved in tandem with TTF, rising 90 per cent on the year to an average of $22/MMBtu, Molnar said. The Argus-assessed prices for deliveries to west and east India for the first half of October stood at $25.34/MMBtu and $25.57/MMBtu, according to UK-based pricing agency Argus.
The ANEA, the Argus assessment for spot LNG deliveries to northeast Asia, for the front-half month was assessed at $25.83/MMBtu, exceeding the initial peak of $25.165/MMBtu recorded on March 19, right after Iranian attacks damaged nearly a fifth of Qatar’s 77 million tonnes a year LNG output capacity. Prices marked an almost four-year high as the front-half month ANEA was last assessed higher on December 30, 2022, at $26.1/MMBtu, Argus said. The second-half October ANEA was $25.78/MMBtu, and the second-half November assessment was $25.64/MMBtu.
“Qatar and the Emirates were effectively cut from global LNG trade for over 6 months now, leading to a cumulative LNG supply loss of more than 50 bcm through the March-August period, a decline equating to around half of China’s LNG imports in 2025,” Molnar said.
Qatar has declared force majeure on term LNG shipments until October/November for buyers including India’s Petronet LNG. Petronet and its promoters have a long-term contract for 8.5 million tonnes a year of LNG supplies, a third of overall LNG imports. Two of Ras Laffan’s LNG trains could take 3-5 years to resume exports, and the rest will start supplies once the Strait of Hormuz is ready for traffic, senior industry officials said.
The squeeze in West Asian supplies echoed in prices of LNG cargoes purchased by Indian importers. State-controlled gas distributor Gail may have purchased an October delivery at around $25.10-25.20/MMBtu, and another November delivery at around $24.90-25/MMBtu, likely on September 1, Argus cited traders as saying.
Cheap domestic gas from old fields accounts for only 40 per cent of CGD supplies, a senior industry official said. The rest comes from costly imported LNG, which shrinks margins and reduces the value of CNG compared to substitutes like petrol and diesel. Post this price hike, the difference versus petrol/diesel for IGL remains at Rs 15 and Rs 8, respectively — decent enough to drive CNG adoption, DAM Capital said. But anything higher would push motorists away from CNG, currently the highest-selling vehicles.
Despite the price increases, South Asian LNG importers, the most price-sensitive globally, have been accelerating imports. In South Asia, weekly shipments to India (0.8 mt, 11 cargoes) rose to their strongest since February, thanks to increased gas demand from the city gas and fertiliser sectors, market intelligence agency Vortexa said in a note. Bangladesh imported three cargoes (0.1 mt) after the country’s two FSRUs resumed operations earlier in August.
Indian imports of LNG rose by a remarkable 34 per cent year-on-year to nearly 2.5 million tonnes in August, according to data from market intelligence agency Kpler. Spot LNG averaged $13-$14/MMBtu in Asia in August 2025. City gas utilities and concerns in New Delhi over gas shortages have prompted higher imports, industry officials said.
The recent rally in LNG prices could just be the beginning, especially with the winter season approaching and Europe low on natural gas storage, analysts said. EU-wide gas storage fill ended last week at 65 per cent, trailing the five-year average by 17 percentage points, Vortexa said.
Hormuz remains the single most important uncertainty, while the ramp-up of new LNG projects might slow down in the coming months, thus offsetting less of the potential supply losses from Qatar and the Emirates, Molnar said. Marry that to a cold winter and a surge in European buying, and that pitches a price-sensitive Indian market against wealthier European buyers for the same molecules.
show less
India is eyeing Russia’s Arctic LNG. Sanctions are holding it back
Arctic LNG remains a matter under study for India: the scale of the resource base and India’s fast-growing economy create real grounds for closer Russia-India ties. LNG is the second-largest growth point — after oil — in the Russia-India energy relationship. But while Delhi has steadily and confidently ramped up its oil purchases, gas is a more complicated story. India has been avoiding sanctioned batches of Russian LNG, even though its interest in the Arctic’s resource base is clear. In the summer of 2026, the issue moved back to the centre of the bilateral agenda, against the backdrop of Asia’s rising gas potential and the continuing search for alternative energy sources. India is already one of the world’s largest LNG importers: by the end of 2025 the country ranked fifth globally by import volume, behind China, Japan, South Korea and France. Current annual imports run at roughly 27–30 million tonnes, handled through seven regasification terminals with a combined capacity of about 48 million tonnes a year. The supplier structure remains fairly conservative and tied to traditional exporters. Qatar accounts for about 41 per cent of the market, the United States for about 19 per cent, the UAE for about 11 per cent, and African states (Nigeria, Angola, Cameroon) for about 10 per cent.
SHOW MORE
Major projects and buyers
India’s strategic ambitions go well beyond current figures. New Delhi aims to raise gas’ share of its energy mix to 15 per cent by 2030 (from roughly 6 per cent today), and the International Energy Agency projects that the country’s LNG demand could rise to 40-50 million tonnes a year. To meet that target, India plans to expand existing terminal capacity and build new terminals — primarily on the east coast, which would also open up potential supply routes from the east, including via the Trans-Arctic Transport Corridor.
On the Russian side, the flagship of Arctic LNG remains Novatek’s Yamal LNG project — extraction, processing and liquefaction of gas from the South Tambey field on the Yamal Peninsula. The plant’s designed capacity is 17.4 million tonnes a year, making it one of the largest LNG producers in the world.
Product is shipped out on Arc7 ice-class “Yamalmax” tankers, moving both west and east along the Northern Sea Route. Shipping routes follow a pronounced seasonal pattern: from November to April, when heavy ice persists in the East Siberian and Chukchi Seas, most LNG moves west, through the European part of the NSR and on into the Atlantic. From June, eastbound shipments build up, peaking in August-September when ice conditions in the eastern Arctic are most favourable.
A landmark moment came in January 2021, when the gas carriers Christophe de Margerie and Nikolay Yevgenov became the first vessels to sail the NSR eastbound independently, without icebreaker escort — proof that year-round navigation is achievable.
Yamal LNG’s delivery footprint keeps expanding despite fierce competition on the global market. In Europe, the bulk of volumes go to France, Belgium and Spain, with smaller amounts to the Netherlands, Portugal and the UK. In the Asia-Pacific, the main buyers are China, Japan and South Korea.
The second major project is Arctic LNG 2 on the Gydan Peninsula, with a combined capacity of around 20 million tonnes a year. Its development has been harder going: under US sanctions, the project has faced delays in both shipping and the construction of its icebreaking tanker fleet, and foreign partners — including France’s Total — have suspended participation. Even so, the first production line came online in late 2023, and in 2025–2026 the first Arc7 ice-class gas carriers built in Russia, at the Zvezda shipyard (lead vessel Alexey Kosygin, followed by Konstantin Posyet), were launched to support Arctic LNG 2 logistics, including shipments to China. A matter under study
Why the caution on India’s side, then? The key condition for scaling up deliveries is the sanctions status of Russia’s various LNG assets. Arctic LNG 2 has been under US sanctions since 2023, and the smaller Gazprom LNG Portovaya plant is also covered by restrictions. That plant was at the centre of a notable incident in spring 2026: an LNG tanker bound for India’s Dahej terminal (Gujarat) was identified by ship-tracking services as carrying gas from the sanctioned project. Indian authorities refused to accept the cargo, and the vessel was left waiting off Singapore with no announced port of discharge.
According to available reports, at a meeting with a Russian deputy energy minister, Indian officials stated plainly that they were not prepared to purchase sanctioned LNG — while talks on possible deliveries of non-sanctioned Russian LNG continue.
It’s important to distinguish between the projects here: Yamal LNG itself is not under blocking sanctions, and India’s GAIL holds a long-term contract with a Gazprom Group trading arm (Gazprom Marketing & Trading Singapore) for roughly 2.9 million tonnes of gas a year.
Yet in the first half of 2026, almost the entire output of the plant — a record for the period, at about 9.89 million tonnes — was bought up by European purchasers rushing to secure fuel ahead of a new EU ban on short-term-contract imports of Russian LNG.
China’s experience — as the largest buyer of Arctic LNG 2 output and a significant recipient of Yamal LNG volumes — points to what it would take to move from intentions to contracts. Asian countries have shown they are willing to work with additional sanctioned projects where the economics make sense and where payment, insurance and tanker arrangements are in place.
For India, which is trying to balance its ties while also positioning itself as a strategic partner of the United States in the Indo-Pacific, that model remains politically sensitive for now.
Arctic LNG remains, for India, still a matter under study: the scale of the resource base and India’s fast-growing economy create real grounds for closer Russia-India ties, but the sanctions architecture built around Russia’s LNG projects continues to hold back the move toward long-term contracts.
https://theprint.in/opinion/india-eyeing-russias-arctic-lng-sanctions-are-holding-back/3039111/
show less
LNG diversification, pipeline connectivity and CBG to shape India’s next gas demand phase: Industry leaders
Industry leaders at the ET Energy Leadership Summit said diversified LNG sourcing, integrated infrastructure, CGD expansion and CBG will drive the next phase of gas demand. India’s gas market is emerging from recent supply disruptions with a sharper focus on diversified LNG sourcing, interconnected pipelines, deeper city gas penetration and domestic alternatives such as compressed biogas. The challenge now is to convert that infrastructure resilience into sustained and affordable demand growth.
SHOW MORE
The issue was discussed at the 6th edition of the ET Energy Leadership Summit 2026 during the panel, “The Gas Bridge – LNG Security, Domestic Infrastructure and the Next Phase of Gas Demand”, which brought together industry leaders from across the gas sector. The discussion was moderated by Purva Jain, Lead Energy Specialist, Gas & International Advocacy, South Asia, IEEFA. The two-day event is being held from September 9-10, 2026, in New Delhi.
Supply security moves beyond long-term LNG contracts
Pramod Narang, Director Technical, Petronet LNG, said recent disruptions demonstrated that energy security cannot depend only on long-term LNG contracts; the entire supply chain needs to remain resilient.
Despite weak volumes during March and part of April, India imported about 18.4 million tonnes of LNG between January and August 2026, compared with 17.3 million tonnes during the same period a year earlier, he said, reflecting the ability to rapidly diversify supply sources. He argued that LNG demand will continue alongside renewables because several applications still require energy in molecular form.
Growth in household PNG and LNG for long-haul transport could create significant additional demand over the coming years.
Gas infrastructure becomes an interconnected system
Madhoop Sah, Director – Authorisation, PNGRB, said PNGRB increasingly views LNG terminals, transmission pipelines and city gas distribution as parts of one integrated network rather than separate infrastructure segments.
India has authorised more than 35,000 km of gas pipelines, of which around 28,000 km is operational, while 309 geographical areas have been authorised for city gas distribution. Around 85 per cent are already connected through pipelines, he said. PNGRB is also working on deeper market development through tariff rationalisation, open access and new trading products, while extending pipeline connectivity into regions including the Northeast, Jammu and other underserved markets.
CGD players continue expansion despite volatility
Mohit Bhatia, Director Commercial, Indraprastha Gas, said city gas distribution is among the fastest-growing segments of India’s gas market, with CNG and PNG providing significant room for expansion. Price volatility has required companies to balance consumer affordability with volume growth rather than passing through the full impact of higher gas costs immediately.
