NGS’ NG/LNG SNAPSHOT November 1-15, 2025
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NATIONAL NEWS
City Gas Distribution & Auto LPG
Five Kalyani houses first to get piped gas in state
Kolkata: Piped natural gas reached the Kolkata Metropolitan Development Authority (KMDA) area last week, with Bengal Gas Company Limited commencing PNG supply to households in Kalyani. The pipeline has to travel another 50 km to reach Baranagar, located on the northern fringes of Kolkata. This will enable the re-introduction of piped gas to homes in Kolkata after several decades. Greater Calcutta Gas Supply Corporation (GCGSC), the predecessor of Bengal Gas, used to supply piped gas to different parts of the city since the 1950s. It took over the operations of the Oriental Gas Company Ltd, which started providing gas to the city a century earlier in 1857. This gas was used to light street lights in Kolkata.
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The Bengal Gas Company Limited (BGCL), a joint venture between GAIL and the state-owned GCGSC, started the supply of PNG to five homes in Kalyani. Among them, Paromita Biswas, a resident of Ward 19 in Kalyani Municipality, got the first connection, when the line to her home was activated last Tuesday. Biswas said, “PNG is very convenient to use. Also, now that the cylinder is out, I have got some empty space in my kitchen.”
In Kolkata, BGCL started PNG supply to Uniworld and Rosedale complexes in New Town in Dec 2023 by carrying gas in cascade from Panagarh and then, flowing it into a pipeline infrastructure there to the kitchens. “But in Kalyani, we have laid a 6.3-km-long pipeline and started gas supply only through pipeline infrastructure. So, we can say the PNG supply has begun in a true sense. Our target is to supply PNG to 2,000 households in Kalyani in one year. We will also start PNG supply in Chandernagore, Debanandapur and Gayeshpur in three months, for which the pipeline work is in an advanced stage,” BGCL CEO Anupam Mukherjee said.
The company has installed gas meters in 5,425 households’ kitchens so far, of which 267 are in Kalyani. BGCL has installed gas meters in 385, 517, and 371 households’ kitchens in Chandernagore, Debanandapur, and Gayeshpur. “We have also installed meters in several households’ kitchens in Barasat, Barrackpore and New Barrackpore, but supplying gas there will take time as pipeline construction is underway,” Mukherjee said.
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Piped CNG To Flow Into Butibori Kitchens & Industry By Dec-End, Long Wait For Core City
Nagpur: With the Gas Authority of India Ltd (GAIL), Nagpur, preparing to begin compressed natural gas (CNG) supply soon, Haryana City Gas (HCG) — the authorised distributor for Nagpur district — is expected to start delivering piped natural gas to industries and residential pockets in Butibori by the end of December. Once operational, consumers across residential, commercial, and industrial categories are likely to benefit from 10% to 15% savings in fuel usage.
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Officials said the initiation of piped natural gas would be a major milestone for the district, introducing a cleaner, safer, and more reliable fuel supply system. HCG currently holds the licence to supply natural gas across Nagpur district, including city and rural areas.
Speaking to TOI, HCG, Nagpur, president (operations) Deepak Sawant said the process would commence shortly after GAIL begins feeding natural gas into HCG’s network. “We have already approached multiple industries in Butibori and 26 of them agreed to take natural gas connections. Also, residential areas, including Cidco colony, will be provided with natural gas,” Sawant said, adding that the pipeline-laying and connection work will be executed in phases.
HCG is set to invest around Rs1,000 crore to lay pipelines and extend domestic connections across the district, with an eight-year deadline to complete the project, including within city limits. “Out of the total cost, so far, we have spent around Rs250 crore. We have also carried out a survey. Initially, we will lay a 150-km long pipeline out of which 51-km has already been laid and further works are in process,” Sawant added.
After Butibori, the company plans to extend piped gas supply to Jamtha, Kothewada, Chinchbhuvan, Mihan, MIDC, and other peripheral areas. “The areas like Hinga, Wadi, Besa, Narendra Nagar, Manewada, and others will also start getting piped gas supply. Currently, we have started laying pipelines in the Hingna area, from there we will move towards Wadi,” Sawant said.
Sources indicated it may take four to five years for the network to penetrate core city areas. Officials also highlighted cost benefits for consumers and industries. HCG claims natural gas will be around 15% cheaper than LPG.
“It is safer and more reliable. The users will only have to pay for whatever they use rather than going through the process of ordering fuel cylinders and waiting for delivery. The industries will benefit on a large scale as currently around 25% of their space is used for stocking fuel, which is also a risk. The CNG pipeline would not only save space and money but also time for industries,” an official said.
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GAIL Set To Begin CNG Supply As Nagpur Pipeline Clears Testing
GAIL has completed the final round of testing for the 700 km Mumbai-Nagpur natural gas pipeline, marking a significant step towards supplying compressed natural gas (CNG) in Nagpur district. The development moves Vidarbha closer to reliable, safer and more economical natural gas access through a dedicated transmission network.
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Senior GAIL officials confirmed that all testing and cleaning procedures on the Nagpur stretch have been completed. According to sources, gas charging has already begun and gas has recently reached Nashik. Multiple tests, including cleaning, were carried out in Nagpur with pressure levels raised to around 140 kg to ensure safety, compared with the expected operating pressure of around 90 kg.
The Mumbai-Nagpur pipeline constitutes a key segment of the broader 1,700 km Mumbai-Nagpur-Jharsuguda natural gas grid, a Rs 80 billion infrastructure project spanning Maharashtra, Chhattisgarh, Madhya Pradesh and Odisha.
Officials overseeing the national gas grid noted that India requires nearly 210 million cubic metres of natural gas per day, with almost half of this volume sourced through imports from Gulf countries and other regions. They explained that gas reaches Mumbai from Dabhol in Ratnagiri, Dahej in Gujarat and Hazira Port near Surat, from where it will be transported onward to Nagpur and beyond through the pipeline.
Industry experts expect that the entry of piped gas in Vidarbha will support industrial expansion, lower logistics and fuel costs, and make operations more economical for small and medium enterprises. The availability of cleaner and cheaper energy is also likely to attract new manufacturing and ancillary investments.
Once gas flow begins, GAIL will supply CNG to Haryana Gas Company (HCG) Nagpur, the PNGRB-licensed local distributor. With testing now complete, the region is preparing for CNG supply to commence soon, reshaping Nagpur’s energy landscape.
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‘Indian City Gas Distribution Firms’ Operating Profit To Rise 12% This Fiscal’: Crisil Ratings
“Against the 30 per cent reduction in APM allocation for the CNG segment, CGD companies got 15-20 per cent long-term allocations from domestic new well gas, mainly towards the end of last fiscal or early this fiscal. For the balance, they have signed additional medium- and long-term contracts, mainly for HPHT gas and R-LNG,” said Ankit Hakhu, Director, Crisil Ratings.
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New Delhi: City gas distribution (CGD) companies in India are projected to clock an operating profit of Rs 7.2–7.5 per standard cubic metre (scm) this fiscal — up 8-12 per cent compared with the second half of last fiscal when margins dropped because of a sudden and steep decline in gas allocation under the administered price mechanism (APM) for the compressed natural gas (CNG) segment, a report said on Thursday.
Consequently, distributors had to take recourse to the spot gas market for supply, which exerted upward pressure on cost. The companies have, thereafter, transitioned to contracted supplies, which is expected to burnish margins. “Healthy earnings will keep leverage in check despite the proposed capital expenditure (capex) by companies.
Our assessment of seven CGD companies, with 70 per cent share of total sales volume last fiscal, indicates as much,” Crisil Ratings said in its report. CGD companies get gas on priority at lower prices under the APM from legacy gas fields to serve the domestic CNG and piped natural gas-domestic (PNG-D) segments. Beyond APM, they procure high-pressure, high-temperature (HPHT) gas and imported regasified liquefied natural gas (R-LNG) under contracted and spot purchase mechanisms.
According to the report, in the second half of the last fiscal, APM gas allocated to the CNG segment was reduced to less than 40 per cent of the total CNG requirement, compared with 70 per cent in the first half of the last fiscal. This led to a substantial increase in gas procurement costs as companies relied on spot purchases, which were 80-100 per cent more expensive than those under APM prices, to protect against supply disruptions. As a result, spot purchases by volume rose to more than 15 per cent of total supplies from 5 per cent in the first half of the last fiscal.
“Against the 30 per cent reduction in APM allocation for the CNG segment, CGD companies got 15-20 per cent long-term allocations from domestic new well gas, mainly towards the end of last fiscal or early this fiscal. For the balance, they have signed additional medium- and long-term contracts, mainly for HPHT gas and R-LNG,” said Ankit Hakhu, Director, Crisil Ratings. This will not only improve gas security but also reduce exposure to the spot market, where prices are 25-30 per cent higher on average, he added.
The report noted that realisations are steady this fiscal, following some increase in the second half of last fiscal when companies implemented price hikes to pass on increased costs to consumers, albeit partially and gradually. However, some of the benefits of reduced gas procurement costs in the current fiscal year will be offset by an increase in other operating costs. These costs will rise as players continue to incur capex to expand gas infrastructure in existing and new geographical areas (GAs) to support volume growth.
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Natural Gas/ Pipelines/ Company News
Final testing of 700km Mumbai–Nagpur natural gas pipeline completed
Nagpur: In a major infrastructure milestone for Vidarbha, the Gas Authority of India Limited (GAIL) has completed the final round of testing for the 700km Mumbai–Nagpur natural gas pipeline. It is preparing to begin compressed natural gas (CNG) supply to Nagpur district in the next few days. The development brings the region closer to reliable, safer, and more affordable natural gas access through a dedicated pipeline network.
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Senior officials from GAIL confirmed the progress, stating that the testing and cleaning procedures for the stretch passing through Nagpur were successfully completed. “The charging of the gas pipeline has started and the gas recently reached Nashik. Multiple testing, including cleaning, has been completed in Nagpur. The gas will soon be supplied by GAIL. The pressure of the gas in the pipeline will be around 90kg, so the testing was carried out with around 140kg pressure to ensure safety,” said sources.
The Mumbai–Nagpur pipeline forms a key component of the longer 1,700 km Mumbai–Nagpur–Jharsuguda (Odisha) natural gas grid, a Rs8,000-crore project being executed across four states — Maharashtra, Chhattisgarh, Madhya Pradesh, and Odisha. Maharashtra accounts for the largest share of the route, with nearly 970km of the pipeline laid within the state.
In addition to the main corridor, the project also encompasses a 310km spur line connecting Nagpur to Chhindwara and Jabalpur, expanding natural gas accessibility deeper into central India.
According to officials familiar with the national gas grid, India’s daily natural gas requirement stands at around 210 million cubic meters, with nearly half of the demand met through imports from the Gulf and other countries. “The gas reaches Mumbai from Dabhol in Ratnagiri, Dahej in Gujarat, and Hazira Port (near Surat). From Mumbai, the gas will be supplied to Nagpur and ahead via pipeline,” sources added.
Industry experts believe the arrival of piped natural gas in Vidarbha could significantly catalyse industrial growth, reduce fuel logistics challenges, and lower operational costs, especially for small and medium-scale industries. Cheaper, cleaner, and safer fuel availability is expected to make the region more attractive for investment in manufacturing and ancillary sectors.
Once operations begin, GAIL will supply CNG to Haryana Gas Company (HCG) Nagpur, which holds the Petroleum and Natural Gas Regulatory Board (PNGRB) licence for gas distribution in the district. With testing now complete, CNG supply to Nagpur is expected to start soon, marking a transformative step for the region’s energy landscape.
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IGL eyes Saudi Arabia for first overseas city gas venture
NEW DELHI: What’s good for Delhi seems to be good for Saudi Arabia. After helping the National Capital Region breathe easy by launching India’s first CNG (compressed natural gas) service in 1999, IGL (Indraprastha Gas Ltd) is poised to enter the Kingdom, becoming the first Indian city gas operator to venture overseas.
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The company, promoted by state-run oil companies and the Delhi government, on Thursday entered into a strategic partnership with Saudi construction major MASAH Construction Company for jointly developing and operating natural gas distribution networks in key industrial cities across the kingdom.
“This collaboration goes beyond economic synergy. It represents a shared commitment to innovation and sustainability. By combining MASAH’s infrastructure expertise with IGL’s proven capabilities in designing and operating city gas networks, in line with (Saudi Arabia’s) Vision 2030, we aim to build resilient and scalable systems that deliver lasting benefits to industries, communities, and the environment,” MASAH Construction chairman Mohammed Abdul Nayeem said.
“We are proud to be the first Indian city gas distribution company to venture in the overseas natural gas sector. Our partnership with MASAH reflects IGL’s strategic expansion for bringing world-class clean energy solutions to new global markets,” IGL MD Kamal Kishore Chatiwal said.
The partnership coincides with the visit of a delegation from the Saudi Arabia Investment Promotion Agency, aimed at highlighting investment prospects within the kingdom. In this regard, IGL’s partnership can be regarded as a pivotal moment in bilateral relations, which have historically been characterised by a buyer-seller dynamic, with Saudi Arabia ranking among the top three oil suppliers to India.
Both countries are making efforts to elevate the buyer-seller relationship to a broad-based economic partnership with cross investments. Saudi Arabia is also trying to wean its economy away from oil and transform into a regional business hub by attracting foreign investors.
Under their alliance, IGL and MASAH Construction are expected to jointly participate in a structured process followed in the kingdom, which typically involves public tenders and strategic partnerships led by the energy ministry and state-owned enterprises followed in Saudi Arabia. The alliance is eyeing several cities, except capital Riyadh and the holy cities of Mecca and Madina.
The alliance will leverage IGL’s strengths in planning, designing and operating natural gas networks, complemented by MASAH’s expertise in regulatory management, engineering, procurement, construction, and local stakeholder engagement.
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Adani to invest Rs 63,000 crore in transformative energy projects in Assam
Adani Power will invest Rs 48,000 crore for a 3,200 MW ultra super critical power plant in Assam. Adani Green Energy will invest Rs 15,000 crore for two Pumped Storage Plants totaling 2,700 MW. These initiatives align with Gautam Adani’s Rs 50,000 crore pledge for the Northeast’s development.
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Guwahati: Adani Power Ltd (APL), will invest Rs 48,000 crore to set up a 3,200 MW greenfield ultra super critical power plant in Assam.
Separately, Adani Green Energy, India’s largest renewable energy company, intends to invest Rs 15,000 crore, to set up two Pumped Storage Plants (PSP) in the state with a combined capacity of 2,700 MW. AGEL has received an LoA for 500 MW of energy storage capacity, which will be catered from the above PSPs.
These landmark initiatives underscore the Adani Group’s strategic focus on the advancement of India’s northeastern region, aligning with Chairman Gautam Adani’s pledge in February this year to invest Rs 50,000 crore in the region’s development and growth.
“The North-East is emerging as a vital frontier in India’s growth story,” said Gautam Adani, Chairman of the Adani Group,” and we are proud to contribute to its transformation. Our 3,200 MW thermal power project and 2,700 MW PSP projects in Assam collectively represent not only the largest private sector investment in the region but also firm steps toward energy security, industrial development and job creation. These projects will not only energize Assam but also catalyse progress across the entire northeastern corridor. We are honoured to contribute to Assam and the entire northeast’s progress and look forward to building partnerships that uplift local communities and drive India’s energy transformation.”
Adani Power emerged as the successful bidder, offering the lowest tariff of Rs 6.30 per kWh, through a tightly contested bidding process. The company will set up an Ultra Super Critical plant under the Design, Build, Finance, Own and Operate (DBFOO) model. The coal linkage for the power plant has been allocated under the SHAKTI Policy of the Government of India.
The project, which is expected to generate direct and indirect employment for around 20,000 to 25,000 people during the construction phase and sustain around 3,500 jobs during the operations phase, will be commissioned in a phased manner from December 2030. The power project will enhance Assam’s energy infrastructure, supporting the state’s growing industrial and household needs with reliable and efficient power. This facility is designed to set new benchmarks in environmental stewardship, leveraging modern technology to minimize emissions and maximize operational efficiency.
APL has received the requisite approvals from the Assam Electricity Regulatory Commission and the Power Supply Agreement (PSA) with APDCL is expected to be executed in due course.
Adani Green Energy too emerged as the lowest bidder for 500MW of energy storage capacity.
The project will introduce cutting-edge solutions for energy storage, grid stability and managing electricity demand during peak times, thus ensuring a sustainable and resilient supply of electricity. It will play a crucial role in integrating renewable energy sources, supporting Assam’s journey toward a greener future.
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‘Tripura’s Rukhia Power Plant to add 120 MW using new gas turbine technology’
AGARTALA: In a major push to boost power generation amid a natural gas shortage, the Tripura government will introduce Combined Cycle Gas Turbine (CCGT) technology at the Rukhia Power Plant in Sepahijala district, increasing its generation capacity by 120 megawatt (MW).
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Power Minister Ratan Lal Nath said on Monday that the foundation stone and Bhumi Pujan for the project will be held on November 26.
Nath, who also holds the Agriculture portfolio, said that despite the ongoing gas crisis, the Tripura State Electricity Corporation Limited (TSECL) has initiated measures to ensure an uninterrupted power supply to the consumers by adopting modern and efficient technology at the Rukhia thermal power plant.
“In 2017-18, the actual installed capacity of the Rukhia Power Plant was 63 MW, but only 40 MW was generated. A similar level of output continued in 2018-19. In 2019-20, despite the gas crisis, we managed to generate 56 MW of power. However, the plant had to be shut down in 2022-23 due to pending environmental clearance,” Nath said.
He added that the issue was resolved after he personally took up the matter with central ministers and officials and secured the required clearances.
Highlighting the benefits of the new technology, Nath said, “With the Combined Cycle Gas Turbine system, we will be able to generate 120 MW of power using the same quantity of gas. Although gas prices remain high in the international market, this technology will ensure higher efficiency.”
The project is estimated to cost around Rs 1,119 crore (excluding GST). The minister also underlined that since natural gas is a depleting resource, the state government is simultaneously giving thrust to solar energy to diversify its energy base. Tripura, one of the electricity-surplus states in the Northeast region, is keen to supply power to Nepal. (IANS)
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Brookfield contemplating IPO of natural gas pipeline InvIT
Energy Infrastructure Trust operates the country’s first bi-directional natural gas pipeline, a 1,485 km corridor connecting gas-producing fields on the east coast with key industrial and urban markets in the west. Private equity major Brookfield, the biggest global investor in Indian infrastructure, is planning to launch an IPO of its infrastructure investment trust (InvIT) – known as Energy Infrastructure Trust – which houses natural gas pipelines that the investor acquired from Reliance Industries Limited in 2019, people aware of the development told Moneycontrol.
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Energy Infrastructure Trust operates the country’s first bi-directional natural gas pipeline, a 1,485 km corridor connecting gas-producing fields on the east coast with key industrial and urban markets in the west.
The people cited above added that Brookfield has appointed a couple of advisors to begin work on the IPO. The quantum of fundraise through the IPO is still not finalized, they said, adding that the deal will include both primary and secondary share sales, with the IPO proceeds to be used for part repayment of the debt of the InvIT.
“In September, Brookfield sold large sums of units of InvIT to domestic investors for over Rs 1,800 crore in multiple block deals. These secondary share sales were meant to test the investor appetite for the pipeline InvIT, especially domestic investors, ahead of the proposed IPO of the trust,” said one of the sources.
As per stock exchange data, several wealth managers such as Neo Wealth, 360 One, Ambit Wealth, LGT Wealth and health insurer Star Health and Allied Insurance Company picked up Energy Infrastructure Trust’s units from Brookfield in the block trades executed in September.
An email sent to Brookfield did not elicit a response.
InvIT IPOs
Brookfield’s push to take its Energy Infrastructure Trust public comes at a time when many other sponsors of such infrastructure trusts are working towards a public market debut, hoping to tap strong domestic investor demand for long term, stable yield generating assets.
Moneycontrol reported on November 11 that Edelweiss Alternatives is planning to soon file draft papers for the initial share sale of its roads InvIT.
Moneycontrol previously reported that private equity firms KKR and I Squared Capital are planning to take their InvITs public, along with the National Highways Authority of India (NHAI)I, contributing to a pipeline of InvIT IPOs that are likely to raise over Rs 20,000 crore from the public markets.
Energy Infra Trust
The gas pipeline owned by Brookfield’s energy infra trust is the country’s first bi-directional pipeline, interconnected to major pipeline networks such as HaziraVijaipur-Jagdishpur/Dahej Vijaipur gas pipeline in Gujarat and Dahej -Uran-Panvel pipeline in Maharashtra, the Krishna Godavari Basin network in Andhra Pradesh owned and operated by GAIL (India) Limited, a pipeline owned by Gujarat State Petronet Limited (GSPL) in Gujarat, as well as the GSPL India Transco Pipeline in Andhra Pradesh. In addition, the Pipeline is connected to 21 direct customers, including city gas distribution customers, fertilizer, iron and steel, power, and petrochemicals.
The pipeline is connected to various domestic gas sources such as KG-D6 gas block operated by Reliance Industries Limited (RIL) and British Petroleum as well as ONGC’s gas fields on the east coast and to a LNG terminal operated by SHELL Energy India Private Limited in the state of Gujarat, on the west coast. The Pipeline also transports gas from LNG terminals at Dahej and Dabhol through interconnected pipelines of GAIL and GSPL.
The trust has a ‘pipeline usage agreement’ with RIL, whereby the latter has contracted a certain capacity of the pipeline for 20 years. The arrangement ensures steady cash flows for the trust.
The 48-inch pipeline, with a capacity of 85 million metric standard cubic meters per day, accounts for nearly 18 percent of India’s gas volumes transported.
For FY 2024-25, the Trust reported a total consolidated income of Rs 4,036 crore and a total distribution of Rs 1,141 crore, translating into a distribution yield of 19.26 percent, the highest among Indian InvITs.
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Policy Matters/ Gas Pricing/ Others
Haryana to launch new gas distribution policy to boost infrastructure investment
Haryana Chief Secretary Anurag Rastogi directed officials to incorporate the suggestions received from the Petroleum and Natural Gas Regulatory Board for the soon-to-be-launched City Gas Distribution Policy. Haryana Chief Secretary Anurag Rastogi Thursday announced that the state government is preparing to unveil a modern and investor-friendly City Gas Distribution (CGD) Policy to accelerate the development of natural gas infrastructure across the state.
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During a review meeting with the Industries and Commerce department and other departments concerned, Rastogi directed officials to incorporate the suggestions received from the Petroleum and Natural Gas Regulatory Board (PNGRB) to ensure that the policy meets national standards and industry expectations.
“The upcoming CGD policy is expected to open new doors for both public and private investment in natural gas pipelines and distribution networks. The policy focuses on creating an enabling environment for establishing pipeline infrastructure, while ensuring fair competition and safeguarding consumer interests relating to access and safety. The expansion of the CGD network will help Haryana reduce its dependence on crude oil by encouraging the use of cleaner energy alternatives in industries and households,” Rastogi said.
“Under the Draft CGD Policy 2025, companies authorised by the PNGRB will be able to seek Right of Use (RoU) and Right of Way (RoW) permissions through the state’s single-window portal – http://www.investharyana.in. Applicants will have to submit a Common Application Form along with GIS-based route maps, work plans, land details, and specifications of the technology to be used – such as HDD, trenchless boring, or open trenching. A transparent fee structure has been introduced. The draft policy simplifies financial procedures with clearly defined charges,” Rastogi added.
Dr Amit K Agrawal, Commissioner and Secretary, Industries and Commerce Department, highlighted that “the policy builds on the earlier CGD Policy formulated… in 2010, updating it to meet current technological and administrative requirements. The Industries and Commerce Department will serve as the nodal agency for implementing the new policy and coordinating with all stakeholder departments.”
Rastogi directed the Industries Department to consider the suggestions of the PNGRB and make the necessary alignments in the policy, adding that “the new CGD policy will strengthen Haryana’s energy security, enhance ease of doing business, and position the state as a leader in clean and sustainable energy infrastructure.”
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CNG Price Hike: IGL Announces New Rs 1/kg Increase Across Key Cities From
CNG Price Hike: IGL has increased CNG prices by Rs 1 per kg across select cities effective November 16, 2025, impacting daily travel costs for commuters. Kanpur, Noida, Greater Noida, and Ghaziabad are among the affected areas. The hike aims to manage rising natural gas procurement costs and maintain operational stability.
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Indraprastha Gas Limited (IGL) has revised CNG prices across select cities, with the new rates coming into effect from 6:00 am on November 16, 2025. The hike averages Rs 1 per kg across the affected regions. The revised CNG rates will directly affect the daily travel expenses of millions of commuters. Check the updated prices for Noida, Greater Noida, Ghaziabad, and Kanpur.
IGL stated that the price revision is aimed at offsetting fluctuations in natural gas procurement costs and ensuring operational stability.
City-Wise CNG Price Increase
- Kanpur GA: Price revised from Rs 87.92 to Rs 88.92 per kg
- Noida & Greater Noida GA: Price revised from Rs 84.70 to Rs 85.70 per kg
- Ghaziabad GA (excluding Hapur): Price revised from Rs 84.70 to Rs 85.70 per kg
IGL stated that the revisions are necessary to maintain operational stability amid fluctuations in input and procurement costs. The company currently supplies CNG to over 7 million vehicles across the National Capital Region and nearby cities.