Ashu Shinghal, Chief Executive Officer, GAIL Gas, said infrastructure expansion has continued even in geographical areas without trunk-pipeline connectivity, using gas cascades to seed demand until pipeline networks arrive. Recent regulatory measures simplifying permissions have also accelerated last-mile infrastructure development.
Girija Shankar, Managing Director, Maharashtra Natural Gas, highlighted a similar approach in Maharashtra, where LNG and CNG infrastructure has been used to develop markets before pipeline connectivity, allowing commercial demand to grow without waiting for the full network to be completed.
Praveer Kumar Srivastava, Managing Director & CEO, Mahanagar Gas, pointed to continued CNG, PNG and industrial demand as evidence that gas retains a role even as competing fuels expand.
CBG could strengthen domestic gas supply
The panel also identified compressed biogas as a major opportunity to reduce import dependence while using existing CNG and PNG infrastructure. Panellists said improving CBG economics, direct pipeline injection, government support and maturing technologies could accelerate investment, while future vehicle technologies combining CNG and electric power could create another demand avenue.
India’s next gas growth phase will therefore depend on more than securing LNG cargoes. Resilience will increasingly come from combining diversified imports with domestic gas, connected infrastructure, stronger CGD markets and renewable gas sources that can collectively make the system less vulnerable to external shocks.
show less
Electric Mobility/ Hydrogen/Bio-Methane
Surrounded by energy crises, Bihar eyes Rs 1.38 lakh crore solar investment
The state collected over Rs 19,000 crore from electricity users in 2025–26, but spent between ₹25,000 crore and ₹35,000 crore annually to buy power from outside sources. It is also burdened with Rs 3,800 crore from offering 125 units of free power to 1.89 crore of its 2.2 crore consumers Amid massive power purchase costs, minimal revenue and energy demand peaking nearly 17 times the generation capacity in summers— Bihar is betting on solar energy to meet its electricity needs with a target of 24 GW of renewable energy capacity and 6 GWh of energy storage systems by 2030.
SHOW MORE
This clean energy push stems from the stark financial reality of the state’s energy sector. The state collected over Rs 19,000 crore from electricity users in 2025–26, but spent between ₹25,000 crore and ₹35,000 crore annually to buy power from outside sources. It is also burdened with Rs 3,800 crore from offering 125 units of free power to 1.89 crore of its 2.2 crore consumers.
The state faces an average daily demand of 7,300 to 7,400 MW, peaking at 9,500 MW in the summer, against its own generation capacity of just 550 MW. With electricity demand projected to cross 11,700 MW by 2030, the government has unveiled a Rs 1.38 lakh crore investment plan over the next five years, heavily focused on renewable energy. Energy department officials, however, insist the move is guided by the power sector’s recent financial turnaround rather than just fiscal pressure. “The focus on clean power comes amid a sharp financial turnaround across the state’s energy utilities,” a senior energy official told The Indian Express. Under its Renewable Energy Policy 2025, Bihar aims to harness nearly 24 GW of renewable energy and build 6 GWh of energy storage systems by 2030, driven predominantly by solar power.
“To keep pace with peak electricity demand, which is projected to grow to 11,747 MW by 2030, the Bihar State Power Holding Company Limited will invest ₹82,679 crore directly to generating assets, including pumped storage power projects, nuclear feasibility studies in Banka and Siwan, and solar installations. Transmission infrastructure will receive Rs 24,683 crore to build a 680-circuit-kilometer Green Energy Corridor, with the remaining funds earmarked for distribution, digital upgrades, and maintenance,” the official said.
A centerpiece of the state’s green agenda — Rs 2,866 crore Kajra Solar Power Plant in Lakhisarai, pairs a 301 MW solar facility with a 523 MWh Battery Energy Storage System (BESS). Beyond utility-scale plants, the state is also expanding decentralized solar infrastructure. Groundwork has begun on the 150 MW Aurangabad Solar Park. Rooftop solar is also scaling up under the Centre’s Surya Sankalp scheme, which has installed 115 MW across 12,000 government buildings, with another 500 MW recently approved. Rural and residential programs add to this through 457 MW in PM-KUSUM feeder solarization projects and rooftop installations targeting 10 lakh consumers under PM Surya Ghar. The state now provides power to over 2.2 crore consumers, up from 17 lakh twenty years ago with per capita electricity consumption growing more than fivefold in the same period.
show less
WeWork India to develop 10 MWp solar plant in Karnataka for renewable energy goal
WeWork India Management Limited, the industry leader in the flexible workspace sector, announced plans to develop a 10 MWp (DC) ground-mounted solar power plant in Karnataka, marking a significant milestone in its goal to transition towards 100% renewable electricity by March 2028. Targeted for commissioning in FY27, the plant is expected to generate approximately 15–16 million units of clean electricity annually. Once operational, it is expected to increase the share of renewable electricity across WeWork India’s portfolio from close to 40% currently to approximately 50%, bringing the company closer to its 100% renewable electricity goal.
SHOW MORE
Nearly 80% of the plant’s output will support WeWork India’s operations, including 10 centres in Bengaluru. The remaining 20% of the plant’s output will be used for its future growth.
Karnataka is a strategic location for the investment, with Bengaluru representing WeWork India’s largest market at 30 operational centres. The state accounts for approximately 30% of the company’s total electricity consumption across its portfolio, making it a natural market to drive renewable energy adoption at scale.
The solar plant will enable WeWork India to meet a meaningful share of this demand through renewable power, while reducing its reliance on conventional grid electricity.
Commenting on the development, Karan Virwani, Managing Director & CEO, WeWork India, said, “Bengaluru is our largest market, making it the natural starting point for an investment of this scale. As we grow, we want a greater share of that growth to be powered by clean energy, but we also want sustainability to make strong business sense. Building our own renewable generation capacity allows us to do both – reduce the carbon footprint of our operations while creating greater certainty over energy costs for the next 25 years. This is the kind of long-term investment we believe can make sustainability an integral part of how we scale, rather than an initiative that sits alongside the business.”
This investment also reflects WeWork India’s approach towards combining sustainability outcomes with disciplined capital allocation. With a design life of 25 years, the solar plant will provide greater long-term visibility over electricity costs for a significant part of its Bengaluru operations, helping insulate the portfolio from fluctuations in grid tariffs.
Solar power is expected to provide electricity at a more competitive cost over the life of the asset, translating into operating efficiencies at the centres it serves. By combining owned renewable generation, captive consumption and open access, WeWork India is creating a more diversified energy sourcing model designed to deliver both lower-carbon operations and greater cost certainty.
The project is part of WeWork India’s broader effort to embed sustainability into the growth and operation of its portfolio. As enterprises increasingly look to reduce the environmental footprint of their operations and supply chains, access to workspaces powered by cleaner energy can also help support their wider sustainability ambitions.
Expected to be commissioned by Q1 2027, the solar plant marks WeWork India’s progression from renewable electricity procurement towards direct investment in renewable generation capacity. As the company scales its portfolio, this approach is intended to ensure that growth is accompanied by a more resilient, efficient and lower-carbon energy model.
show less
Brazil Seeks Stronger Green Energy Partnership with India
Brazil has expressed interest in expanding its cooperation with India in renewable energy and the broader transition towards a low carbon economy, highlighting its long experience in developing alternative energy solutions. Roberto Carlos Razera Papa, Agricultural Attache at the Embassy of Brazil in India, said that the two countries could benefit from greater exchange of knowledge and experience as India accelerates its clean energy transition.
SHOW MORE
Brazil has been developing renewable and alternative energy programmes for several decades, particularly in areas linked to biofuels and clean mobility. The country now sees scope to share its experience with India while exploring opportunities for collaboration across the green energy sector.
Razera said that the energy transition needs to consider not only environmental objectives but also economic and social factors. He added that cooperation between Brazil and India could help identify practical approaches that support sustainable development.
Energy is also likely to remain an important area of engagement between the two countries through the BRICS grouping, as members seek greater cooperation on energy security and the transition towards cleaner energy sources.
India is simultaneously expanding its clean mobility ecosystem through electric vehicles, biofuels, compressed biogas and compressed natural gas as it works to reduce emissions from the transport sector.
https://www.energetica-india.net/news/brazil-seeks-stronger-green-energy-partnership-with-india
show less
SECI Tenders 700 MW Solar Capacity for Odisha C&I Offtake
What happened: SECI has invited bids for 700 MW of ISTS-connected solar PV projects under a BOO model to supply power to C&I entities in Odisha. Why it matters: The tender allows developers to bypass ALMM requirements for projects located within SEZs or EOU-designated areas, offering a strategic advantage for module procurement.
SHOW MORE
Watch: Future announcements regarding the specific C&I buying entities and the final e-Reverse auction dates.
Background and Context
The Solar Energy Corporation of India (SECI) has officially invited bids for the development of 700 MW of interstate transmission system (ISTS)-connected solar PV projects. This initiative is specifically designed to cater to the growing power requirements of commercial and industrial (C&I) consumers located in Odisha. By acting as the intermediary nodal agency, SECI will facilitate the procurement of solar power through a build-own-operate (BOO) model, ensuring a stable 25-year power purchase agreement (PPA) for successful developers.
Key Details
This 700 MW solar tender represents a strategic push to integrate renewable energy into the industrial landscape of Odisha. A critical aspect of this tender is its alignment with the Ministry of New and Renewable Energy (MNRE) circular issued in May 2024. Projects established within special economic zones (SEZs) or designated export-oriented units (EOUs) are eligible for exemptions from the Approved List of Models and Manufacturers (ALMM) requirements. This provision provides developers with greater flexibility in sourcing solar modules, potentially optimizing project costs.
The bidding process involves e-bidding followed by an e-Reverse auction. Developers are permitted to bid for a minimum capacity of 50 MW, up to the full 700 MW. SECI has clarified that a single project may be distributed across multiple locations, provided they meet the delivery point requirements. Developers bear the full responsibility for land acquisition, project development, and the construction of transmission infrastructure up to the designated interconnection point.
What This Means for EPCs and Developers
For EPC contractors and solar developers, this tender offers a unique opportunity to participate in a large-scale C&I project with the security of a government-backed intermediary. The exemption from ALMM for SEZ/EOU-based projects is a significant incentive, allowing developers to leverage global supply chains for modules without the regulatory hurdles typically associated with domestic content requirements. However, the onus remains on the developer to manage the complexities of land acquisition and grid connectivity within the stipulated timelines.
What Happens Next
SECI is expected to disclose the specific identity of the C&I buying entities in the near future. As the India renewable energy sector continues to pivot toward C&I-focused growth, this tender serves as a benchmark for how intermediary agencies can bridge the gap between large-scale solar generation and specific industrial demand. Stakeholders should monitor the upcoming pre-bid clarifications to assess the impact of grid connectivity requirements on project viability.
https://www.mvapulse.com/seci-tenders-700-mw-solar-capacity-for-odisha-ci-offtake/
show less
SECI Tenders 700 MW Solar Capacity for Odisha C&I Offtake
What happened: SECI has invited bids for 700 MW of ISTS-connected solar PV projects under a BOO model to supply power to C&I entities in Odisha. Why it matters: The tender allows developers to bypass ALMM requirements for projects located within SEZs or EOU-designated areas, offering a strategic advantage for module procurement.