The latest hike is expected to cause only a minor rise in daily travel expenses for passengers and fleet operators. IGL reviews CNG prices periodically based on natural gas procurement trends and government policies. No additional changes have been announced for other geographical areas at this time.
About Indraprastha Gas Limited
Indraprastha Gas Limited is a listed entity, whose shares fell over 1 percent on Friday, closing at Rs 213, with a market capitalisation of Rs 29,772 crore. Established in 1998, IGL manages city gas distribution in Delhi and supplies natural gas to several adjoining regions including Noida, Greater Noida, Ghaziabad, Hapur, Gurugram, Meerut, Shamli, Kanpur, Muzaffarnagar, Karnal, Rewari, Hamirpur, Fatehpur, Ajmer, Pali, and Rajsamand. The Delhi government holds a 5 percent stake in the company.
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Himachal targets full green energy state status by 2026: Dharmani
Himachal Pradesh is set to lead the nation toward a green-energy future, aiming to become India’s first fully green state by 2026 with a strong emphasis on electric mobility and solar power. This was stated by Technical Education Minister Rajesh Dharmani while addressing the annual day celebrations, “Arohan 2025,” at DAV Public School, Ghumarwin, in Bilaspur district today.
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Dharmani outlined the government’s ambitious plan and underscored the crucial role of education in shaping a sustainable and progressive society. He announced that a new Education Dialogue programme will soon be launched across schools in the state to encourage students and parents to engage in discussions on ongoing education reforms, fostering collaboration between families, teachers and policymakers.
Emphasising that education forms the foundation of a strong and creative society, Dharmani called for a nurturing home and school environment that promotes curiosity, innovation and open expression among children.
On sustainability, he said the state government is committed to achieving 90 per cent of its total energy consumption from renewable sources by 2026. To advance electric mobility, the government is offering subsidies of 40-50 per cent on e-taxis, e-buses and e-trucks and has begun replacing traditional fuel vehicles in government departments with electric alternatives.
Encouraging students to excel in academics, culture and sports, Dharmani said today’s youth will drive Himachal toward a greener, self-reliant and prosperous future. He also presented awards to students for their achievements in various fields.
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Hardeep Singh Puri calls for maritime cooperation with Korean shipbuilders
Petroleum and Natural Gas Minister urged Korean yards to partner on fleet expansion, LNG carriers and energy shipping as India scales maritime capacity. India has sought stronger maritime and shipbuilding cooperation with South Korea as Petroleum and Natural Gas Minister Hardeep Singh Puri concluded a two-day visit to the country on November 13-14.
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The minister visited the HD Hyundai Heavy Industries shipyard in Ulsan and said the engagement was “highly productive.” He noted that India’s expanding energy and shipping sectors, supported by the Make in India programme, offer opportunities for Korean shipyards to “Make in India for the World.”
He said nearly 20 per cent of global vessels are expected to either come to or go from India in the next 15 years. India spends $5–8 billion annually on freight, and its public sector undertakings can procure up to 59 crude, LNG and ethane vessels.
He also reviewed progress under an MoU with Cochin Shipyard and said that plans for a block fabrication facility will be finalised soon.
Meetings with Korean companies
The visit followed a meeting with HD Hyundai Chairman Chung Ki-sun in Seongnam. HD Hyundai briefed the Indian delegation on its ship design and smart shipyard systems. The company noted that India plans to expand its commercial fleet from 1,500 to 2,500 vessels and invest $24 billion under the Maritime Amrit Kaal Vision, including $8 billion announced for fleet expansion. It reaffirmed its interest in partnering with India.
Earlier in the day, Puri met leaders of Korea Ocean Business Corporation, SK Shipping, H-Line Shipping and Pan Ocean. He said energy and shipping remain central to India’s economic growth and noted that crude and gas imports worth over $150 billion are entirely seaborne. The oil and gas sector accounts for nearly 28 per cent of India’s total trade by volume, but only around 20 per cent of this cargo is carried on Indian-flagged or Indian-owned vessels.
He said rising demand for crude oil, LPG, LNG and ethane, along with ONGC’s need for about 100 offshore service and platform supply vessels by 2034, creates scope for joint work combining Korean shipbuilding capabilities with India’s manufacturing base.
India invites Hanwa Ocean to explore opportunities
The minister also met Hanwa Ocean President and CEO Kim Hee-Cheul in Seoul and invited the company to explore opportunities in India’s shipbuilding sector. He said the oil and gas sector is the largest commodity group at Indian ports but is mostly carried on non-Indian vessels.
He added that Indian PSUs are prepared to partner with Korean companies to manufacture LNG and crude oil carriers to support long-term asset creation.
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LNG Use / LNG Development and Shipping
ONGC Videsh Lifts Force Majeure On Mozambique LNG Project
ONGC Videsh, the overseas arm of Oil and Natural Gas Corporation, has lifted the Force Majeure on the multi-billion-dollar Mozambique liquefied natural gas (LNG) project, allowing construction work to restart after more than four years.
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The Force Majeure had been in effect since May 2021 after insurgent attacks disrupted operations in Mozambique’s Cabo Delgado province. The consortium operating the project has now informed the government of Mozambique that security conditions have “significantly improved”, and the suspension has been withdrawn with immediate effect.
“Security situation in Cabo Delgado Province (CDP), north of Mozambique, Area 1 Mozambique LNG Project has significantly improved, and Area 1 Mozambique LNG consortium has accordingly notified the government of Mozambique to end the Force Majeure which was declared on 11 May 2021.
Withdrawal of the Force Majeure enables construction activities to restart for early completion of the project,” ONGC said in a stock exchange filing.
ONGC Videsh holds a 16 per cent stake in the 13.12 million tonne per annum (MMTPA) project, which is operated by France-based Total Energies with a 26.5 per cent share. Other partners include Mozambique’s national oil company ENH, Japan’s Mitsui, and India’s Bharat Petroleum Resources.
Valued at over USD 20 billion, the Mozambique LNG project is one of Africa’s largest energy developments and is expected to help transform the country into a major global exporter of natural gas. With construction now set to resume, the consortium is targeting early completion of the project to restore momentum and support regional energy supply.
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CMA CGM Orders Six Dual-Fuel LNG Containerships from India’s Cochin Shipyard
The CMA CGM Group has signed a letter of intent for the construction of six new 1,700 TEU Dual-Fuel LNG containerships to be built at Cochin Shipyard Limited (CSL) in India. This strategic agreement makes CMA CGM the first major international container shipping company to commission LNG-powered vessels from an Indian shipyard.
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All six of the newbuilds, which are scheduled for delivery between 2029 and 2031, will be registered under the Indian flag. This move strongly supports the Indian government’s maritime policy and Prime Minister Modi’s vision to transform India into a global shipbuilding power. The project will also benefit from the technical cooperation of Korean shipbuilder HD Hyundai Heavy Industries (HD HHI).
Investment in Sustainability and India’s Maritime Sector
The 1,700 TEU vessels demonstrate CMA CGM’s commitment to a more sustainable shipping future. The ships can run on Liquefied Natural Gas (LNG) and are designed to be ready for low-carbon fuels, significantly reducing greenhouse gas (GHG) emissions. This aligns directly with the Group’s ambition to achieve Net Zero Carbon by 2050.
The initiative underscores CMA CGM’s deep commitment to India’s strategic national priorities, including the Make in India and Atmanirbhar Bharat initiatives. The Group is actively investing across the Indian maritime value chain:
Port Infrastructure: CMA CGM holds significant strategic stakes in terminals at Nhava Sheva Freeport Terminal (NSFT) near Mumbai and Mundra Port.
Flagging and Employment: The Group is reflagging four vessels under the Indian registry in 2025 and plans to recruit 1,000 Indian seafarers by the end of the year, with an additional 500 seafarers planned for hiring in 2026.
Rodolphe Saadé, Chairman and CEO of the CMA CGM Group, stated: “This milestone reflects the trust we place in India’s industrial and technological capabilities and supports Prime Minister Modi’s ambition to make India a global shipbuilding power. India is a strategic country for CMA CGM, where we invest, train, and innovate.”
Madhu S Nair, CMD of Cochin Shipyard, welcomed the landmark project, noting CSL’s commitment to delivering high-quality, sustainable vessels and the value of collaborating with a major partner like HD HHI. CMA CGM has a 34-year presence in India, a workforce of approximately 17,000 employees, and operates 19 weekly maritime services connecting India to global markets.
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OMCs clinch large LNG import deal with US for 2026
The country has been seeking trade arrangements with the US in the energy sector since Washington imposed high tariffs and a penalty on imports from India for buying Russian oil. India’s state-owned oil companies have concluded a one-year deal for imports of 2.2 million tonnes per annum of liquified petroleum gas (LPG) in 2026 from the US, Union Minister for Petroleum and Natural Gas Hardeep Singh Puri said on Monday. The imports, accounting for close to 10% of the country’s annual imports, will be sourced from the US Gulf Coast, the first structured contract of US LPG for the Indian market.The deal follows the commitment expressed by India to scale up energy imports from the US, with which the country is negotiating a bilateral trade agreement (BTA), even as most Indian goods face an additional tariff of 50% in the US over the most favoured nation rates.
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“This purchase is based on using Mount Belvieu as the benchmark for LPG purchases and a team of our officials from IndianOil , BPCL, and HPCL had visited the US and engaged in discussions with major US producers over the last few months, which have been concluded now,” the minister said in a post on X.
The country has been diversifying its sourcing of LPG in its attempt to provide secure and affordable supplies to the consumers. The country has been seeking trade arrangements with the US in the energy sector since Washington imposed high tariffs and a penalty on imports from India for buying Russian oil.
“India is already a growing offtaker of the US LNG, with long-term contracts in place with exporters like Cheniere and Freeport. While US LNG currently holds a modest share of India’s gas mix, expanding volumes or prepaying for future offtake would signal strong commercial alignment—especially as new US liquefaction projects seek demand security,” Sumit Ritolia, Lead Research Analyst, Refining & Modeling at Kpler had told FE.The US is now already India’s second-largest LNG supplier, driven by abundant supply and competitive long-term contracts, as per report by Rubix Data Sciences. Between FY20 and FY25, India’s LNG imports from the US grew at a 30% CAGR by value, with its share in LNG imports rising from 7% to 17%.
Crude oil imports from the US have also seen a rise in October reaching 568,000 barrels per day, touching their highest level since March 2021 and are expected to average 450,000–500,000 bpd in November, compared with a year-to-date average of around 300,000 bpd, Kpler had said.
In August, the Union Cabinet approved compensation amounting to Rs 30,000 crore to the three public sector oil marketing companies for the under- recoveries incurred on sale of domestic LPG.
Domestic LPG cylinders are supplied at regulated prices to consumers by the state-run OMCs including IOCL, BPCL, and HPCL. The international prices of LPG remained at high levels during 2024-25.
Puri noted that even as global prices soared by over 60% last year, the government ensured that Ujjwala consumers continue to receive LPG cylinders at just Rs 500-550 against its actual cost of over Rs 1,100. The government incurred the cost of over Rs 40,000 crores last year on this account.
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THINK Gas inks major long-term LNG pact with Shell Energy India
The deal marks a significant step in strengthening the company’s energy portfolio and enhancing supply reliability across its operational geographies. THINK Gas, THINK Gas, the merged entity of AG&P Pratham and THINK Gas, has announced a long-term gas sales and purchase agreement with Shell Energy India, marking a major milestone in India’s natural gas landscape. As per the deal, THINK Gas will receive natural gas supply from Shell Energy India’s portfolio through the Hazira LNG terminal.
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A press release says the agreement reinforces THINK Gas’ position as one of India’s leading city gas distribution companies, reflecting its commitment to delivering reliable, cleaner energy across its operational areas and customer segments.
CEO’s statement
Abhilesh Gupta, MD and CEO, THINK Gas, said, “The execution of this long-term agreement builds upon our strategy to diversify our gas portfolio in a complex global environment and to offer reliable, flexible, affordable, and sustainable solutions to the company’s downstream customers.”
Future plans
The supplies from Shell Energy India would help meet the growing demand of our customers, powering homes, vehicles and fuelling industries with cleaner energy. This agreement will cover a portion of our company’s projected energy requirements, and we are evaluating other similar partnerships to meet the growing energy needs of our customers, he said.
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IndianOil commences first-ever export of LNG to Nepal, informs Petroleum Minister Hardeep Puri
This is the first consignment of a five-year deal between IndianOil and Nepal’s Yogya Holding agreed during the India Energy Week in February this year. Refiner IndianOil has commenced India’s first-ever export of liquified natural gas (LNG) to Nepal, Union Minister for Petroleum and Natural Gas Hardeep Singh Puri informed on Thursday.
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This is the initial consignment of a five-year deal between IndianOil and Nepal’s Yogya Holding to deliver 1,000 metric tons of LNG during the agreed period. The agreement was signed during the India Energy Week in February this year.
The consignment reached Yogya Holding’s facility on Wednesday, November 19.
The LNG is being sourced from IndianOil’s Dhamra LNG terminal in Odisha and is being transported using cryogenic road tankers via the international border at the Raxaul town of Bihar.
Mr. Puri stated the state-owned refiner has established cryogenic storage and regasification facilities at Simara in Nepal to aid the cryogenic transportation.
He added the deal reflected New Delhi’s “unwavering commitment to advancing regional energy security, sustainability, and cross-border collaboration.”
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Electric Mobility/ Hydrogen/Bio-Methane
Unlocking India’s Green Hydrogen Production Potential
India targets 5 MMT of Green Hydrogen production annually by 2030. India’s first port-based Green Hydrogen pilot commissioned at V.O. Chidambaranar Port. Hydrogen mobility pilots launched across 10 routes, involving 37 fuel cell and hydrogen internal combustion engine vehicles.
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The Mission is expected to attract over ₹8 lakh crore in investments and reduce fossil fuel imports by more than ₹1 lakh crore.
India’s energy transition is entering a decisive phase, as the country reduces its dependence on fossil fuels and increases domestic clean energy production. This is in line with its vision of becoming a developed nation by 2047 and achieving Net Zero by 2070. In this transition, Green hydrogen, has emerged as a clean, scalable fuel alternative that can decarbonize hard-to-abate sectors, reduce import dependence on fossil fuels, and support India’s goals for energy security and industrial growth.
The Indian government launched the National Green Hydrogen Mission (NGHM) in 2023, as an umbrella programme that aims to establish a Green Hydrogen ecosystem and catalyse a systemic response to the opportunities and challenges in this sector.
Objectives
The Mission represents more than an energy initiative; it is a strategic pathway toward industrial competitiveness, import reduction, and long-term energy security—linking sustainability with self-reliance.
What is Green Hydrogen?
Green Hydrogen is Hydrogen produced using renewable energy, such as solar or wind power, instead of fossil fuels. In this process water is split into hydrogen and oxygen through electrolysis, using electricity from solar panels or wind turbines. According to standards notified by Govt of India, Hydrogen made this way is considered “green” if the total emissions from the process are very low, not more than 2 kg of CO₂ equivalent for every 1 kg of Hydrogen produced. Green Hydrogen can also be produced by converting biomass (like agricultural waste) into hydrogen, as long as emissions remain below the same limit.
The National Green Hydrogen Mission (NGHM) aims to build the capacity and ecosystem required to position India as a global leader in clean hydrogen. By 2030, the Mission will be supported by about 125 GW of new renewable energy capacity dedicated to green hydrogen production, along with investments exceeding ₹8 lakh crore. The Mission is expected to create over 6 lakh jobs, reduce fossil fuel imports by more than ₹1 lakh crore, and avoid nearly 50 MMT of greenhouse gas emissions every year by 2030.
As of May 2025, 19 companies have been allocated a cumulative annual production capacity of 862,000 tonnes of Green Hydrogen every year and 15 firms have been awarded a 3,000 MW annual electrolyzer manufacturing capacity. India has also launched pilot project in steel, mobility and shipping sectors.
Sectoral Innovation & Implementation Under NGHM
Launched in January 2023, the National Green Hydrogen Mission has an initial outlay of ₹19,744 crore till Financial Year 2029-30. This includes ₹17,490 crore for the Strategic Interventions for Green Hydrogen Transition (SIGHT) programme, ₹1,466 crore for pilot projects, ₹400 crore for research and development (R&D), and ₹388 crore towards other Mission components.
The Mission focuses on four key pillars, including policy and regulatory framework, demand creation, research and development & innovation, and enabling infrastructure and ecosystem development — aimed at positioning India as a global hub for green hydrogen production, use, and export.
To augment the Mission’s vision, the government has also launched multiple schemes to accelerate production and use of green hydrogen, promote domestic manufacturing and exports, ensure regulatory compliance, and strengthen public–private partnerships.
(i) Strategic Interventions for Green Hydrogen Transition (SIGHT) Scheme: A financial incentive mechanism with an outlay of ₹ 17,490 crore up to 2029-30 provides incentives for the manufacturing of electrolysers that are used for production of green hydrogen.
(ii) Development of Green Hydrogen Hubs: In October 2025, the Ministry of New and Renewable Energy (MNRE) has announced the recognition of three major ports Deendayal Port Authority (Gujarat), V.O. Chidambaranar Port Authority (Tamil Nadu), and Paradip Port Authority (Odisha) as Green Hydrogen Hubs under the NGHM.These coastal gateways will serve as integrated centres for production, consumption, and future export.
(iii) Standards, Certification and Safety: Launched in April 2025, the Green Hydrogen Certification Scheme of India (GHCI) provides a national framework to certify hydrogen as “green” by assessing its greenhouse gas emissions across the entire production cycle. The scheme ensures that only hydrogen produced using renewable energy, and within the prescribed emission limits, can be officially labeled as Green Hydrogen. It provides transparency, traceability, and credibility for producers, buyers, and export markets.
Under the GHCI, obtaining a ‘Final Certificate’ is mandatory for any green hydrogen production facility in India that (a) receives subsidies or incentives from the central or state governments, or (b) sells or uses the hydrogen domestically (in India).
The Bureau of Energy Efficiency (BEE) is the Nodal Authority responsible for accrediting agencies that monitor and certify projects.
(iv) Strategic Hydrogen Innovation Partnership (SHIP): The Mission fosters public-private partnerships for R&D through the Strategic Hydrogen Innovation Partnership (SHIP). It is designed to support the development of advanced, globally competitive hydrogen technologies through collaborative research involving Government institutions, industry, and academic organisations. The programme includes the creation of a dedicated R&D fund with contributions from both the Government and industry. Under SHIP, consortium-based research will be encouraged to leverage the strengths of national scientific institutions such as BARC, ISRO, CSIR, IITs, IISc, and other partners. The objective is to drive innovation across the Green Hydrogen value chain and support domestic manufacturing capability.
Adedicated ₹400 crore R&D scheme under the Mission is already powering 23 cutting-edge projects across areas such as hydrogen production, safety systems, storage, and industrial applications. In addition, a ₹100 crore Call for Proposals has been launched to support start-ups working on innovative technologies for hydrogen production, storage, transport and utilisation, with funding of up to ₹5 crore per project. These initiatives are aimed at developing globally competitive technologies and reducing costs across the hydrogen value chain.
The second round of R&D proposals, launched in July 2025 focuses on collaborative research and industry participation, with over 30 joint proposals internationally submitted under the EU–India Trade and Technology Council.
Pathways For Adoption
The roadmap is not just limited to forming policies and providing subsidies, but green hydrogen is also being introduced in key sectors to reduce emissions, supporting domestic manufacturing, and replacing fossil-based hydrogen and feedstock. The NGHM is facilitating applications across industry, mobility, and infrastructure.
Industrial
- Fertilizers: Replacing fossil-fuel-based feedstocks with Green Ammonia. A recent auction for a long-term supply of green ammonia to fertilizer units, with an aggregate procurement capacity of 7.24 lakh metric tonnes per annum,at a price of ₹55.75 per kg.
- Petroleum Refining: The Mission is seamlessly facilitating the replacement of fossil-based hydrogen with green hydrogen in refineries, directly reducing the carbon footprint of this essential industry.
- Steel: Five pilot projects have been initiated in collaboration with public and private steel producers to evaluate the use of Green Hydrogen for iron reduction and other process applications. These pilots are designed to assess the technical feasibility, economic viability and safety of hydrogen-based steelmaking in Indian operating conditions.
Mobility and Transport
- Road Transport: In March, five major pilot projects were initiated involving 37 hydrogen vehicle (buses and trucks), and 9 refueling stations across 10 different routes. The vehicles to be deployed for the trial include 15 hydrogen fuel cell-based vehicles and 22 hydrogen internal combustion engine-based vehicles. The financial support for the project would be around Rs. 208 crore.
- Shipping: India’s first port-based Green Hydrogen Pilot Projectwas commissioned at V.O. Chidambaranar Port in September 2025. The₹25 crore, 10 Nm³/hr facility will produce green hydrogen for local applications, including street lighting and an EV charging station. A ₹42 crore, 750 m³ Green Methanol Bunkering and Refuelling Facility is also being developed to support cleaner maritime operations and enable a Coastal Green Shipping Corridor between Kandla and Tuticorin.
- High-Altitude Mobility: NTPC in November 2024was commissioned the world’s highest altitude(3,650 m) Green Hydrogen Mobility Project in Leh, which includes 5 hydrogen intra-city buses and a fuelling station proving the fuel’s reliability in extreme conditions. This station shall mitigate the carbon emissions of approx. 350 MT/year and contribute 230 MT/year of pure oxygen into the atmosphere which is equal to planting of approx. 13000 trees.
Enabling Framework:
Beyond direct incentives, a comprehensive enabling framework is being established to de-risk investments and accelerate development.
- Policy Framework: To facilitate the delivery of low-cost renewable energy for hydrogen production, the government has provided a waiver of Interstate transmission charges and ensured a time-bound grant of Open Access.
- Skill Development: A coordinated skill development programme is being implemented, which has already led to the certification of more than 5,600 trainees in hydrogen-related qualifications, building a future-ready workforce.
Building Global Partnerships
In 2024, India made its debut in the international hydrogen community at the World Hydrogen Summit in Rotterdam with the inauguration of its first India Pavilion. This positions India as a prime partner for global investment, and key partner in the emerging global hydrogen economy.
- EU-India Collaboration: Under the EU-India Trade and Technology Council, collaboration is expanding, with over 30 joint proposals received on hydrogen production from waste.
- India-UK Partnership: A dedicated Standards Partnership Workshop in February 2025was held to strengthen cooperation on hydrogen standardization, focusing on safe, scalable, and globally harmonized Regulations, Codes and Standards (RCS) to enhance trade.
- Partnership with H2Global: In November 2024, Solar Energy Corporation of India (SECI) signed an MoU with Germany’s H2Global Stiftung to collaborate on market-based mechanisms and joint tender designs, facilitating the export of Indian green hydrogen to international markets.
- Singapore: In October 2025, Sembcorp Industries signed MoUs with V.O. Chidambaranar and Paradip Port Authorities to develop integrated green-hydrogen and ammonia hubs for production, storage and exports.
Conclusion: A Legacy of Clean Growth
Green hydrogen stands at the center of India’s clean energy strategy, driving the shift toward a low-carbon and self-reliant economy. Building on one of the world’s most competitive renewable energy bases, the National Green Hydrogen Mission is expanding domestic production, scaling innovation, and opening global markets for green hydrogen and its derivatives. The Mission reduces dependence on fossil fuels, accelerates industrial transformation, and positions India to lead with credibility in the global clean energy transition—advancing a future that is sustainable, secure, and self-sustained.
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India set to command 10% of global green hydrogen demand by 2030: Shripad Naik
India is on track to command 10 percent of the global green hydrogen demand by 2030, Union Minister of State for New and Renewable Energy and Power Shripad Y. Naik said on Wednesday. Addressing the 3rd International Conference on Green Hydrogen (ICGH 2025) at Bharat Mandapam in New Delhi, he said the country’s clean energy transition is among the boldest and fastest in the world, guided by Prime Minister Narendra Modi’s Panchamrit commitments at COP-26.
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Naik said India’s installed non-fossil-fuel-based power capacity has reached 260 GW, led by solar and wind energy. “This renewable strength is enabling the next decisive step — the Green Hydrogen Revolution — converting clean energy into green molecules to decarbonise industries and fuel transport,” he said.
The Minister highlighted that India’s green hydrogen market is projected to grow at a compound annual rate of 20–40 percent over the next decade. With its renewable energy base and enabling policies, India is emerging as a global hub for hydrogen trade and technology, he added.
Under the National Green Hydrogen Mission (NGHM) launched in January 2023, the government has already allocated ₹17,000 crore in incentives for hydrogen production and electrolyser manufacturing. Projects have been awarded for 3,000 MW per annum of electrolyser manufacturing and 8.62 lakh metric tonnes per annum of green hydrogen production. Competitive prices have been discovered for 7.24 lakh MTPA of green ammonia for fertiliser units and 20,000 MTPA of green hydrogen for IOCL, BPCL and HPCL refineries.