SHOW MORE
Watch: Future announcements regarding the specific C&I buying entities and the final e-Reverse auction dates.
Background and Context
The Solar Energy Corporation of India (SECI) has officially invited bids for the development of 700 MW of interstate transmission system (ISTS)-connected solar PV projects. This initiative is specifically designed to cater to the growing power requirements of commercial and industrial (C&I) consumers located in Odisha. By acting as the intermediary nodal agency, SECI will facilitate the procurement of solar power through a build-own-operate (BOO) model, ensuring a stable 25-year power purchase agreement (PPA) for successful developers.
Key Details
This 700 MW solar tender represents a strategic push to integrate renewable energy into the industrial landscape of Odisha. A critical aspect of this tender is its alignment with the Ministry of New and Renewable Energy (MNRE) circular issued in May 2024. Projects established within special economic zones (SEZs) or designated export-oriented units (EOUs) are eligible for exemptions from the Approved List of Models and Manufacturers (ALMM) requirements. This provision provides developers with greater flexibility in sourcing solar modules, potentially optimizing project costs.
The bidding process involves e-bidding followed by an e-Reverse auction. Developers are permitted to bid for a minimum capacity of 50 MW, up to the full 700 MW. SECI has clarified that a single project may be distributed across multiple locations, provided they meet the delivery point requirements. Developers bear the full responsibility for land acquisition, project development, and the construction of transmission infrastructure up to the designated interconnection point.
What This Means for EPCs and Developers
For EPC contractors and solar developers, this tender offers a unique opportunity to participate in a large-scale C&I project with the security of a government-backed intermediary. The exemption from ALMM for SEZ/EOU-based projects is a significant incentive, allowing developers to leverage global supply chains for modules without the regulatory hurdles typically associated with domestic content requirements. However, the onus remains on the developer to manage the complexities of land acquisition and grid connectivity within the stipulated timelines.
What Happens Next
SECI is expected to disclose the specific identity of the C&I buying entities in the near future. As the India renewable energy sector continues to pivot toward C&I-focused growth, this tender serves as a benchmark for how intermediary agencies can bridge the gap between large-scale solar generation and specific industrial demand. Stakeholders should monitor the upcoming pre-bid clarifications to assess the impact of grid connectivity requirements on project viability.
https://www.mvapulse.com/seci-tenders-700-mw-solar-capacity-for-odisha-ci-offtake/
show less
Torrent Green Energy commissions 322 MWp decentralised solar projects
Torrent Green Energy commissioned 322 MWp solar projects in Nashik district. These projects support Maharashtra’s Mukhyamantri Saur Krushi Vahini Yojana 2.0 scheme. Power from these plants will supply MSEDCL for twenty-five years. This initiative brings clean energy closer to agricultural demand centers.
SHOW MORE
Torrent Green Energy commissions 322 MWp of decentralised solar projects in Maharashtra under the Mukhyamantri Saur Krushi Vahini Yojana 2.0.
New Delhi: Torrent Power on Tuesday said its arm, Torrent Green Energy, has commissioned 322 MWp decentralised solar projects in Maharashtra under the Mukhyamantri Saur Krushi Vahini Yojana (MSKVY) 2.0.
The MSKVY 2.0 scheme was launched for the implementation of feeder-level solarisation under Component-C of the Pradhan Mantri Kisan Urja Suraksha Evam Utthan Mahabhiyan (PM-KUSUM) scheme. According to a company statement, Torrent Green Energy Pvt Ltd successfully commissioned 322 MWp of ground-mounted decentralised solar power projects across Nashik district, Maharashtra.
“This milestone reinforces Torrent’s commitment to supporting India’s clean energy transition while empowering the agricultural sector with reliable and sustainable daytime electricity supply,” said Jigish Mehta, Whole-Time Director of Torrent Power Ltd.
Power from the project will be supplied to Maharashtra State Electricity Distribution Company Limited (MSEDCL) under a 25-year power purchase agreement.
Aligned with the government of India’s agricultural solarisation and energy self-reliance goals, the project brings clean energy generation closer to agricultural demand centres.
Local solar plants powering rural feeders will ensure daytime electricity for farmers, enhance grid efficiency, reduce distribution losses and support sustainable agriculture.
The successful execution of this complex project required coordinated development across multiple locations, involving resolving land issues, grid connectivity, local clearances, engineering excellence, and simultaneous construction activities.
Developed across 50 locations and spanning 14 talukas of Nashik district, the company’s solar portfolio represents one of the most extensive and geographically diversified agricultural feeder solarisation projects implemented under the MSKVY framework, the statement added.
Torrent Power is the Rs 29,000 crore integrated power utility of the Rs 49,000 crore Torrent Group. Torrent Group is one of the largest companies in the country’s power sector with presence across the entire power value chain – generation, transmission and distribution.
show less
Tripura sets 500 MW green energy target by 2030
Agartala: Tripura has set a target of 500 MW renewable energy capacity by 2030, covering green energy projects and off-grid solutions, power minister Ratan Lal Nath said after launching Tripura Clean Energy Roadmap, Green Skilling Programme and TREAT Initiative here. Nath said renewable energy, particularly solar power, has become an essential catalyst for economic growth, technological innovation, job creation and sustainable development in the state.
SHOW MORE
Unnayan through Transformative Solar Applications (UTSA), an initiative by Tripura govt, is designed to develop skilled personnel for the growing solar industry. UTSA directly supports Tripura Energy Vision 2030 and 6Ds Clean Energy Road Map 2025-2035, focusing on cultivating solar PV skills for clean energy applications.
Tripura Renewable Energy Development Agency (TREDA), in partnership with Tripura Rural Livelihood Mission (TRLM) and Tripura State Electricity Corporation Limited (TSECL), is executing training programmes like Suryamitra and Solar PV Technician. Nath noted that these programmes are supported by the new and renewable energy ministry and align with an Asian Development Bank (ADB)-backed project to transform green energy in the state. Schemes including PM-KUSUM, PM-DevINE, PM Surya Ghar Muft Bijli Yojana, PM-JANMAN, Grameen Bazaar Alok Jyoti Prakalpa, solar micro-grids, green hydrogen, micro-hydel, hydrokinetics, pumped storage, battery storage and biogas projects are expanding clean energy access to farmers, households, public institutions and communities.
Tripura has achieved roughly 58.76 MW of renewable energy capacity. Under PM-KUSUM, solar pump installations have covered substantial agricultural land, with more planned. Solarisation of grid-connected pumps is generating power and cutting costs for farmers. Solar micro-grids are also delivering clean power to thousands of families under PM-DevINE and PM-JANMAN, earning praise from Prime Minister in his ‘Mann Ki Baat’ programme.
Tripura’s green energy drive has earned multiple honours, including recognition as the best-performing state among northeastern states for installing the highest number of solar pumps under PM-KUSUM, and SKOCH Power & Energy Silver Award 2025 for its solar micro-grid project.
show less
Gujarat emerges as India’s top state in green hydrogen hub potential: WRI India
Rajasthan ranked second in the resource assessment, buoyed by high scores in renewable energy resources and transmission capacity. Gujarat has emerged as India’s leading place for green hydrogen hub development, outperforming other states across both resource availability and consumption scenarios, according to a study released by WRI India.
SHOW MORE
The state’s commanding edge stems from a convergence of abundant renewable energy, power transmission networks, dependable water supplies, an established pipeline grid, and an active base of heavy industrial off-takers.
In the resource evaluation conducted by WRI India, renewable energy carried the highest weight at nearly 56 per cent, followed by water availability at 27 per cent and power transmission infrastructure at 17.1 per cent. Gujarat took the top position in both the existing and potential resource models, backed by operational solar and wind installations, high grid connectivity, and strong surface and groundwater access.
Rajasthan ranked second in the resource assessment, buoyed by high scores in renewable energy resources and transmission capacity.
However, WRI India noted that Rajasthan’s hub potential is bottlenecked by low water availability, which scores only a fraction of its power capabilities. Andhra Pradesh followed in third place with a balanced profile across renewable generation, grid connectivity, and water resources. Meanwhile, states such as Uttar Pradesh and Madhya Pradesh demonstrated exceptional transmission network scores, with Uttar Pradesh leading the country in power transmission coverage, yet both states lagged overall due to limited renewable energy capacity and the need for strategic water resource planning.
Maharashtra and Karnataka showed marked improvements once potential renewable generation was accounted for, with Maharashtra advancing to fourth place overall.
Under the National Green Hydrogen Mission, the central government has committed an outlay of ₹19,744 crore to scale domestic green hydrogen output to 5 million metric tonnes per annum by 2030. While roughly 11.7 million metric tonnes per annum of capacity has been identified under the mission, deployment on the ground remains in its infancy, with just 0.34 million metric tonnes, about 2 per cent, currently commissioned.
show less
Karnataka aims to boost power generation capacity to 66 GW by 2030
To efficiently manage this demand surge, Karnataka is among the first states to implement a ‘Resource Adequacy’ plan approved by the Central Electricity Authority (CEA) and the Karnataka Electricity Regulatory Commission. New Delhi: Karnataka is set to nearly double its installed power generation capacity over the next decade, reaching 66 gigawatts (GW) by 2030 from current 39 GW installed capacity, according to Gaurav Gupta, Additional Chief Secretary of the Energy Department.
SHOW MORE
Speaking at an event here on Thursday, Gupta said one-third of Karnataka’s electricity production already comes from hydropower and other renewable sources, and the state plans to further strengthen its renewable energy portfolio to support national renewable energy targets.
He emphasized that rapid industrial growth, the increasing adoption of electric vehicles, and the expansion of major data centers in Bangalore, Mysore, and Mangalore are expected to double Karnataka’s power demand in the next decade.
To efficiently manage this demand surge, Karnataka is among the first states to implement a ‘Resource Adequacy’ plan approved by the Central Electricity Authority (CEA) and the Karnataka Electricity Regulatory Commission. The state is also prioritizing grid stability and energy storage solutions, he said.
A key project underway is the 2,000 MW Sharavathi pumped storage project. Additionally, large-scale Battery Energy Storage Systems (BESS) are being installed at major substations managed by Karnataka Power Transmission Corporation Limited (KPTCL) to ensure consistent grid performance.
The Pavagada Solar Park, one of the largest solar parks in Asia, is being expanded, alongside increased wind power capacity. Agricultural solarization initiatives like the PM KUSUM-C and the Chief Minister Solar Agriculture Scheme are encouraging farmers to adopt solar power, further supporting the renewable push.
On the transmission front, KPTCL reported transmission losses of less than 3 percent and is actively constructing thousands of kilometers of new transmission lines and super-grid substations to handle the rising power flow.
To attract investments, the state government is facilitating private sector participation in energy storage and transmission projects, aiming to bring in Rs 2 to Rs 3 lakh crore over the next four to five years. Efforts to simplify land acquisition and regulatory approvals through digitalization are expected to ease project implementation.