Calling the transition an economic, environmental, and societal transformation, Naik said green hydrogen will fuel sustainable growth and strengthen India’s position as a key pillar in the global hydrogen value chain.
Union Minister for Science and Technology Dr. Jitendra Singh, who also addressed the event, said the Green Hydrogen Mission embodies a “whole-of-government, whole-of-nation” approach, integrating efforts across ministries and sectors. He noted that several earlier initiatives of the Department of Science and Technology have been integrated into the mission, showing how India is breaking traditional silos to advance strategic clean technologies.
Dr. Singh emphasised that India’s scientific missions — from biotechnology and biofuels to hydrogen and electric mobility — are being implemented with public–private partnerships and a focus on long-term sustainability. These efforts, he said, reflect India’s move towards a self-reliant and globally competitive hydrogen economy, aligned with the vision of Viksit Bharat 2047.
Senior officials, including SECI Managing Director Akash Tripathi and National Green Hydrogen Mission Director Abhay Bakre, highlighted that India has emerged as one of the fastest-growing ecosystems for hydrogen development globally. The discussions at ICGH 2025 focused on developing hydrogen hubs, integrating production with industrial clusters, and enabling blended finance for large-scale adoption.
The International Conference on Green Hydrogen 2025, organised by the Ministry of New and Renewable Energy, brought together global policymakers, scientists, and industry leaders to discuss policy frameworks, technology innovations, and investment strategies shaping the future of the green hydrogen sector.
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State aims to be green energy hub: CM, Madhya Pradesh
Bhopal: CM Mohan Yadav on Wednesday inaugurated three compressed biogas (CBG) plants in Bhopal, Indore and Satna, through video conference from Samatva Bhavan. Yadav said these state-of-the-art compressed biogas plants by Reliance Green Energy symbolise partnership and progress, converting waste into energy.He emphasised that the state has very fertile land, and energy production via CBG plants will help reduce incidents such as stubble burning in the state. “We are preparing the energy of the future in Madhya Pradesh. We wish to make MP a nub of green energy,” the CM said.
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MP’s green push: CM opens 3 biogas plants using farm waste
Bhopal: Madhya Pradesh Chief Minister Mohan Yadav on Wednesday said that green energy is the need of the hour and the state is moving towards a clean, bright and sustainable future through integrated energy production methods. He was virtually inaugurating three newly built Compressed Bio-Gas (CBG) plants of Reliance Green Energy in Bhopal, Indore, and Satna from the CM House.
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Calling the CBG plants symbols of “partnership and progress,” Yadav said the facilities not only convert waste into energy but also address environmental challenges like stubble burning. “With private participation and collaboration, we will make Madhya Pradesh a hub of green energy,” he said.
The CM noted that the inauguration marks the beginning of a new era of clean energy, green growth and self-reliant Madhya Pradesh. The Bhopal plant, set up by Reliance Industries Limited, is the largest and most advanced CBG plant in the state. The project is a step towards Prime Minister Narendra Modi’s “Waste to Wealth” and “Energy from Waste” vision and India’s 2070 net-zero carbon emission goal.
Each unit will produce 22.5 tonnes of CBG daily using 260 tonnes of agricultural residue, offering a viable alternative to stubble burning. The gas produced from a single plant can power nearly 2,000 auto-rickshaws, private and light vehicles. Every plant is expected to generate employment for over 250 people.
Reliance Industries has invested about Rs 700 crore in six CBG plants in the state with a combined annual production capacity of 45,000 tonnes. These plants are expected to cut carbon dioxide emissions by 17,000 tonnes annually.
“Such innovations benefit farmers, strengthen the state’s green credentials, and help convert agricultural waste into an economic asset,” Yadav said.
Chief Secretary Anurag Jain, ACS to CM Neeraj Mandloi, PS Industry Raghwendra Kumar Singh, Secretary to CM Alok Kumar Singh and Reliance Group President Farhan Ansari were present on the occasion.
https://www.millenniumpost.in/nation/mps-green-push-cm-opens-3-biogas-plants-using-farm-waste-635304
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India to establish four hydrogen valleys to drive clean energy transition
New Delhi: India will set up four hydrogen valleys across the country to showcase the full hydrogen value chain—from production and storage to transport and use—with a total investment of ₹485 crore, Union Minister of State (Independent Charge) for Science and Technology Jitendra Singh announced on Wednesday.
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Speaking at the 3rd International Conference on Green Hydrogen (ICGH–2025) at Bharat Mandapam, Singh said that ₹169.89 crore of the total investment will come from the National Green Hydrogen Mission (NGHM), while ₹315.43 crore will be contributed by industry and consortium partners.
The Hydrogen Valley Innovation Clusters (HVICs), conceptualised by the Department of Science and Technology (DST) and now part of the NGHM under the Ministry of New and Renewable Energy (MNRE), will serve as large-scale demonstration projects and act as real-world laboratories for innovation, standardisation, and policy formulation, Singh explained.
He said that clean energy is now an economic, technological, and strategic necessity for India’s progress. India, he added, intends not just to adopt clean technologies but also to invent and lead them, positioning the hydrogen economy as a central pillar of the country’s energy security and industrial growth.
Organised by MNRE and the Office of the Principal Scientific Adviser, in collaboration with the Ministry of Petroleum and Natural Gas (MoPNG), DST, and the Department of Scientific and Industrial Research (DSIR), the two-day conference brought together policymakers, scientists, and industry leaders to discuss India’s green hydrogen roadmap.
Singh highlighted the Research, Development and Innovation (RDI) Scheme launched by Prime Minister Narendra Modi on November 3, 2025, describing it as a major step to link research and real-world application. The ₹1 lakh crore scheme includes ₹20,000 crore for DST to promote deep-tech and clean energy innovation in partnership with startups and industry.
He said the initiative represents a shift from government-led funding to a more collaborative and sustainable model, strengthening India’s long-term scientific and economic resilience.
Singh also pointed to the formation of the Anusandhan National Research Foundation (ANRF) as a landmark reform aimed at uniting academia, industry, and government within a single, mission-driven framework. The foundation, he said, will help align scientific capability with national priorities in clean energy, advanced manufacturing, and sustainability.
Referring to the Mission for Advancement in High-Impact Areas – Electric Vehicle (MAHA–EV), Singh said it embodies India’s self-reliance vision by encouraging domestic innovation in electric mobility and hydrogen fuel technologies. The mission brings together public and private entities to develop advanced batteries, fuel cells, and scalable charging infrastructure suited to Indian needs.
Emphasising India’s global role in clean energy, Singh reminded the audience that the term “Mission Innovation” was first introduced by Prime Minister Modi. Under Mission Innovation 2.0, India is collaborating with global partners to reduce the cost of clean hydrogen to $2 per kilogram and expand the Hydrogen Valley model worldwide by 2030.
He said India’s efforts show how science, innovation, and enterprise are working together to create a cleaner and more secure future. Singh praised MNRE, the Office of the Principal Scientific Adviser, MoPNG, DST, and DSIR for their joint work under the Green Hydrogen Mission.
Concluding his remarks, Singh said that a self-reliant hydrogen economy will be key to achieving the goal of a developed India by 2047. He urged all stakeholders to work collectively to make India a global leader in clean energy innovation.
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PDEU researchers validate safe hydrogen mixing for gas grids
Ahmedabad: A research team at Pandit Deendayal Energy University (PDEU) has successfully demonstrated the blending of 99% pure hydrogen with natural gas at 18% to 25% levels — a development experts say could enable hydrogen integration into the city gas distribution networks under the National Green Hydrogen Mission.
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The project, mentored by prof Anirbid Sircar and Dr Namrata Bisht, won second place at the FICCI RD Summit 2025 held recently in New Delhi. Their entry showcased safe and effective hydrogen blending for the city gas distribution (CGD) industry.
Researchers said the work marks an important step forward for hydrogen-based clean energy systems in India. The project — funded by a major petroleum company — assessed combustion performance, pipeline compatibility and operational behaviour of hydrogen–natural gas blends in a simulated CGD setup. The team also included Kunal Gajbhiye, Pallav and industry partner Balief Corporation.
Prof Sircar said the project evaluated blending hydrogen across various levels to understand its characteristics. “The functional setup comprised high-pressure hydrogen storage cylinders, PLC-based mass flow controllers, a gas mixing unit, moisture and hydrocarbon filtration, and multi-material pipelines, including galvanised iron (GI) pipe, medium-density polyethylene (MDPE) pipe, and carbon steel pipe,” he said. “It is to simulate different distribution conditions in real setups.”
The team reported that hydrogen blends between 18% and 25% delivered the highest heat flux values — 22,489 to 22,763 W/m² (watts per sq m) — indicating faster thermal energy transfer and improved burner response. While peak thermal efficiency reached about 16%, they found the optimal balance of high heat flux, stable flame behaviour and reduced gas consumption at a 25% blend.
“Gas usage analysis indicated that blends up to 25% hydrogen lowered overall volumetric gas consumption, improving fuel efficiency and reducing emissions intensity,” said Dr Bisht.
Prof Sircar added that PDEU had earlier demonstrated the production of green hydrogen using solar and geothermal energy in Gujarat.
Head: Clean Energy Shift
– Hydrogen is seen as a key component of India’s future energy mix, with the National Green Hydrogen Mission (NGHM) targeting the production of 5 MMT of green hydrogen by 2030
– The project at PDEU is the first of its kind to demonstrate the potential for higher levels of hydrogen blending in a safe and stable manner, with scalability to a city-wide gas distribution network
– Gas usage analysis shows that blending up to 25% hydrogen reduces overall volumetric gas consumption, improves fuel efficiency, and lowers emissions
– PDEU is preparing to operationalise a CGD-based hydrogen blending network with SCADA-enabled monitoring of pressure, temperature, flow, and efficiency
– The team has filed a patent for the blending system and reactor design
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INTERNATIONAL NEWS
Natural Gas / Transnational Pipelines/ Others
Syria: Dana Gas to explore redevelopment of natural gasfields in Syria
Dana Gas, one of the largest private natural gas companies in the Middle East, has signed an initial agreement with Syrian Petroleum Company to explore redevelopment and expansion of natural gasfields in central Syria, as the country looks to revive its energy sector and increase production.
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The deal includes an assessment of Abu Rabah gasfield, one of the largest in Syria, Dana Gas said in a statement on Wednesday to the Abu Dhabi Securities Exchange, where its shares are traded.
The UAE company said it is the first gas developer to sign such an agreement in Syria.
“Dana Gas will conduct a comprehensive technical assessment of the identified fields and propose a development plan aimed at significantly increasing total gas production if the evaluation is successful and both parties reach a final agreement,” the company said.
The move comes as Syria seeks to revive its energy sector and attract more investment after US President Donald Trump announced the lifting of sanctions on the country during his trip to the Gulf in May.
Saudi Arabia, Qatar and Turkey have since pledged to invest in the country to help it rebuild its infrastructure, energy and other sectors after the devastating nearly 14-year civil war.
Richard Hall, chief executive of Dana Gas, said: “This agreement marks an important first step in evaluating opportunities to redevelop Syria’s gas infrastructure and unlock the potential that exists within its gas sector.
“The fields identified … could make a real difference to domestic gas production, strengthening Syria’s energy security and supporting local communities.”
The company’s early completion of the KM250 expansion project in Iraq alongside its operating partner and the technical strength of the Syrian Petroleum team prepared Dana Gas to take up the new challenge, he added.
“The lessons and capabilities we developed there are directly transferable to projects such as this, where hands-on execution, technical and financial discipline, and regional understanding are key to delivery,” Mr Hall said.
Before the civil war, oil was a central pillar of Syria’s economy. It accounted for up to 25 per cent of its gross domestic product, the International Monetary Fund estimated, and about $3 billion in annual revenue.
But production had nosedived by 2014, plummeting to about 25,000 barrels per day, according to a US Energy Information Association country analysis in 2015. Syria produced an estimated 380,00 to 400,000 bpd before the outbreak of the civil war in 2011.
The sharp decline was driven by extensive damage to infrastructure, such as power grids and gas refineries, after ISIS took control of key oilfields and Syria lost its connection to global energy markets.
Syria is seeking more than $30 billion to fully rehabilitate the country’s oil, mineral, electricity and water sectors, Ahmed Sleiman, director of communications for the Ministry of Energy, told The National in an interview last week.
In September, Syria announced the dispatch of the country’s first official crude export shipment in 14 years, signalling its return to the global energy market.
The 600,000 barrels of heavy crude set sail from the historic port of Tartus aboard the Nissos Christiana tanker, under a deal with B Serve Energy, Reuters reported.
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US: N.J. and N.Y. regulators approve $1B underwater natural gas pipeline permits
Regulators from New Jersey and New York have approved environmental permits needed for the Northeast Supply Enhancement (NESE) project, which will deliver natural gas from Pennsylvania to New York City through New Jersey and pipelines beneath Raritan Bay and New York Harbor.