Divya Prabhu G R J, Managing Director of the Clean Renewable Energy Development Corporation of Karnataka (CREDL), underscored Karnataka’s commitment to supporting the national vision of a developed India by 2047 by focusing on renewable energy expansion. She noted that comprehensive renewable energy project mapping and a unified digital platform for investors are streamlining investment decisions across the state.
show less
Karnataka aims to boost power generation capacity to 66 GW by 2030
To efficiently manage this demand surge, Karnataka is among the first states to implement a ‘Resource Adequacy’ plan approved by the Central Electricity Authority (CEA) and the Karnataka Electricity Regulatory Commission. New Delhi: Karnataka is set to nearly double its installed power generation capacity over the next decade, reaching 66 gigawatts (GW) by 2030 from current 39 GW installed capacity, according to Gaurav Gupta, Additional Chief Secretary of the Energy Department.
SHOW MORE
Speaking at an event here on Thursday, Gupta said one-third of Karnataka’s electricity production already comes from hydropower and other renewable sources, and the state plans to further strengthen its renewable energy portfolio to support national renewable energy targets.
He emphasized that rapid industrial growth, the increasing adoption of electric vehicles, and the expansion of major data centers in Bangalore, Mysore, and Mangalore are expected to double Karnataka’s power demand in the next decade.
To efficiently manage this demand surge, Karnataka is among the first states to implement a ‘Resource Adequacy’ plan approved by the Central Electricity Authority (CEA) and the Karnataka Electricity Regulatory Commission. The state is also prioritizing grid stability and energy storage solutions, he said.
A key project underway is the 2,000 MW Sharavathi pumped storage project. Additionally, large-scale Battery Energy Storage Systems (BESS) are being installed at major substations managed by Karnataka Power Transmission Corporation Limited (KPTCL) to ensure consistent grid performance.
The Pavagada Solar Park, one of the largest solar parks in Asia, is being expanded, alongside increased wind power capacity. Agricultural solarization initiatives like the PM KUSUM-C and the Chief Minister Solar Agriculture Scheme are encouraging farmers to adopt solar power, further supporting the renewable push.
On the transmission front, KPTCL reported transmission losses of less than 3 percent and is actively constructing thousands of kilometers of new transmission lines and super-grid substations to handle the rising power flow.
To attract investments, the state government is facilitating private sector participation in energy storage and transmission projects, aiming to bring in Rs 2 to Rs 3 lakh crore over the next four to five years. Efforts to simplify land acquisition and regulatory approvals through digitalization are expected to ease project implementation.
Divya Prabhu G R J, Managing Director of the Clean Renewable Energy Development Corporation of Karnataka (CREDL), underscored Karnataka’s commitment to supporting the national vision of a developed India by 2047 by focusing on renewable energy expansion. She noted that comprehensive renewable energy project mapping and a unified digital platform for investors are streamlining investment decisions across the state.
show less
INTERNATIONAL NEWS
Natural Gas / Transnational Pipelines/ Others
US: Shell Acquires PJM Gas Power Plant
Shell PLC has agreed to acquire a 169-megawatt (MW) natural gas-fired power plant in Pennsylvania, while selling a 609-MW combined-cycle gas power plant in New England.
“These transactions reflect our dynamic approach to managing our trading portfolio”, Shell president for trading and supply Andrew Smith said in an online statement Thursday. “We selectively invest in assets that strengthen our market position and create value, while remaining ready to realize value when market conditions present attractive opportunities”.
SHOW MORE
Shell will acquire Hunlock Creek Generating LLC, which owns the plant in Pennsylvania, one of 13 states in the PJM power market. Hunlock is owned by Riverview Power Holdings LLC, part of Castleton Commodities International LLC.
“The acquisition secures supply and capacity offtake for SENA in the Mid-Atlantic power grid operated by PJM Interconnection, the largest wholesale electricity market and grid operator in the USA”, Shell said, referring to its subsidiary Shell Energy North America (U.S.) LP.
“SENA’s focus is on power markets where it can play to its strengths, including trading and optimization, backed by increased access to battery energy storage systems and flexible power plants”, the British energy giant said.
Hunlock also owns a two-unit, 125-MW combined-cycle power plant and a 44-MW simple-cycle peaking plant, Shell noted. It did not disclose the purchase price.
In the other transaction, Constellation Energy Generation LLC will acquire RISEC Holdings LLC from Shell for $715 million. RISEC owns the Rhode Island State Energy Center, a two-unit combined-cycle gas turbine facility that generates up to 609 MW for the ISO New England wholesale electricity market.
“SENA’s earlier acquisition of RISEC ensured continued access to the plant’s capacity and associated trading opportunities in the market, enabling SENA to deliver substantial value as part of its asset-backed trading portfolio. With this transaction, SENA will bring forward the return it expected to generate from its longer-term ownership through a significant gain on the sale”, Shell explained.
Constellation said separately RISEC will grow its merchant generation portfolio.
“As Constellation’s business in New England grows, we need a reliable asset that is well-positioned on both the electric grid and the natural gas pipeline system”, said Constellation chair, president and chief executive Joe Dominguez.
Earlier Shell signed an agreement to divest its four-gigawatt (GW) portfolio of mostly in-the-pipeline onshore renewable energy (RE) projects in Europe to TotalEnergies SE.
The dispositions, whose price was not disclosed, include 500 MW of solar and wind in operation or under construction, mainly in Italy and the Netherlands. The 3.5-GW pipeline consists of battery storage, solar and wind projects in Italy, Spain and the United Kingdom, according to TotalEnergies’s announcement of the deal August 3.
“This transaction complements TotalEnergies’ power generation activities in these four key markets for the deployment of its Integrated Power strategy in Europe, in particular its European renewables asset portfolio, which amounts to nearly 10 GW of gross installed capacity or capacity under construction and 27 GW under development”, TotalEnergies said.
Shell said separately the sale will allow it to prioritize investment in “areas where it has differentiated capabilities in power, including asset-backed trading, increasing access to flexible generation capacity and customer-focused energy solutions while remaining disciplined on capital allocation and returns”.
Shell and TotalEnergies expect to complete the transaction by yearend, subject to government approval.
Last July it executed an agreement to sell Solenergi Power Private Ltd, which supplies solar and wind power to utilities in India, to Aditya Birla Renewables Ltd for $1.8 billion.
The sale consists of 3.3 GW peak operating and 1.7 GWp contracted, Shell said July 13. It expects to complete the transaction by yearend subject to closing conditions including regulatory approval.
https://www.rigzone.com/news/shell_acquires_pjm_gas_power_plant-11-sep-2026-184601-article/
show less
UK to approve Jackdaw gas field development this month, Times reports
LONDON, Sept 4 (Reuters) – Britain is expected to give approval on September 15 to bring the Jackdaw gas field online, ending years of legal delays, The Times newspaper reported on Friday, citing government sources. The decision on the field, which is operated by a joint venture between energy giants Shell (SHEL.L), and Norway’s Equinor (EQNR.OL),, has become increasingly significant for Prime Minister Andy Burnham since he took office in July.
SHOW MORE
Rising energy prices are affecting consumers and businesses, hitting Britain’s economy, and U.S. President Donald Trump has publicly urged Burnham to drill the country’s North Sea basin to help lower costs.
A spokesperson for the government’s energy department said they would not comment on speculation but added that the North Sea “remains a vital national asset”.
BURNHAM PROMISES A PRAGMATIC APPROACH
Burnham has said he wants to be pragmatic when asked about energy, adding that while oil and gas will remain part of the mix for decades, he is also committed to his party’s policy of shifting to clean energy sources.
The previous British government approved Jackdaw in 2022, but climate activists launched a legal challenge against it and Rosebank, an oil and gas field. A 2025 ruling blocked the operators from extracting oil or gas until further government consent was granted.
Adura, the Shell and Equinor joint venture developing both projects, has since reapplied for government approval. In the meantime, some work on the field has continued and much of the infrastructure needed to produce gas has already been built, meaning it could start producing this winter if approved.
ANNOUNCEMENT DUE IN ABERDEEN
The Times said Burnham was expected to announce the Jackdaw decision during a visit to Aberdeen in Scotland where he would also announce investment in renewable energy.
Friends of the Earth said approving Jackdaw would be “a staggering step backwards”.
The Times said on X that an expansion of Rosebank was considered very unlikely to receive approval, citing government sources, but a decision will not be announced until a later date.
North Sea fossil fuel production has declined sharply since its peak in the late 1990s.
Jackdaw will have a peak production of 40,000 barrels of oil equivalent per day of natural gas, an Adura spokesperson has said.
Rosebank would have peak production of around 70,000 barrels per day of mainly oil if approved.
Neither field is large. In the Norwegian North Sea, the Johan Sverdrup field produces more than 10 times Rosebank’s projected daily output.
The opposition Conservative party has argued in favour of developing the basin’s resources in the interests of energy security, while unions have also called on Burnham to approve the projects to help boost energy jobs.
Jackdaw lies about 150 miles (241 km) off the coast of Aberdeen and could contribute around 6% to British gas supply.
Adura said developing both Jackdaw and Rosebank, in which Ithaca Energy (ITH.L), holds a stake, would generate £1.4 billion ($1.9 billion) in tax revenues by 2029.
show less
Korea Picks $22 Billion Gas Project as First in US Trade Deal
South Korea has identified a gas-fired power project in Texas as the first US investment under a trade deal agreed last year, local media reported, a step that could help ease tensions between the two allies after months of friction over the pace of progress related to Seoul’s commitments..
The project in Encinal, Texas, with an investment of around $22 billion, would have a total capacity of 6.3 gigawatts and would start with 1.4 GW of gas-turbine generation before adding 4.9 GW of combined-cycle capacity, Yonhap News and other Korean media outlets reported. It would help meet surging electricity demand from artificial-intelligence data centers.
SHOW MORE
The South Korean government has refrained from disclosing details of projects and said on Monday it won’t announce anything until it finishes a process that includes reporting to the National Assembly. Media reports said the administration will brief parliament on the investment negotiations on Sept. 17 and may sign on MOU as soon as Sept. 18.
The expected signing of the deal comes nearly a year after the two countries struck an initial trade deal that set US toriffs on South Korean exports at 15%. Seoul pledged to invest $350 billion in the US as part of the agreement, but delays in identifying the first project drew criticism from President Donald Trump, who threatened to reise tariffs on Korean goods to as high as 25%.
In the short term, the project could be “something tangible” to diffuse a point of tension in the alliance. by eliminating one of the Trump administration’s talking points, said Mason Richey, a professor of International relations at Hankuk University of Foreign Studies.
The selection marks an important step toward turning Secul’s headline investment pledge into actual projects and could therefore remove a persistent source of friction with Washington. But won’t result in larger structural changes and Trump will “come back for another bite of the apple,” Richey added. In a last-minute twist, the US had asked South Korea to submitinvestment projects whose combined value exceeds the previously agreed $350 billion, Yonhap reported, citing unidentified parliamentary officials. Seoul is in talks with the US to ensure its actual commitment doesn’t exceed $350 billion, the report added.