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The Williams Company, owner of the Transcontinental Pipeline Co. (TRANSCO), will drill piles into the bay floor with mechanical hammers and pistons to mount 23 miles of pipes underwater.
The NESE project is set to provide $1.8 billion in economic development, delivering gas to 2.3 million homes in the city, and reducing CO2 emissions by over 13,000 tons per year; equivalent to removing 2,800 cars from the road each year.
NESE also supports over 3,000 jobs and generates millions in gross state product (GSP) and state tax revenues for the state. During the construction phase of the project, the state of New Jersey will experience an increase in economic activity, including direct and indirect job creation and an increase in state and local tax revenue.
“We’re proud to move NESE forward and do our part in providing New Yorkers access to clean, reliable and affordable natural gas,” said Chad Zamarin, president and CEO of Williams. “This project reflects our commitment to deliver clean and reliable energy while lowering energy costs and supporting economic growth and environmental stewardship.”
“We are pleased to see that the DEP has approved the permit for this much-needed regional pipeline project,” said New Jersey Business & Industry Association Deputy Government Affairs Officer Ray Cantor. “This project will allow more natural gas to flow into a region that desperately needs it.”
Despite the proposed benefits, environmental groups have opposed the project. Additionally, several nonprofits, homeowners and conservation groups sued over the project Oct. 30 in the U.S. Court of Appeals for the District of Columbia Circuit after the Federal Energy Regulatory Commission reissued authorization for NESE.
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Qatar: QatarEnergy signs agreement for Guyana offshore exploration block
QatarEnergy has signed a Production Sharing Agreement for shallow-water Block S4 offshore the Cooperative Republic of Guyana. The block was awarded through the 2022 Guyana Licensing Round. Under the terms of the agreement, QatarEnergy will hold a 35% share, while its partners TotalEnergies (the operator) will hold 40%, and PETRONAS will hold 25%.
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Commenting on this agreement, His Excellency Saad Sherida Al-Kaabi, the Minister of State for Energy Affairs, and President and CEO of QatarEnergy, said: “We are pleased to secure this exploration block in Guyana, further building on the strategy to expand our global upstream exploration activities.”
H.E. Al-Kaabi added, “I would like to thank the Government of the Cooperative Republic of Guyana and our partners in the block for their valued support and cooperation. We look forward to working together to deliver on our exploration objectives.”
Block S4 covers an area of 1,788 km2 and is situated approximately 50-100 km from Guyana’s coast, in water depths of 30-100 metres. Located in shallow waters close to shore, it is promising due to its strategic location close to proven geological trends.
Guyana has emerged as a fast-growing energy frontier, following a wave of major offshore oil discoveries that have transformed its economic outlook and drawn interest from leading global energy companies. In line with this, the government launched the 2022 Licensing Round, offering both shallow- and deep-water blocks to broaden exploration activity and attract diversified expertise.
QatarEnergy’s participation aligns with its strategy of expanding its upstream portfolio into high-potential regions. The agreement reinforces the company’s vision to strengthen its presence in the Americas, following recent ventures in Suriname and Brazil. It strongly reflects Guyana’s efforts to build strategic international partnership, as it develops its energy sector for long-term production growth.
This partnership also highlights Guyana’s commitment to fostering a competitive investment environment, as it expands its energy sector. Rising interest from several leading global companies has led to the country balancing rapid development with strategic resource management.
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Egypt announces major natural gas discovery in Western Desert with production potential of 36 million cubic feet daily
Khalda Petroleum Company has announced a new natural gas discovery in the Western Desert, following drilling and electrical logging that confirmed the presence of gas with an estimated production rate of approximately 36 million cubic feet per day (mmcf/d), as reported by Egypt’s Ministry of Petroleum and Mineral Resources.
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On Monday, the ministry stated that testing and initial flow assessments are currently in progress, with plans to start production from the exploratory well, Gomana-1, on November 19. This discovery is part of the ministry’s strategy to enhance production rates and attract investment partners to increase exploration drilling activities.
Khalda Petroleum is a joint venture between the Egyptian General Petroleum Corporation (EGPC) and the U.S.-based Apache Corporation. In September, EGPC entered into an agreement with Apache for exploration and development that includes five new blocks, involving the drilling of 14 wells in the Western Desert with a total investment of $35 million and a $25 million signing bonus.
Apache has been operating in Egypt since the mid-1990s and is a key producer in the Western Desert. In May, Khalda Petroleum discovered the South NUT-1 well in the same region, which began production in September with a rate of 50 mmcf/d of natural gas.
Recent oil discovery in West Fewebs-1
Additionally, in August 2025, Khalda Petroleum Company announced an oil discovery in the West Fewebs-1 area. The well was drilled to a depth of 270 feet into the Paleozoic sands, yielding a production rate of 7,165 barrels of oil per day through a 1-inch opening, with an oil quality of 44 degrees and 23 million cubic feet of gas accompanying it. Also, electrical logs from the well indicated the presence of hydrocarbons in the Paleozoic layer, which has a total net thickness of 462 feet.
Shell advances in El-Amriya block
Moreover, in November 2023, Shell, in partnership with Stena Drilling, made significant advancements in Egypt at the northeast El-Amriya block of the Mediterranean Sea. The drilling operations, located in the offshore Nile Delta at approximately 250 meters below sea level, have generated promising data. Over the past five years, Egypt has made substantial progress in energy exploration, discovering 284 new fields, which include 217 oil wells and 67 gas wells. Minister El-Molla highlighted that the addition of 1.32 billion barrels of oil to the country’s reserves has greatly enhanced production.
Recognizing the need to shift towards renewable energy, Egypt further signed an agreement in July to allocate land to Norway-based Scatec for a $5 billion wind power plant in the Sohag region. This facility is expected to generate 5 gigawatts of electricity annually, supporting Egypt’s goal of obtaining 42 percent of its energy from renewable sources by 2030.
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Greece: Hydrogen-ready gas pipeline approved in Western Macedonia
By decision of Alternate Minister of National Economy and Finance Nikos Papathanasis, the grant for the construction of a high-pressure natural gas pipeline to Western Macedonia was included in the “Environment and Climate Change” Program of the NSRF 2021-2027, with a total cost of 188,341,603.94 euros and a total state expenditure of €84,311,895.
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The project consists of 157 kilometers of high-pressure natural gas pipeline, starts from the Imathia village of Trikala and ends north of Ptolemaida.
The new pipeline in Western Macedonia is one of the important projects included in the National Natural Gas System Development Program 2023-2032, as it will be the first high-pressure natural gas transmission pipeline in Greece – and among the first in Europe – designed to operate and transport up to 100% “hydrogen ready.”
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Natural Gas / LNG Utilization / Bio-LNG
Japan: Japanese contractor powering along thanks to LNG
Major global liquefied natural gas projects have shone through in Japanese contractor JGC’s latest financial results, and the company has its eye firmly on new contracts in Mozambique and Papua New Guinea. JGC is Japan’s leading energy engineering, procurement and construction contractor, and it had a prolific quarter to the end of September, winning new LNG front-end engineering and design contracts for Shell in Canada, Eni in Mozambique and Inpex in Indonesia.
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LNG is the largest component in its overseas order book as at 30 September 2025, comprising 32% of the total of more than 1.1 trillion yen (US$7.1 billion); and the contractor said it is targeting material orders in the half year to March 2026 for a floating LNG project in Mozambique and an LNG project in PNG.
JGC is also targeting future LNG plant investments in other major petroleum basins around the world.
Promoting itself, JGC said it is one of the few lump-sum EPC contractors “with a strong financial position”, adding that it has an “extensive track record in LNG and floating LNG including modular execution”.
Its financial results for the half year ended 30 September were solid, with a 27% increase in operating profit of 15.7 billion yen on revenues of 381.2 billion yen.
In terms of the market environment, JGC said the importance of natural gas and LNG “is a common understanding for a realistic transition to a decarbonised society. The demand is expected to continue in the medium to long term, with a wealth of projects available”.
“Clients are moving ahead with capital investment plans while taking environmental measures such as E.Drive (installing electric motors).”
https://www.upstreamonline.com/lng/japanese-contractor-powering-along-thanks-to-lng/2-1-1899375
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US: Harvest Midstream Acquires Kenai LNG Facility to Bolster Alaska Gas Supply
(P&GJ) — Harvest Midstream has completed its acquisition of the Kenai LNG facility in Nikiski, Alaska, marking a key step in the company’s plan to redevelop legacy LNG infrastructure and strengthen Southcentral Alaska’s energy reliability. The purchase includes roughly 100 acres of industrial waterfront, 107,000 cubic meters of LNG storage, and dock infrastructure historically capable of handling vessels up to 138,000 cubic meters, equivalent to about 2.9 billion cubic feet of natural gas.
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“Today’s announcement is another milestone in delivering real energy solutions for Alaska and advancing America’s energy infrastructure,” said Jason C. Rebrook, Harvest CEO. “Earlier this year, we delivered the first-ever North Slope LNG to Fairbanks, and now we are building on that momentum by putting existing LNG infrastructure back to work to help meet Southcentral Alaska’s near-term gas needs and strengthen long-term energy reliability for the state.”
The company said it plans to use the facility to meet near-term regional gas needs through LNG imports while maintaining the option for future exports. Harvest is seeking an amendment to its existing FERC permit to expand import capacity and is in advanced talks with LNG suppliers and potential offtakers.
A final investment decision is targeted for the second quarter of 2026, with first LNG imports expected in early 2028, according to the company.
Harvest operates across the Cook Inlet and North Slope and holds a 49% stake in the Trans-Alaska Pipeline System (TAPS).
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U.S. natural gas and LNG exports rise as oil prices soften
Global oil markets are expected to ease in 2026, but the U.S. natural gas sector continues to tighten as liquefied natural gas (LNG) exports expand and domestic production growth slows, according to the U.S. Energy Information Administration’s (EIA) latest Short-Term Energy Outlook.
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The EIA projects Henry Hub natural gas prices will average about $4.00 per million British thermal units (MMBtu) in 2026, up 16% from this year, reflecting stronger LNG exports and steady winter heating demand. In contrast, global oil inventories are rising, putting downward pressure on crude prices even as gas markets strengthen.
Gas prices firm as exports expand
The EIA expects Henry Hub spot prices to rise to an average of $3.90/MMBtu this winter (November–March), following typical seasonal patterns of higher heating demand. Prices are then forecast to hold near $4.00/MMBtu in 2026 as U.S. LNG exports continue to grow and domestic production levels off.
“Flat production and strong export growth are expected to tighten natural gas balances,” the agency said.
U.S. LNG terminals are exporting gas at record levels. The EIA expects average LNG exports of 14.9 billion cubic feet per day (Bcf/d) in 2025, up 25% from last year, driven largely by rapid commissioning of the Plaquemines LNG facility in Louisiana. That project has come online faster than expected, prompting the EIA to raise its fourth-quarter export forecast by 3% from the prior month.
Exports are projected to increase another 10% in 2026, underscoring the U.S. role as the world’s leading LNG supplier.
In contrast to the tightening gas market, the EIA expects global oil inventories to build through 2026, exerting downward pressure on crude prices. Brent crude is forecast to average $54 per barrel in the first quarter of 2026 and $55 per barrel for the year, about $3 higher than last month’s forecast due to revised assumptions about Chinese stockpiling and ongoing Russian sanctions.
Lower crude prices will filter through to the retail level, with U.S. gasoline prices projected to fall below $3.00 per gallon in 2026 and diesel prices averaging $3.50 per gallon, both declines from 2024 levels.
While oil prices ease, electricity demand continues to grow—particularly in Texas and neighboring states. The EIA expects U.S. electricity sales to rise 2.4% in 2025 and 2.6% in 2026, led by demand from data centers and cryptocurrency mining facilities in the West South Central region.
Coal production, meanwhile, is forecast to remain steady above 500 million short tons (MMst) in 2026, buoyed by the reopening of several Appalachian mines and slower stock drawdowns at coal-fired power plants.
Outlook
The EIA’s forecast highlights diverging trends across the U.S. energy landscape. Oil and refined fuel prices are poised to soften amid growing inventories, but natural gas remains on a firmer trajectory as export capacity expands and new LNG projects ramp up.
By late 2026, the United States is expected to solidify its position as the world’s largest LNG exporter, even as domestic producers face limited output growth and infrastructure planners balance expanding export demand with system reliability.
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Major oil developer enters into Alaska LNG project
A global oil field developer announced that it inked a “strategic alliance” with Glenfarne Group, the majority owner of the proposed Alaska LNG Project.
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In a statement, Baker Hughes said it plans to supply the project with refrigerant compressors needed to liquefy natural gas and power generation equipment for the gas pipeline’s North Slope treatment plant.
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Canada names proposed Ksi Lisims LNG project for fast-tracking
Canada said on Thursday it will add the proposed Ksi Lisims LNG facility to its major projects list for fast-tracking, a designation the company behind the project said makes it more likely to proceed. Prime Minister Mark Carney made the announcement in Prince Rupert, British Columbia, where the facility would be located with direct shipping access to Asia. Ksi Lisims has a planned capacity of 12 million metric tons per year, which would make it Canada’s second-largest liquefied natural gas export terminal after Shell-led LNG Canada, which began operations this year.
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Carney is aiming to speed up natural resource project construction to boost the economy that has been damaged by U.S. tariffs.
The government created this year a major projects office tasked with streamlining approvals and helping to coordinate financing for large-scale infrastructure projects deemed in the national interest.
INVESTMENT DECISION EXPECTED NEXT YEAR
The proponents of Ksi Lisims — Houston-based Western LNG; a consortium of Canadian natural gas producers called Rockies LNG; and the Nisga’a First Nation, who own the land for the project — have not made a final investment decision to proceed.
But Western LNG CEO Davis Thames told Reuters inclusion on Canada’s major projects list brings Ksi Lisims closer to fruition, adding the proponents expect to decide whether to proceed early next year.
“It’s pretty obvious that the different constituents of the project will see this (designation) as being favorable,” Thames said, adding expedited permitting times would decrease the likelihood of construction delays once Ksi Lisims is under way.
“Time is money, and when you have to stop construction because you didn’t get a permit in time, that’s what just kills budgets,” he said.
Shell (SHEL.L), and TotalEnergies (TTEF.PA), have signed 20-year LNG purchase agreements with Ksi Lisims. The company is working to finalize other commercial agreements with LNG purchasers before committing to a final investment decision, Thames said.
Construction is already under way on the 900-km (560-mile) Prince Rupert Gas Transmission pipeline, which will transport natural gas from northeast B.C. to Ksi Lisims and was also on the government’s list.
Canada’s major projects office has also been tasked with collaborating with affected Indigenous groups to help fast-track infrastructure development.
Having the backing of the major projects office increases the odds of the project going ahead, but is not a guarantee that a positive final investment decision will be reached, said RBN Energy analyst Martin King.
“Locking up the needed financing is also something that needs to be finalized,” King said.
Carney’s government said fast-tracking the latest round of projects will spur private investment worth C$56 billion ($39.93 billion). Other projects announced on Thursday for inclusion on the fast-track list include the North Coast Transmission line – an estimated C$6 billion electrification project by BC Hydro that is expected to provide clean energy to the province’s LNG and mining industries – and the Crawford Nickel project, an open-pit nickel and cobalt mine in Ontario by Canada Nickel Company.
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Global LNG Development
US: Venture Global Bags Long-Term LNG Supply Contracts
United States liquefied natural gas (LNG) producer Venture Global Inc this week announced multiple long-term contracts to supply three Greek, Japanese and Spanish companies. Atlantic-See LNG Trade SA, formed this month by Greek companies Aktor Group and DEPA Commercial SMSA, committed to at least 0.5 million metric tons per annum (MMtpa) of United States-produced LNG for 20 years from 2030.
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“Under the SPA [sale and purchase agreement], Atlantic-See has the potential to expand its purchase commitment”, Venture Global said in a press release.
“This deal marks Greece’s first ever long-term LNG supply agreement with a U.S. exporter, launching a dynamic and growing partnership between Atlantic-See LNG and Venture Global”, Venture Global said.
The agreement between Venture Global and Atlantic-See LNG Trade was signed at the Partnership for Transatlantic Energy Cooperation summit between Central and Eastern European countries and the U.S.
Separately Venture Global said it had bagged a contract to supply Tokyo-based Mitsui & Co Ltd one MMtpa for 20 years from 2029.
“This collaboration between our two companies will strengthen energy security, enhance the balance of trade and deepen the long-standing ties between our nations”, said Venture Global chief executive Mike Sabel. “This agreement builds upon our existing long-term relationships with Japanese companies”.
Spain’s Naturgy also contracted Venture Global for one MMtpa for 20 years from 2030.
“The agreement represents Spain’s first long-term contract for American LNG since Venture Global’s first contract in 2018”, Venture Global said in another statement. “To date, Venture Global has supplied Spain with 35 cargos from its Calcasieu Pass and Plaquemines facilities”.
Sabel said, “This contract will positively impact the U.S. balance of trade with Spain and enhance energy security across the region”.
“The signing of this agreement, along with the strong commercial momentum we’ve achieved over the past six months, reflects the continued customer confidence in our company and the robust demand for LNG globally”, Sabel added.
In its latest quarterly report, Venture Global said it had exported 100 cargos totaling 372 trillion British thermal units (TBtu) in the third quarter, up 261 TBtu from the same three-month period last year.
Q3 revenue rose 260 percent year-on-year to $3.3 billion. Net profit was $429 million, compared to a net loss of $347 million for Q3 2024.
The profit increase “was largely driven by higher income from operations of $1.1 billion primarily due higher LNG sales volumes of $1.9 billion primarily at the Plaquemines Project, partially offset by lower LNG sales prices net of the cost of feed gas of $645 million at the Calcasieu Project due to the commencement of LNG sales under its post-COD SPAs in April 2025, non-cash favorable changes in interest rates swaps of $336 million and higher interest expense of $293 million”, Venture Global said.
“Consolidated Adjusted EBITDA for the three months ended September 30, 2025, increased $1.2 billion, or 439 percent, as compared to 2024 driven primarily by higher LNG sales volumes primarily at the Plaquemines Project, resulting in greater total margin for LNG sold”.
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Argentina: NOV awarded second contract for Argentina FLNG development
NOV has executed a contract to supply a second APL submerged swivel and yoke (SSY) system for Southern Energy SA’s floating LNG (FLNG) project in the Gulf of San Matías, offshore Argentina. This follow-up award builds on SESA’s ongoing FLNG development plans and reflects the company’s confidence in APL’s subsea mooring and transfer solutions. The project will utilise Golar’s MK II FLNG design with a capacity of 3.5 million tpy. With two FLNG units, Argentina is expected to export up to 6 million tpy of LNG.
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This project builds on APL’s joint development with Golar to evolve the SSY system for harsher environments.
The APL SSY is designed to provide safe mooring and uninterrupted gas transfer via subsea pipeline. By removing the need for a jetty, the system aims to reduce topside infrastructure, lower project complexity, and enable SESA to deliver LNG to market more efficiently, addressing key customer challenges in offshore export developments.
“We are honoured to receive this second contract from Southern Energy SA and support their LNG export expansion in Argentina. Advanced technology, great collaboration, and trusting relationships are essential for complex projects to succeed. I truly believe all factors are present here, and we are looking forward to continuing to support SESA in these two critical projects for Argentina’s gas export programme,” said Haavard Hjellseth, Managing Director, NOV APL.
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Australia: Jade Secures Preliminary Funding Deal for Mongolian CBM-to-LNG Project
Zhengzhou Langrun Intelligent Equipment Co Ltd has signed a non-binding letter of intent to provide up to $46 million (AUD 70 million) in financing for a coal bed methane (CBM)-to-liquefied natural gas (LNG) project by Jade Gas Holdings Ltd in Mongolia.
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The agreement is for the Red Lake gas field, part of the Australian company’s flagship project with the Mongolian government’s Erdenes Methane LLC to develop the Tavantolgoi XXXIII unconventional oil basin (TTCBM Project). Red Lake has 246 billion cubic feet of 2C gross unrisked contingent resources, according to Jade.
The Chinese CBM-focused gas equipment manufacturer would fund drilling and production for the next 18 wells in the field, Jade said in a stock filing. Jade has already drilled seven Red Lake wells according to the company.
The “non-dilutive financing” would also cover surface facilities for gathering, processing and liquefying gas produced from the field into LNG. The deal also includes “a low upfront capital outlay option, to be funded by future Jade revenue”, Jade said.
The parties agreed to consider expanding the terms to accommodate all 175 gas production wells in Red Lake’s first-phase development. Phase 1 involves 20 production wells, including two that came online June, according to Jade.
“Langrun’s expertise in the gas industry in China and in particular in CBM offers a great fit for Jade as the company seeks options to fast-track development of the Red Lake gas field and to optimize gas production for faster access to customer markets and ultimately early revenue”, Jade said.
“Subject to agreement of definitive documentation, and government and regulator cooperation and other approvals, the Red Lake gas field could potentially be developed to cover purification, pipeline and other transport, compression (for potential production of CNG), liquefaction (for production of LNG), refueling station construction, enabling gas sales for vehicle, industrial and other markets”, Jade said.
“Jade could provide the gas source, suitable land for construction of facilities, and operational rights, while Langrun will arrange the financing for drilling and associated production services, supply and install gas processing equipment and manage production operations”.
Jade added, “A binding agreement is subject to commercial flow rates being achieved at the first two production wells, regulator and Mongolian government approval”.
Langrun chief executive Wang Yongtao said, “We share in Jade’s view that there is a significant opportunity for gas in the southern Mongolian region, and Langrun has the experience and understanding to execute on this vision to take advantage of the gas demand in the region, particularly for LNG and CNG where we have a rich experience”.
“Jade has the potential for a large-scale, long-term energy project that can have a significant impact on the energy dynamic of the southern Mongolia and northern China region, and we want to be a part of that”, Wang added.
On Friday, Jade said it had issued two million shares without disclosure to investors.
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Greece: Naftogaz Secures Preliminary Deal for Winter LNG from Greece’s DEPA
Greece’s state-owned DEPA Commercial SMSA on Sunday signed a letter of intent (LOI) to supply Ukraine an unspecified volume of liquefied natural gas (LNG) from the United States for the 2025-26 winter via Ukraine’s state-owned Naftogaz Group.
This follows Naftogaz’s agreement earlier this month with Atlantic-See LNG Trade SA, formed early November by DEPA and Aktor Group, for the importation of LNG from the U.S. into Ukraine and other European countries.
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Naftogaz and Atlantic-See “agreed to jointly develop the supply of LNG from the U.S. to Europe and Ukraine through Greek LNG terminals and the Vertical Corridor”, Naftogaz said in a statement on its website November 7.
DEPA Commercial chief executive Konstantinos Xifaras said in an online statement Sunday about the LOI, “The supply of U.S. LNG will be facilitated through Atlantic-See, in which DEPA holds a 40 percent stake, underlining the company’s commitment to providing practical and secure energy solutions across Southeast Europe”.
DEPA Commercial said, “Under the framework of the prospective agreement, LNG volumes originating from the U.S. are expected to be transported through ‘Route 1’ [of the Vertical Corridor], offered jointly by the gas transmission system operators (TSOs) of Greece (DESFA), Bulgaria (Bulgartransgaz), Romania (Transgaz), Moldova (VestMoldTransgaz) and Ukraine (GTSOU)”.
Newly Proposed Gas Routes
Recently the TSOs requested their national regulators to approve more flows on the Vertical Corridor, a network of existing gas infrastructure allowing multidirectional flow across seven European countries, via two routes: Routes 2 and 3.
“TSOs request the regulators’ approval on the availability of Routes 2 and 3 until April 2026; and the possibility of simultaneous provision of Route 1, Route 2 and Route 3 special capacity products in competing auctions”, said a statement posted on DESFA’s website November 7, announcing a joint letter to regulators.
“All participating TSOs have agreed to apply significant discounts – ranging from 25 percent to 50 percent across their interconnection points, to encourage market use of the new capacity and facilitate diversified gas flows. The coordinated tariff reductions and the availability of multiple route options will help mitigate potential disruptions, support uninterrupted deliveries to Ukraine, and ensure the most efficient use of existing infrastructure across the region.
“The TSOs underline that as identified by the European Commission, the Trans-Balkan corridor, part of the Vertical Corridor, is a key component of the EU’s strategy to diversify gas transportation and phaseout reliance on Russian gas. Approving the availability of Routes 2 and 3 is directly in line with this strategy, as it leverages LNG and Caspian gas to reinforce long-term energy security and market integration”.
Route 2 would start at the Amfitriti interconnection point on the DESFA grid, cross the Greece-Bulgaria interconnector (ICGB) and continue through the Trans-Balkan corridor. Route 3 would originate at the ICGB pipeline’s interconnection point with TAP and continue through the same path, according to the statement.
“Faster approval of these additional products will significantly enhance the potential for LNG to reach Ukraine via Greek terminals, strengthening energy security and enabling traders to select the optimal supply routes based on their needs”, the statement said.