South Korea denied that part of the Yonhap report.
“It is not true that the US side has requested investments exceeding $350 billion,” South Korea’s Industry Ministry said in a statement late Tuesday. “Under the strategic Investment MOU, total investment in the US will not exceed $200 billion under any circumstances, and the annual remittance. limit will not exceed $20 billion.”
It added that the scale and timing of the initial remittance have not been confirmed.
Other investment proposals South Korea is considering include eight large nuclear reactors and an Alaska LNG project, Yonhap added.
South Korea’s investment pledge mirrors a similar commitment by neighboring Japan to avert higher US tariffs, though Tokyo has moved more quickly to put its $550 billion plan into action. Japan’s first batch of projects envisages $36 billion of investment in US oil, gas and critical-minerals projects, including a natural gas facility in Ohio.
A second group calls for $73 billion in investment in a nuclear power project spanning Tennessee and Alabama and natural gas power plants in Pennsylvania and Texas.
The Industry Ministry statement said that while South Korea and the US are engaged in various discussions regarding cooperation on nuclear power plant investments, no specific details have been determined.
South Korea’s parliament approved special legislation in March to implement the US investment commitment, hours after the Trump administration sought new legal grounds to impose tariffs on Seoul.
show less
Iran: South Pars Phase 11 on verge of producing 1b cubic feet of gas
TEHRAN- South Pars Phase 11 has witnessed a significant production surge and simultaneous developmental progress during the 14th government. Production at Location B, which stood at around 400 million cubic feet per day during the 12th and 13th governments, has now exceeded 915 million cubic feet per day in the 14th government. According to the schedule, with the connection of the 12th well in the coming weeks, it will reach maximum production of 1 billion cubic feet per day.
SHOW MORE
At Location A, the 4,000-ton jacket has been installed offshore, and the construction progress of the topside, which was about 4% at the start of the 14th government, has now reached nearly 50%.
According to IRNA, quoting the Oil Ministry, South Pars Phase 11 is considered one of the country’s key gas development projects due to its location in the border section of the shared South Pars field.
The development of this phase was pursued in previous years with the presence of companies such as Total and CNPC, but the withdrawal of these companies following sanctions affected the project’s progress. Subsequently, the phase’s development continued relying on the capabilities of Iranian companies, with the Petropars Group, a subsidiary of the National Iranian Oil Company, taking over the project’s execution.
During the 12th and 13th governments, Location B produced approximately 400 million cubic feet per day using the Phase 12D jacket and a platform transferred from Location 12C. In the 14th government, with continued drilling, well completions, and their gradual connection to existing facilities, production at this location has reached over 915 million cubic feet per day. According to the project schedule, with the connection of the 12th well in the coming weeks, production will reach 1 billion cubic feet per day—the maximum production capacity of Location B.
Simultaneously, the development of Location A has also followed a remarkable trajectory. At the start of the 14th government, the jacket for this location had about 35% progress and had not yet reached the uprighting stage, while topside construction was in its early phases with about 4% progress. Now, the jacket, weighing approximately 4,000 tons, has been installed at its offshore site, and topside construction progress during the 14th government has risen from about 4% to nearly 50%. Over 700 meters of piling have been completed for the jacket installation.
The advancement of this section of the project was carried out under conditions where Phase 11 faced sanctions-related restrictions, regional threats, and security challenges. During the 40-day “Third Imposed War” [referring to recent conflicts], the contractor’s site for the 11A topside construction was struck by several rockets, but construction operations did not halt, and the project’s execution continued.
On the topside front, in addition to physical construction progress, a significant portion of the project’s procurement items—especially long-lead equipment—has been finalized. These equipment pieces are currently being manufactured, tested, and transported to the contractor’s site to prepare the topside for final stages.
According to the execution plan, topside progress will reach approximately 80% at the time of load-out, and after transportation, installation, and offshore commissioning, Location A will enter the production phase.
Initial production at this location will begin with 4 to 6 wells, and drilling of subsequent wells will continue in phases. The project estimates that on average, one new production well will come online every four months, with drilling continuing for about three years until the platform’s nominal capacity is fully achieved.
South Pars Phase 11 is part of the Petropars Group’s track record in developing South Pars. Petropars has been involved in a significant portion of this field’s development projects both onshore and offshore, with over half of the development plans for the South Pars gas field’s phases in coastal and offshore sections carried out by this group.
What has been achieved in Phase 11 during the 14th government can be summarized in three main indicators: increasing production at Location B from about 400 million cubic feet per day during the 12th and 13th governments to over 915 million cubic feet per day in the 14th government, moving toward maximum production of 1 billion cubic feet with the connection of the 12th well; installing the 4,000-ton jacket at Location A; and advancing topside construction progress during the 14th government from about 4% to nearly 50%. This trajectory, alongside continued drilling and well completions, will increase Phase 11’s production capacity in the coming years.
The South Pars gas field is a supergiant natural gas accumulation located in the Persian Gulf, shared between Iran and Qatar. It is the world’s single largest gas accumulation with over 2,000 trillion cubic feet (tcf) of recoverable resources. The field is being developed in 24 phases, and it is the foundation of Iran’s energy supply, providing approximately 70-80% of the country’s domestic gas needs.
Phase 11 is the last undeveloped phase of this shared field and is strategically important due to its location on the maritime border. Initially, a $4.8 billion contract was signed in 2017 with a consortium led by France’s Total and China’s CNPC, but both companies withdrew following the re-imposition of US sanctions, leaving Iran’s domestic company, Petropars, to execute the project.
The development of Phase 11 has seen significant progress recently.
show less
Russia: Putin Rebrands Planned China Gas Pipeline to ‘Power of Baikal’ Amid Stalled Price Talks
Russian President Vladimir Putin has officially renamed the long-planned “Power of Siberia 2” natural gas pipeline to China, rebranding the strategic infrastructure project as the “Power of Baikal,” Russia’s Energy Minister Sergei Tsivilev announced Wednesday. Speaking at the Eastern Economic Forum in the Pacific port city of Vladivostok, Tsivilev said project officials are entering the final preparations to begin physical construction on the energy corridor.
SHOW MORE
“We are in the final stages of moving to the construction of the project formerly known as Power of Siberia 2, but thanks to Vladimir Vladimirovich (Putin), he named it, quite literally, Power of Baikal,” Tsivilev told attendees at the summit.
The massive infrastructure enterprise spans approximately 2,600 kilometers (1,616 miles) and is designed to transport up to 50 billion cubic meters of natural gas annually.
The pipeline will originate in the Arctic gas fields of Yamal, cross Mongolia, and deliver fuel directly to Chinese markets.
Once operational, the supply line will complement the existing Power of Siberia 1 pipeline, an established route that supplied 38 billion cubic meters of Russian natural gas to China last year.
Despite official statements signaling an impending move to the construction phase, the mega-project has experienced extensive delays over the years due to prolonged negotiations regarding pricing terms between Moscow and Beijing.
Addressing pricing structures, Putin previously noted that the valuation of the gas delivered via the link would rely on a standardized market formula akin to the pricing mechanism Russia historically utilized for calculating energy shipments to European buyers.
Tsivilev provided no immediate clarification on whether the president’s renaming directive accompanied any structural, technical, or financial modifications to the energy pipeline project.
show less
Jordan Approves Gas Supply to Lebanon via Syria
Jordan’s Council of Ministers approved the agreements needed to supply Lebanon with natural gas through Jordanian infrastructure and Syrian territory, the official Jordan News Agency, Petra, reported on September 7. According to the agency, Jordan will import the gas and convert it from its liquid state into gas using existing infrastructure in the kingdom, including the shore-based gas unit and transmission lines extending from the south of the country to the north, before sending it to Lebanon in cooperation with the Syrian side.
SHOW MORE
Lebanon will receive the gas through the floating vessel at the Port of Aqaba, and the gas is expected to be used as an energy source for electricity generation.
The move builds on an existing supply mechanism between Jordan and Syria. The Jordanian government said the kingdom has been supplying Syria with gas since the beginning of 2026, and that supplies allocated to Lebanon will follow the same mechanism through Syrian territory.
The step also comes as Lebanon’s electricity crisis worsens, again highlighting Syria’s potential role in securing new energy sources by using its geographic position as a link between countries in the region.
Syria has also emerged as a potential route for transmitting electricity from Turkey to Lebanon, as part of proposals that examined supplying Beirut with electricity through Syrian territory amid Lebanon’s ongoing power crisis.
Abdul Rahman Mohammad, a professor of finance and banking at the Faculty of Economics at the University of Hama, said the project to supply Lebanon with energy through Syrian territory, with gas from Jordan and electricity directly from Turkey, goes beyond being a technical solution to Lebanon’s electricity crisis. He said it represents a genuine test of Syria’s ability to redefine its geopolitical and economic role after years of isolation.
Speaking to Enab Baladi, Mohammad said the scenario could give Syria an important economic and diplomatic role and turn its geographic position into a source of strength in the regional energy market. However, he stressed that Syria must not remain merely a transit corridor for electricity, and that project revenues should instead be transformed into real investments that increase production capacity and improve the country’s domestic electricity grid.
Gas Exchange Agreement Among Syria, Lebanon and Jordan
Jordanian Minister of Energy and Mineral Resources Saleh al-Kharabsheh announced in May that an agreement had been reached on cooperation in gas exchange among Syria, Jordan, and Lebanon.
The announcement came after technical preparations were completed, contracts were concluded, and studies were conducted to repair gas transmission networks, al-Kharabsheh said during a press conference with his Syrian counterpart, Mohammad al-Bashir, and Lebanese counterpart, Joseph Saddi.
Syrian Energy Minister Mohammad al-Bashir said progress was being made on projects to transport gas to Lebanon through Syria, contributing to increased electricity production and improved energy supplies in Lebanon. He noted that energy cooperation with Jordan began from the first day after the overthrow of the Assad regime.
The Jordanian energy minister said the meetings discussed ways to develop gas exchange projects and make use of existing infrastructure, in addition to strengthening electricity interconnection.
He explained that Jordan’s role in the agreement involves using its infrastructure to import liquefied natural gas, convert it back into gaseous form, and then pump it to Syria through the Arab Gas Pipeline.
Lebanon’s minister of energy and water said the importance of electricity interconnection and natural gas projects lies in securing reliable energy sources at a lower cost.
https://english.enabbaladi.net/archives/2026/09/jordan-approves-gas-supply-to-lebanon-via-syria/
show less
Natural Gas / LNG Utilization / Bio-LNG
Kuwait: Al-Zour facilities play a key role in LNG imports, supply system
KUWAIT: The ministry of oil affirmed that the Al-Zour LNG import facilities play an important role in Kuwait’s energy supply system, with their operational capabilities providing the flexibility needed for supplies and supporting the continued provision of fuel to electricity and water plants, particularly during the summer months when demand rises sharply.
SHOW MORE
This came in remarks by Director of Public Relations and Petroleum Media at the Ministry of Oil, Sheikha Tamader Khaled Al-Ahmad Al-Sabah, during a panel discussion organized by the ministry on Wednesday titled “Importing LNG to Meet the Needs of Electricity Plants During the Summer Peak and the Role of Al-Zour Facilities in Meeting Rising Natural Gas Demand in Kuwait.”
Sheikha Tamader said the importance of the Al-Zour facilities stems from the integration of their operational system, beginning with receiving LNG supplies from global markets and providing strategic storage capacity, through regasification, and finally pumping the gas according to the requirements of the consumer network.
She said this supports supply reliability and strengthens the ability to respond to the requirements of the summer peak season. She added that the ministry of oil is keen to support energy-sector projects and initiatives that contribute to meeting the country’s needs and keeping pace with development requirements. She noted that the Al-Zour facilities demonstrate the importance of energy infrastructure in connecting LNG supplies from global markets with domestic market needs, serving the requirements of electricity and water plants and supporting the flexibility of the supply system.
Kuwait National Petroleum Company (KNPC) Gas Group Operations Team Head Abdullah Al-Ajmi and KNPC Operations Department Head Salah Behzad gave a presentation on the role played by the Al-Zour LNG import facilities in meeting energy requirements during the summer peak. Al-Ajmi and Behzad explained that the facilities operate as a strategic system supporting continuous fuel supplies to electricity and water plants and enhancing supply flexibility by providing a flexible global source of natural gas and strategic reserves that increase the reliability of the consumer network.
They reviewed the operational capabilities of the Al-Zour facilities, which include eight LNG tanks, each with a capacity of 225,000 cubic meters, bringing total storage capacity to 1.8 million cubic meters. The facilities have an annual receiving capacity of 22 million tons and a supply capacity of 3,000 billion British thermal units.
They said these capacities enable the Al-Zour facilities to support domestic supplies for up to 12 days without receiving incoming shipments, based on the design and operational basis at maximum capacity. They explained that the Al-Zour LNG import facilities constitute a vital link between global LNG supplies and the needs of the national gas network during periods of high demand. The process begins with LNG carriers arriving from global markets, followed by reception at marine berths and through the unloading system. The gas is then stored in high-capacity refrigerated tanks before the LNG is converted back into natural gas through regasification and subsequently supplied to the consumer network and electricity plants.
Regarding the panel’s focus on the “summer peak challenge,” Al-Ajmi and Behzad said fuel reliability for electricity and water plants is a key element of preparedness, as summer brings a sharp increase in electricity and water demand, raising the importance of stable gas supplies in supporting service continuity.They added that these requirements are addressed through flexibility in receiving global shipments according to market needs, maintaining reserves based on strategic storage capacity capable of absorbing supply fluctuations, and responding rapidly by immediately increasing or reducing gas deliveries in line with the requirements of the consumer network.
Regarding key operational indicators and achievements recorded through 2026, the two officials said the Al-Zour facilities had received 445 LNG carriers and taken in the equivalent of 67 million cubic meters of LNG, while the volume of gas delivered amounted to approximately 1.263 million standard cubic feet. They said the facilities also reduced greenhouse gas emissions by approximately 8,000 tons through nitrogen gas injection, in addition to implementing a gas re-liquefaction project.
They stressed that the Al-Zour LNG import facilities constitute a key pillar in strengthening the security and flexibility of Kuwait’s energy supplies, particularly during periods of peak summer demand, supported by reliable supply, operational flexibility and the ability to meet the needs of electricity and water plants. — KUNA
show less
\
Saudi Arab: Energy Ministry, MODON sign MoU to establish natural gas compression plant in Dammam
The Ministry of Energy signed a memorandum of understanding (MoU) with the Saudi Authority for Industrial Cities and Technology Zones (MODON) on Sept. 6 to establish a natural gas compression and tanker distribution plant at the Third Industrial City in Dammam. The ministry was represented by Assistant Minister for Development and Excellence Ahmed Al-Zahrani, while MODON was represented by its CEO Majed Al-Argoubi, the Saudi Press Agency (SPA) reported.
SHOW MORE
The MoU aims to provide compressed natural gas services to the First Industrial City in Dammam, the First Industrial City in Al-Ahsa, and nearby factories through tankers that will distribute compressed gas to targeted industrial facilities.
The MoU is expected to enhance the efficiency and reliability of natural gas supplies and support the energy needs of the industrial sector.
https://www.argaam.com/en/article/articledetail/id/1934502?amp
show less
German: Nikkiso to provide pumps for German LNG import terminal
Nikkiso Clean Energy & Industrial Gases Group (Nikkiso CE&IG) has secured a contract with CS Gas North to provide 16 submerged motor pumps for German LNG Terminal in Brunsbüttel. Nikkiso CE&IG is manufacturing high-pressure, low-pressure, and ship-loading pumps for the project, which is being built by German LNG Terminal GmbH and scheduled to be operational in 2027.
SHOW MORE
The terminal includes two LNG tanks, each with a capacity of 165 000 m3, and will have the capacity to send 10 billion m3/y of gas into Germany’s national grid once operational. The project is built around infrastructure for LNG, bio-LNG, and synthetic natural gas (SNG), but is also designed to enable the transition to even lower-carbon fuel alternatives like hydrogen in the future.
Nikkiso CE&IG has been contracted by the lead EPC contractor, CS Gas North S.L., to provide the pumps for the project.
Ole Skatka-Jensen, Regional Vice President for Europe, Middle East and Africa at Nikkiso CE&IG, said: “The German LNG Terminal is a crucial part of Germany’s energy future thanks to the supply of LNG and green gases, as well as preparing for the future hydrogen economy.
“Both Nikkiso CE&IG’s presence and our contribution to major energy transition projects in Europe continues to grow. We have expertise in providing equipment and servicing support for not just LNG, but also hydrogen and ammonia, and we are proud to be part of such an important project for Germany and Europe’s move to these lower-carbon fuels.”
The award of the contract with CS Gas North S.L follows a similar contract for the Hanseatic Energy Hub in Stade, where Nikkiso CE&IG is supplying 20 low-pressure and nine high-pressure pumps for Germany’s largest land-based terminal for liquefied gases.
show less
Global LNG Development
Mexico: Shell to acquire stake in BP-operated Conifer prospect in Gulf of Mexico
Sept 2 (Reuters) – Shell Offshore, a subsidiary of British oil and gas major Shell (SHELL),, said on Wednesday it would acquire a 30% stake in the BP-operated (BP.L), Conifer exploration prospect in the Gulf of Mexico. Shell and BP are prioritising long-term growth in their oil and gas portfolios after years of investing heavily in renewables and other lower-carbon energy businesses.
SHOW MORE
The Reuters Power Up newsletter by columnist Ron Bousso provides everything you need to know about the global energy industry. Sign up here.
BP said in a separate statement that Shell would also acquire a 50% stake in the Tupinamba exploration block in Brazil’s Santos Basin. BP will retain the remaining 50% interest in Tupinamba and 70% in Conifer and continue as operator in both.
The Gulf of Mexico, which U.S. President Donald Trump has called on U.S. institutions to refer to as the Gulf of America under an executive order, is home to about 15% of U.S. crude oil production.
BP said earlier this year that its Brazilian Bumerangue discovery, described last year as its biggest in 25 years, holds 8 billion barrels of liquids, making Brazil a cornerstone of its upstream portfolio.
show less
Singapore: MOL Completes Unification of Ship Management Units
Mitsui OSK Lines Ltd has consummated the combination of six ship management subsidiaries to streamline safety culture. Singapore-based MOL Global Ship Management Pte Ltd (MOLGSM), previously named MOL LNG Ship Management Pte Ltd, is the surviving company to manage over 200 vessels across the Japanese group’s operations.
SHOW MORE
Besides MOL LNG Ship Management, the merged companies were MOL LNG Transport Co Ltd, MOL LNG Transport (Europe) Ltd, MOL Ship Management Co Ltd, MOL Ship Management (Singapore) Pte Ltd and MOL Tankship Management Pte Ltd.
“MOL will accelerate the implementation of safety measures across all vessel types, promote a unified safety culture, facilitate knowledge sharing and foster globally capable talent, by integrating the group’s six vessel management companies – which were previously organized by vessel type – into MOLGSM”, MOL said in a press release.
“The merger will also centralize safety and quality data and insights – which were previously dispersed across various locations – on a group-wide basis and enhance specialist capabilities across the organization, to respond to changes in the business environment, including geopolitical risks and increasingly stringent environmental regulations.
“In addition, MOLGSM will work to standardize and optimize operations through technologies such as AI and data analytics to enable rapid and advanced decision-making, while ensuring the safe implementation of new initiatives, including alternative-fuel vessels and other emerging technologies”.
MOL operates a global fleet carrying crude oil, liquefied petroleum gas (LPG), liquefied natural gas (LNG), ethane, chemicals and other products.
Its energy business – which includes tanker transport, LNG transport and FPSO contracts – contributed JPY 61.3 billion (around $390.81 million) in revenue and JPY 22 billion in ordinary profit for the three months ended June. The figures fell year-on-year from JPY 115.2 billion and JPY 15 billion respectively.
“In the crude oil tanker market, the vessel supply-demand balance tightened due to an increase in ton-miles resulting from alternative procurement of Middle Eastern cargoes and a decrease in effective vessel supply, following the deterioration of the situation in the Middle East and the de facto closure of the Strait of Hormuz”, MOL said in its financial report August 7. “Accordingly, market conditions remained above the level of the previous fiscal year.
“In the LPG carrier market, as in the crude oil tanker market, the vessel supply-demand balance tightened against the backdrop of an increase in ton-miles resulting from a shift in demand to North American cargoes following disruptions to loadings of Middle Eastern cargoes, as well as congestion in the Panama Canal. Accordingly, market conditions remained above the level of the previous fiscal year”.
“The FPSO business continued to secure stable profit from existing long-term charter contracts. In addition, the steady progress of FPSO construction projects at MODEC Inc, an equity-method affiliate, resulted in an increase in profit compared to the previous fiscal year”, it added.
show less
Abu Dhabi: Adnoc Keeps Loading LNG on Tankers Despite Hormuz Disruption
Abu Dhabi National Oil Co. appears to be continuing to load liquefied natural gas onto tankers in the Persian Gulf, according to satellite images, despite ongoing disruptions to energy flows through the Strait of Hormuz and a recent escalation of hostilities in the waterway.
A vessel was docked at the Das Island export facility on Sept. 2, with at least one other tanker spotted nearby, according to images taken by the Copernicus Sentinel-2 satellite. However, there are no tankers broadcasting their positions near the plant, ship-tracking data showed, suggesting they have switched off their transponders to avoid detection.
SHOW MORE
The United Arab Emirates’ state-owned company has proven adept at moving energy supplies through Hormuz to global customers, particularly crude, despite the persistent threat of attack. Satellite images have shown a number of ships docked at the facility over the past few months, indicating Adnoc has had at least some success transporting LNG out of the gulf.
Adnoc didn’t immediately respond to a request for comment.
A tanker docked at the Das Island LNG export plant in the Persian Gulf. Source: Copernicus Sentinel-2
The US and Iran renewed fighting this week after a period of relative calm, raising concerns about further disruptions to energy flows through Hormuz. US President Donald Trump said attacks on Iran would likely be short-lived, but warned that “we’re prepared to do another one any time we want.”
Even with the Adnoc cargoes, LNG exports out of the Persian Gulf remain far below pre-war levels of three shipments a day. Visible flows have been at an effective standstill since an Iranian attack on a Qatar-owned vessel in early July. Earlier this week, two oil supertankers were struck in the strait.
Qatar, the world’s second-largest LNG exporter lest year, has also periodically loaded tankers at its Res Laffan facility within the gulf. However, the country has largely stopped sending fuel through the narrow waterway due to safety concerns, with shipments delivered to Kuwait instead.
These LNG tankers are linked to Adnoc and haven’t sent a signal for at least five days. The green dot is Adnoc’s Das Island LNG export plant.
LNG tankers linked to Adnoc have stopped transmitting signals around Hormuz and within the Persian Gulf, according to ship-tracking data. Instead, vessels will stop near the eastern shore of the UAE, turn off their transponders and then travel dark through the strait to Das Island to collect a cargo. Tankers resume broadcasting once sefely outside the gulf.
Last month, an Adnoc-owned ship conducted a ship-to-ship transfer outside of Hormuz, a tactic to get more gas out of the Persian Gulf.
show less
Bangladesh: Novatek proposes $950m seabed-fixed LNG terminal
A new option for Bangladesh’s long-term LNG import infrastructure has been proposed, with Novatek Middle East presenting a $950 million gravity-based structure (GBS) as a cheaper and longer-lasting alternative to a conventional land-based LNG terminal. The company presented the concept to Petrobangla yesterday. The proposed facility would be built in the Bay of Bengal as a fixed offshore terminal for receiving, storing and regasifying imported LNG (liquefied natural gas), with a regasification capacity of 7.5 million tonnes per annum (MTPA).
SHOW MORE
According to Novatek’s presentation, the GBS would cost about $950 million, compared with an estimated $1.2 billion for a conventional 7.5-MTPA land-based terminal. This would make the offshore option about $250 million, or 21 percent, cheaper in initial capital costs.
However, the figures are based on the company’s own estimates and have not been independently verified. They have also not been compared with the government’s feasibility study for the planned 7.5-MTPA land-based LNG terminal at Matarbari.
The proposal remains at a very early stage, and Novatek has not yet submitted a formal proposal.
“It was a very preliminary-level presentation. We have learned from them. We would discuss it later with the higher-ups,” a top Petrobangla official told The Daily Star.
OFFSHORE STRUCTURE COULD OFFER LONGER LIFE
The main difference between the proposed GBS and a conventional LNG terminal is where the infrastructure is located.
A land-based terminal keeps LNG storage tanks and regasification facilities on the coast, with LNG carriers unloading through marine facilities. A GBS would instead place the storage and regasification facilities offshore on a large reinforced-concrete structure fixed to the seabed. The gas would then be sent to the national grid through a subsea pipeline.
Both systems perform the same basic functions: receiving LNG, storing it, converting it back into gas and supplying it to the gas network.
Novatek has identified deep-sea areas around Moheshkhali and Matarbari as possible locations.
The company estimates that a GBS could be built in 30 to 36 months and have a design life of 60 to 80 years. A conventional land-based terminal would take about 48 to 60 months to build and have a design life of 40 to 60 years.
An FSRU (floating storage and regasification unit), meanwhile, could be deployed in 24 to 30 months but would have a design life of only about 15 years, according to the presentation.
Bangladesh currently imports LNG through two FSRUs at Moheshkhali and plans to add a third. The government has also revived efforts to develop its long-delayed 7.5-MTPA land-based LNG terminal at Matarbari.
The GBS proposal could therefore offer another option as Bangladesh faces a persistent gas shortage, declining domestic gas production and growing dependence on imported LNG.
Recent disruptions at the country’s FSRUs have also exposed the vulnerability of LNG import facilities to technical problems and adverse weather. Reduced LNG send-out during such disruptions has further squeezed gas supplies to power plants and industries.
TWO DESIGNS AIM TO WITHSTAND SEVERE WEATHER
Novatek has proposed two GBS configurations. The larger one would have gross LNG storage capacity of about 290,000 cubic metres, while the smaller one would hold about 194,000 cubic metres.
Both would have 7.5 MTPA of regasification capacity, 1 MTPA of LNG bunkering capacity and 42MW of captive power generation capacity. The larger structure would also be capable of receiving the world’s largest LNG carriers, according to the presentation.
Weather resilience is one of the main advantages claimed for the technology. Novatek describes the GBS as a stationary, all-weather terminal with “very high” resistance to cyclones. FSRUs, by comparison, can face operational disruptions from strong winds, high waves and currents.
These claims, however, would need to be tested for the proposed site. The presentation itself calls for a detailed study of weather and marine conditions, including extreme winds, waves, storm surges, currents, seabed conditions and the safe berthing and transfer of LNG carriers.
The main GBS facility would not require coastal land, according to the proposal. Some onshore infrastructure would still be necessary, however, to connect the subsea gas pipeline to the national transmission network.
The technology draws on GBS structures developed by Russia’s Novatek, which has used large concrete gravity-based structures for its Arctic LNG 2 project.
The application in Bangladesh would be different. The Arctic LNG 2 structures house LNG production and liquefaction facilities, while the proposed Bangladesh facility would receive imported LNG, store it and convert it back into gas for domestic use.
‘Virtual pipeline’ and regional hub planned
The proposal also includes a second phase in which small, shallow-draft vessels would transport LNG from the offshore terminal to riverbank facilities near Meghnaghat, Ashuganj, Ghorashal and Bheramara.
Novatek calls this a “virtual pipeline” that could supply major gas-consuming areas without relying entirely on the existing pipeline network.
The idea comes as the government is also exploring the use of ISO tanks from Malaysia to transport LNG to gas-starved areas outside the main gas network.
ISO tanks would carry LNG in standardised cryogenic containers by road or other transport modes and would serve relatively small volumes. Novatek’s proposed system, in contrast, would move much larger volumes using dedicated LNG vessels to riverbank regasification facilities.
Novatek also sees the GBS becoming a regional LNG transhipment and bunkering hub. The presentation identifies potential shipments from Bangladesh to India, Pakistan, Sri Lanka, Vietnam, Malaysia and Indonesia using small and medium-sized LNG vessels.
Novatek has proposed an investment model based on foreign direct investment, but the presentation does not provide details on the commercial structure, tariffs, financing costs or expected investor returns.
show less
Israel’s $35B gas deal with Egypt moves ahead as key pipeline opens
Israel’s largest-ever gas deal has taken a significant step forward: NewMed Energy, controlled by Yitzhak Tshuva’s Delek Group and Idan Wells, announced that the undersea pipeline between Ashdod and Ashkelon has been completed, a project that will make it possible to increase the flow of natural gas from Israel to Egypt.
SHOW MORE
The project, carried out by Israel Natural Gas Lines, will increase by about 2 billion cubic meters a year the volume of gas that can be transported through the EMG pipeline, which connects Ashkelon to el-Arish in Egypt.
Following the completion of the work, transmission capacity in the pipeline will increase from about 6.5 billion cubic meters a year to about 8.5 billion cubic meters. Of that amount, the Leviathan gas field’s export capacity is expected to stand at about 6.5 billion cubic meters a year, in addition to about 2 billion cubic meters currently exported to Egypt via the export pipeline to Jordan and northern Egypt.
This marks the first stage in implementing the export agreement with Egypt signed in August, which is considered Israel’s largest energy export deal, worth about $35 billion.
The first stage included two major projects: connecting a third pipeline from the Leviathan reservoir to the production platform, which increased the field’s production capacity to about 15.8 billion cubic meters a year, and expanding the transmission system between Ashdod and Ashkelon, which has now been completed.
Following the fulfillment of the required conditions, the amount of gas the Leviathan partners are committed to supplying Egypt is expected to increase from about 4.7 billion cubic meters a year to about 6.7 billion cubic meters, an increase of about 40% compared with the amount currently exported.
“The completion of the Ashdod-Ashkelon transmission line project allows the largest export deal in the country’s history to get underway,” NewMed Energy CEO Yossi Abu said. “This opens up an important bottleneck in transmission to Egypt, enabling us to significantly increase volumes and save on transmission costs.”
According to Abu, increasing production from the Leviathan reservoir and advancing the next expansion phase will make it possible to meet growing demand in Israel and in export markets.
show less
Germany, UAE deepen energy cooperation with renewable, gas agreements
FRANKFURT, Sept 11 (Reuters) – Germany and the United Arab Emirates on Friday deepened their energy ties with a number of agreements covering renewables and natural gas, part of a broader investment of €40 billion ($46.4 billion) to support industry in Europe’s biggest economy. With a trade relationship worth around $15.5 billion a year, Germany and the UAE have been seeking closer relations to counter growing political uncertainty and disruption caused by the U.S.-Israeli war in Iran. RWE, Germany’s largest power producer, on Friday signed a memorandum of understanding with UAE state-backed renewable energy firm Masdar over a possible joint participation in German offshore wind auctions in 2027, covering potential investment of more than €3 billion.
SHOW MORE
RWE (RWEG.DE), opens new tab also signed a letter of intent with ADNOC (ADNOC.UL) on future supplies of liquefied natural gas, building on an initial framework agreement between the two parties in February.
“The UAE and Germany are building on decades of trusted partnership to advance economic growth and shared prosperity for the long-term,” Sultan al-Jaber, ADNOC CEO and the UAE’s Minister of Industry and Advanced Technology, said. Both parties plan to agree terms for up to two LNG offtake agreements to supply German as well as other European and Asian markets from the early 2030s. Any LNG volumes are to come from ADNOC Gas (ADNOCGAS.AD), opens new tab and ADNOC’s international arm XRG.
XRG, ADNOC, and German state-owned energy firm SEFE also signed an MoU to explore deeper cooperation in the fields of natural gas and LNG.
XRG’s chemicals chief Rainer Seele said he was interested in close ties with SEFE.
“We already have a broadly diversified LNG portfolio and will continue to invest in securing future LNG production. We wish to bring this expertise to a long-term partnership and agree on the next steps without delay,” he told Reuters.
Masdar and German energy infrastructure investment firm Luxcara also agreed to explore joint energy storage and offshore wind investments in Germany and other markets worth more than €5 billion.
Reporting by Christoph Steitz Editing by Miranda Murray, Louise Heavens and Barbara Lewi
show less
Israel: Energean signs $1.4 billion gas deal with new Sorek power plant
The agreement brings Energean’s contracted backlog in Israel to $20 billion over two decades and completes contracts with three major power projects expected to come online by the end of the decade. The company reported $160 million in first-half profit despite a 41-day production shutdown during the war with Iran.
SHOW MORE
LNG as a Marine Fuel/Shipping
Qatari, UAE LNG cargoes transferred via ship-to-ship outside Strait of Hormuz
SINGAPORE, Sept 2 (Reuters) – Three liquefied natural gas cargoes loaded in Qatar and the United Arab Emirates have been transferred between ships outside the Strait of Hormuz in recent weeks for delivery to India and Japan, according to ship-tracking firms. Several commercial vessels have faced attacks amid heightened tensions in the Strait of Hormuz key shipping route a since the U.S. and Israeli war on Iran broke out on February 28.
SHOW MORE
Most LNG tankers that have managed to transit the strait have delivered the cargoes directly to end-buyers. Unlike crude oil, ship-to-ship (STS) LNG transfers are unusual.
The LNG carrier GasLog Shanghai, which was involved in an incident while exiting the Strait of Hormuz, completed an STS transfer with GasLog Savannah in late August off the coast of Oman, according to Vortexa and Kpler.
An incident had occurred on the GasLog Shanghai LNG vessel on July 31 while exiting the Strait of Hormuz with cargo loaded at Qatar’s Ras Laffan export terminal.
Both GasLog Shanghai and GasLog Savannah are controlled by Greek shipping company GasLog. QatarEnergy and GasLog did not respond to requests for comment.
Iran has largely shut the Strait of Hormuz during the six-month conflict, disrupting energy supplies, driving up prices and fuelling wider inflation concerns.
LNG exports from the region have fallen since the conflict’s start, helping to push Asian spot LNG prices to a five-month high of $23.20 per million British thermal units (mmBtu), more than double the pre-conflict levels.
Additionally, the QatarEnergy-controlled Al Rekayyat tanker, which was hit by a projectile near the Strait of Hormuz in early July, conducted an STS transfer in mid-August on the east coast of the United Arab Emirates, Vortexa and Kpler data showed.
The Al Rekayyat conducted the ship-to-ship transfer with another Qatari LNG tanker, Tembek. The cargo, originally loaded at Ras Laffan, was subsequently delivered by Tembek to India’s Dahej terminal on August 31, Kpler data showed.
A third tanker – ADNOC-controlled Mraweh completed an STS transfer with LNG Enugu off the coast of Oman, outside the Hormuz strait, in mid-August, according to Vortexa and Kpler.
The Mraweh had loaded an LNG cargo from Das Island in early August before conducting the STS transfer with LNG Enugu. The LNG Enugu is currently en route to Futtsu, Japan, showed Kpler data.
ADNOC declined to comment. Shipping firm BW Group and Japanese trading house Marubeni, which both own LNG Enugu through a joint venture, did not respond to requests for comment.
show less
Germany’s Stade floating LNG terminal set for November commissioning cargo
The new floating LNG import terminal in Stade, Germany, will begin start-up operations in September, with a first commissioning cargo expected in November. The new floating liquefied natural gas (LNG) import terminal in Stade, Germany, will begin start-up operations in September, with a first commissioning cargo expected in November, its operator said on Thursday.
SHOW MORE
Stade will host Germany’s fifth floating LNG import terminal as part of a wider push to diversify supplies after Russian pipeline deliveries were cut off in 2022.
The Energos Force floating storage and regasification unit (FSRU) is expected in Stade in September as planned, commencing work to start up operations, a spokesperson for operator Deutsche Energy Terminal (DET) said.
“We expect the delivery of a first commissioning cargo in Stade in November,” the DET spokesperson said.
The company is also preparing the allocation of capacities at the terminal and will inform the market of any auctions in due course, he added.
The Energos Force had been sub-chartered to Egyptian oil and gas company EGAS and deployed in Jordan amid delays to the German project.
Germany has been slow to fill gas storage this summer, with filling levels last seen at 53.6%, and will rely on LNG imports to help meet gas demand this winter.
show less
US: Equinor receives first US Gulf Coast cargo
Equinor has taken delivery of its first LNG cargo under long-term supply agreements signed with Cheniere, the largest producer of LNG in the US. The cargo was loaded at Cheniere’s Sabine Pass LNG export facility in in Louisiana and is bound for Europe. Future deliveries will serve customers in Asia and Europe, based on market demand, demonstrating Equinor’s ability to connect reliable US energy supply with growing demand in global markets through its integrated LNG portfolio.
SHOW MORE
Under the 15-year agreements signed in 2022 and 2023, Cheniere’s Gulf Coast facilities will ultimately supply Equinor with around 3.5 million tpy of LNG. These volumes will allow Equinor to double its global LNG portfolio by 2030, strengthening the company’s ability to deliver reliable energy to customers while supporting energy security and economic development in key international markets.
“Today’s milestone further strengthens Equinor’s position as a reliable supplier of energy to customers around the world,” said Helle Østergaard Kristiansen, Senior Vice President for Gas and Power. “The US will play an increasingly important role in our global LNG portfolio, complementing the strength of our existing gas position and providing additional flexibility to serve customers in Europe and Asia.”
The Cheniere supply agreements are part of a wider effort to grow a diversified LNG business that offers energy security through long-term, reliable supply arrangements. As one of the world’s largest suppliers of natural gas, Equinor combines access to competitive gas resources, shipping capabilities, and global marketing and trading expertise to deliver energy where it is needed most.
“The US is a cornerstone of the global LNG market, with abundant natural gas resources, world-class infrastructure, and a growing role in meeting energy demand around the world,” added Chris Golden, US Country Manager and Senior Vice President Upstream US and Argentina. “This first cargo highlights how Equinor can connect reliable American energy supply with customers in global markets, while further strengthening our long-term position in the US.”
https://www.lngindustry.com/liquid-natural-gas/04092026/equinor-receives-first-us-gulf-coast-cargo/
show less
Technological Development for Cleaner and Greener Environment Hydrogen & Bio-Methane
Wales & West Utilities launches green hydrogen vehicle trial in Swansea
Wales & West Utilities (WWU) has launched a 12-week green hydrogen vehicle trial in Swansea toassess the potential of hydrogen fuel-cell technology as a zero-emission solution for commercial fleets, Wales247 reported. The gas emergency and pipeline services company is working with Ford and hydrogen technology specialists to test a prototype Ford Transit light commercial vehicle powered by a hydrogen fuel cell.
SHOW MORE
The trial is aimed at identifying low-carbon alternatives for parts of WWU’s fleet where batteryelectric vehicles currently face limitations related to payload, driving range, towing capacity and charging infrastructure. Green hydrogen for the trial is being produced and supplied by Protium Green Solutions. The vehicle will be refuelled at a facility supported by Fuel Cell Systems at the Hyppo Hydrogen Solutions site in Swansea. WWU operational staff will use the vehicle during their regular duties across Swansea and wider West Wales. The company will assess its range, refuelling requirements, payload capacity and operating costs under real-world conditions. The vehicle will use hydrogen refuelling at 700 bar, allowing it to operate with zero tailpipe emissions while providing the rapid refuelling capability required for commercial operations. Stephen Offley, Transport Lead for WWU’s Net Zero & Sustainability team, said the company operates around 1,300 vehicles across Wales and the south-west of England. Its fleet travelled more than 15 million miles in 2025 and consumed around 4.3 million litres of diesel. He said hydrogen could play an important role in decarbonising road transport and urged other organisations to consider the technology as they move away from fossil fuels.
The latest project builds on WWU’s previous hydrogen vehicle trial and is intended to assess whether fuel-cell technology can meet the operational requirements of light commercial vehicles used in sectors such as utilities and construction. The trial also highlights the potential role of green hydrogen in decarbonising commercial transport where vehicles operate long distances, carry heavy loads or require significant towing capacity. The project involves Ford, Protium Green Solutions, Fuel Cell Systems and Hyppo Hydrogen Solutions and is part of wider efforts in the UK to develop hydrogen vehicles and the refuelling infrastructure needed to support zero-emission commercial fleets.
https://bioenergytimes.com/wales-west-utilities-launches-green-hydrogen-vehicle-trial-in-swansea/
show less
Hydrogen trucking heavyweights target coordinated deployment push in Germany
A group of major truck makers, hydrogen producers, and infrastructure firms will launch a coordinated effort in Germany to tackle the cost and infrastructure barriers holding back hydrogen-powered heavy-duty transport. Volvo Group, Daimler Truck, Toyota, Bosch, Air Liquide, TotalEnergies, Teal Mobility, and MB Energy are the companies behind the initiative, which aims to synchronise hydrogen trucks, refuelling stations, and fuel supply.
SHOW MORE
The firms have yet to disclose planned truck and station numbers, hydrogen volumes, investment, or target fuel prices, with further details set to be revealed at a press conference during the IAA Transportation event in Hanover, Germany, on 15 September.
The companies are targeting large-scale deployment by 2030, with Germany intended to serve as a benchmark. The country is also currently assessing bids for an oversubscribed €220m ($255m) funding programme for up to 400 hydrogen trucks and up to 40 refuelling stations.
The initiative will also target competitively priced hydrogen and a total cost of ownership capable of making hydrogen trucks commercially attractive to fleet operators.
Previous assessments by coalition the Global Hydrogen Mobility Alliance (GHMA) – of which several of the above companies are members – claimed hydrogen trucking reaching cost parity with diesel would depend on hydrogen prices of €8/kg by 2030.
However, GHMA said that to achieve that price for dispensed hydrogen, early deployments could not be tied to the use of clean hydrogen.
The details of the new group’s activities will be closely watched by the hydrogen sector, as high fuel costs and uncertainty over vehicle demand have complicated the business case for investing in dedicated heavy-duty hydrogen transport.
The push comes despite continued doubts over the economics of hydrogen trucking, particularly compared with battery-electric alternatives.
David Cebon, Professor of Mechanical Engineering at Cambridge University, told a H2 View webinar earlier this year that it was “completely out of the question” for fleet operators to buy and run a hydrogen vehicle, citing the technology’s lower energy efficiency.
However, the initiative comes as several participants deepen their cooperation on hydrogen trucking.
Earlier this year, Toyota agreed to join Volvo and Daimler Trucks’ fuel cell-making joint venture Cellcentric.
Volvo and Daimler have also worked with TotalEnergies and Teal Mobility under the H2Accelerate coalition.
show less
eCap Marine to fit hydrogen propulsion on two new vessels
German maritime technology manufacturer eCap Marine will supply hydrogen fuel cell propulsion systems for two new 3,000 DWT carrier vessels. The ships, on order for Norway’s Green Maritime Infrastructure (GMI) group, will be built in India and equipped with eCap’s H2EPS power systems, according to industry reports.
SHOW MORE
Planned for operation by 2029, they will be constructed by Chowgule Shipyards and are intended for voyages mostly in Norwegian waters.
Each vessel’s H2EPS incorporates a 1.2MW PEM fuel cell system, converting stored compressed hydrogen into electricity to drive motors.
eCap is also supplying fuel cell propulsion systems for two Samskip short-sea vessels in the form of a 3.2MW H2Powerpack unit. In 2024, it retrofitted an offshore supply vessel with its hydrogen-electric system, receiving “first-class certification” from DNV.
Hydrogen’s role in the maritime sector faces questions, with operators of larger vessels turning to derivatives like ammonia and methanol, while smaller boats often adopt battery-electric propulsion.
The molecule and its derivatives are, however, widely expected to play a role in the maritime industry’s pursuit of decarbonisation.
The International Maritime Organisation’s current Net Zero framework plans to impose a carbon levy on ships above 5,000 tonnes from 2028, while the EU’s FuelEU Maritime regulation already sets carbon pricing for ships of this size using EU ports.
show less