EIB Grant
On November 13 Naftogaz and the European Investment Bank (EIB) announced a grant of EUR 127 million ($147.3 million) for the procurement of gas for Ukraine, in addition to a EUR 300-milllion EIB loan to Naftogaz that was disbursed October for the same purpose.
The loans are guaranteed under the Ukraine Investment Framework, part of the European Union’s Ukraine Facility. The facility is a platform to mobilize up to EUR 50 billion – EUR 33 billion in loans and EUR 17 billion in grants – from 2024 to 2027, according to the European Council, which gave the final greenlight for the facility February 2024. The UIF aims to mobilize up to EUR 40 billion of investments for recovery, reconstruction and modernization, according to its implementer the European Commission.
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Khalifa Port Signs LNG and LPG Terminal Development Deals
Abu Dhabi’s AD Ports Group has signed two landmark agreements with Nimex Terminals aimed at transforming Khalifa Port into a leading regional and global trading hub for low-carbon energy and petrochemical logistics.
The agreements cover the development of the UAE’s first private sector Liquefied Natural Gas (LNG) and Liquified Petroleum Gas (LPG) terminal hubs, both designed to accommodate large deep-sea gas carriers. Valued at over AED 30 billion (US$8 billion) based on projected 50-year revenue streams, the deal will establish the critical infrastructure required for LNG and LPG bunkering, enabling Khalifa Port to support two of the fastest-growing alternative fuels in the global maritime industry.
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Under the terms of the agreements, AD Ports Group will invest up to AED 1.3 billion (US$354 million) in infrastructure development – including dredging works and jetty construction – while Nimex Terminals will invest up to AED 2.6 billion (US$700 million) in the construction of LNG and LPG storage tanks and associated superstructure.
The LNG terminal, covering an area of 130,000 m², will feature cryogenic storage facilities with a total capacity of 400,000 m³. The LPG terminal, occupying 90,000 m², will ultimately provide a total capacity of 280,000 m³. Both facilities will be equipped to handle import, export, and transshipment operations, supporting the growing energy demand from Asian markets and reinforcing the UAE’s role as a global energy logistics hub.
Development of the two terminals will take place in phases over a five-year period, with investments distributed over the same timeframe. Initial operations are expected by mid-2028, while steady-state operations are projected for 2031 for the LNG terminal and 2033 for the LPG terminal. This phased approach is designed to ensure early market readiness and to support medium- and long-term growth in LNG and LPG trade volumes across the region.
https://www.themaritimestandard.com/khalifa-port-lng-and-lpg-terminal-deals-signed/
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LNG as a Marine Fuel/Shipping
Taiwan: Evergreen orders 14 LNG-fueled mega-ships in nearly $3b fleet expansion
Evergreen Marine has confirmed a massive order for fourteen 14,000-TEU LNG-powered container ships, split evenly between Samsung Heavy Industries and Guangzhou Shipyard International, at a total price of $2.45–$2.9 billion. The new tonnage, adding 196,000 TEUs, will boost Evergreen to the world’s fifth-largest container line, ahead of ONE and Hapag-Lloyd, and underscores the industry’s accelerating shift toward LNG, with nearly 380 LNG-fueled boxships now on order globally. The announcement coincides with stronger Q3 results for Taiwan’s three major carriers compared with Q2, driven by pre-tariff cargo frontloading, though all reported significantly lower earnings than a year earlier.
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Govt clears PSO to finalise Qatar deal for 24 LNG cargoes
The government has given Pakistan State Oil sanction to seal a deal with Qatar before November 15 for diverting as many as 24 cargoes of LNG in 2026, keeping in view the difference in net proceeds. “As PSO has to close discussions on net proceeds differential before the deadline of November 15, 2025, it is proposed that the Petroleum Division and PSO are authorised to finalise ADP for 2026 with a cargo range of 24 to 29,” the Petroleum Division told the Economic Coordination Committee (ECC) in a recent meeting.
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Responding to the proposal, the ECC authorized PSO to strike the deal by November 15. During discussions, the Petroleum Division apprised ECC about the current demand for LNG and said that PSO had a surplus stock due to a constant decrease in consumption. Therefore, the proposed option was the optimal solution available.
Due to scores of challenges, especially the low offtake by power producers, there is renewed demand destruction in the gas system. Consequently, the Sui Northern Gas Pipelines Limited has surplus LNG.
As a mitigating measure, the Petroleum Division and Pakistan LNG Limited reached an understanding with Eni on the basis of which 11 cargoes were sold in the market in 2025 under the net proceeds differential formula.
The Petroleum Division and PSO are also working with Qatar Energy on the deletion of some cargoes for 2025 onwards. A surplus of approximately 177 cargoes has been estimated to accrue in a cumulative manner between July 2025 and December 2031 or 24 cargoes per year.
Petroleum Division submitted a summary to ECC
The Petroleum Division, in order to address the issue, submitted a summary to ECC, seeking authorization to take up the matter with the Qatari government. There were a few options. First was to reduce surplus cargoes on a mutual basis at any time. Second was to slash the surplus and the same quantity may be procured after 2031 by extending the contract period. The third option was to adopt the net proceeds differential formula for the remaining contract period.
It was decided that a separate summary would be placed before ECC for issuing necessary policy guidelines to the Oil and Gas Regulatory Authority to pass on the impact of net proceeds differential to power producers and other LNG consumers.
Pursuant to the approval, a delegation comprising the minister for petroleum, secretary petroleum, PSO MD, SNGPL MD, adviser to the prime minister and representatives of the Attorney General of Pakistan visited Doha from August 25 to 27, 2025.
Thereafter, a series of follow-up meetings were held at the Petroleum Division, where it was agreed that net proceeds differential was the preferred option. PSO conveyed it to Qatar Energy. The Ministry of Energy (Petroleum Division) stated that PSO had informed it that Qatar Energy showed its willingness for the net proceeds differential pertaining to 24 cargoes scheduled for delivery in 2026. In addition to this, Qatar Energy is willing to continue to be engaged and explore other more sustainable solutions for surplus management. The ECC considered the summary entitled “Update on Negotiation with State of Qatar for Mitigation of Surplus LNG” and it was approved.
https://www.theopinion.com.pk/govt-clears-pso-to-finalise-qatar-deal-for-24-lng-cargoes/
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Poland celebrates 400th delivery of liquefied natural gas
On Sunday, the Aktoras, a 299-metre-long tanker, unloaded a shipment of liquefied natural gas (LNG) at Poland’s regasification terminal in Świnoujście – the 400th such delivery that the facility on the Baltic coast has received since opening almost exactly a decade ago.
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The landmark emphasised how integral the terminal has become to Poland’s energy strategy, in particular the shift away from Russian supplies, which began well before the 2022 invasion of Ukraine but accelerated afterwards.
A record number of LNG deliveries have arrived at Świnoujście this year, accounting for around 40% of Poland’s gas demand. The country also aims to open one, and possibly two, more terminals in the coming years, as it seeks to become a regional hub, supplying gas to Ukraine, the Czech Republic and Slovakia.
The Aktoras unloaded a cargo of 160,000 cubic metres of LNG from the United States. After regasification (i.e. being converted from liquid to gas), it will amount to 96 million cubic metres of natural gas.
The delivery was the 71st received at Świnoujście this year – already well beyond the previous annual record of 62 deliveries received in 2023. The 2025 figure is likely to rise to 82 by the end of this year, says Gaz-System, Poland’s state gas transmission operator.
That has helped make “the Świnoujście terminal one of the pillars of building Polish energy sovereignty” since it opened in December 2015, declared Wojciech Wrochna, the government’s plenipotentiary for strategic energy infrastructure, on Sunday
“Today’s 400th LNG delivery is not only a significant operational event – it is proof of the government’s effectively implemented energy policy, which is delivering tangible results,” added Wrochna. “Poland has secured its own needs and can support the energy stability of countries in the region.”
Earlier this month, Poland’s energy ministry confirmed that it is in talks with the US – which is currently the country’s main LNG supplier – over acting as a regional hub for gas deliveries to Ukraine and Slovakia.
Shortly afterwards, Polish state energy giant Orlen signed an agreement with its Ukrainian counterpart, Naftogaz, to continue supplying Ukraine with American gas delivered via the Baltic as LNG. Orlen began doing so earlier this year.
To meet anticipated demand, construction recently began on a second terminal, to be located in Gdańsk, that will open in 2028 with an annual capacity of 6.1 billion cubic meters (bcm). That will boost the 8.3 bcm capacity of Świnoujście.
Last month, Gaz-System announced that it had begun gauging market interest from neighbouring countries in LNG imports, with the aim of assessing whether to build a second floating terminal in Gdańsk alongside the one already under construction.
In 2022, Poland also opened the Baltic Pipe, which brings gas from Norway to Poland across the Baltic Sea. Last year, it supplied around 6.75 bcm of gas, compared to 6.1 bcm that arrived as LNG in Świnoujście.
https://notesfrompoland.com/2025/11/17/poland-celebrates-400th-delivery-of-liquefied-natural-gas/
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Qatar: Qatar-Exxon LNG Plant in Texas Plans First Shipment in February
The Golden Pass liquefied natural gas terminal under construction in Sabine Pass, Texas. The Texas joint venture between QatarEnergy and Exxon Mobil Corp. is targeting February to load its first liquefied natural gas cargo, in what would be a major milestone for US exports of the fuel.
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The timeline could still change because initiating production at LNG export facilities is a complex procedure, according to people familiar with the matter, who asked not to be identified because they weren’t authorized to speak publicly. A Golden Pass spokesperson didn’t immediately respond to a request for comment.
Golden Pass LNG, located at the border between Texas and Louisiana, is 70%-owned by QatarEnergy while Exxon holds the other 30%. Exxon said previously that the venture was due to start LNG production by the end of the year.
The facility is part of an LNG boom that in the space of several years has turned the US into the world’s biggest exporter. Golden Pass will become the ninth operational US export plant. It’s slated to bring a total of 18 million tons a year of capacity online once fully completed, just as concerns are mounting that global supply could exceed demand.
One of the next steps in the startup process at Golden Pass is expected to involve an LNG cargo imported from Qatar that will be used to cool down the complex. The vessel Imsaikah is now heading toward Texas with an estimated arrival date of Nov. 29, according to shipping data compiled by Bloomberg, although vessel data is subject to change.
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Lithuania: For the first time, a cargo of natural gas ordered by a Ukrainian company has reached the Klaipėda LNG terminal
On Monday, a liquefied natural gas (LNG) cargo from the United Stats of America ordered by D.TRADING International SA, a subsidiary of DTEK Group, the largest private Ukrainian energy company, reached the Klaipėda LNG terminal operated by the international terminal operator KN Energies. Approximately 160 thousand cubic metres of U.S. LNG will be transferred into the tanks of the floating storage and regasification unit (FSRU) Independence from the LNG carrier GasLog Houston that arrived in Klaipėda port. A share of the LNG cargo delivered to Klaipėda will, after regasification, reach Ukraine via pipelines and international interconnector links.
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“After the brutal russian attacks on Ukraine’s energy infrastructure, Lithuania was quick to act – a cargo of LNG is already on its way to Ukraine. The Klaipėda LNG terminal is one of the busiest and most utilized in Europe, yet it also provides an opportunity to assist Ukraine – through it, we can help ensure gas supply and energy security for our partners. This is a concrete example of our solidarity and transatlantic cooperation. Together, we are seeking ways to ensure a reliable gas supply to Ukraine during the upcoming winter by making full use of Lithuania’s existing infrastructure,” said Minister of Energy Žygimantas Vaičiūnas.
The Ambassador of Ukraine to Lithuania Olha Nikitchenko noted: “Ukraine is entering another winter under relentless Russian attacks on our critical energy infrastructure. Day after day, Russia strikes purely civilian facilities that provide Ukrainians with heat, light, and the essential services people need simply to live. In such conditions, every reliable route for energy supply becomes a matter of national resilience. Access to the Klaipėda LNG terminal gives Ukraine something extremely important: confidence that even when our facilities are hit, we still have alternative ways to keep our system running. We are deeply grateful to Lithuania, one of the leaders in supporting Ukraine’s energy sector, for taking yet another meaningful step. It strengthens Ukraine, it strengthens our region, and it shows that in the face of terror, transatlantic unity sends a clear message: Russia may try to turn winter into a weapon, but together we will not allow it”.
The Ukrainian energy resources trader D.TRADING is a new client of the Klaipėda LNG terminal, and this is the company’s first cargo in Klaipėda. The possibility for the company to import and regasify approximately 1 terawatt-hour (TWh) of natural gas arose after booking the spot regasification capacities allocated by KN Energies.
“US LNG is key for Ukraine’s and Europe’s energy independence. This latest shipment reflects the vision of DTEK to be an energy bridge uniting US producers and a region that phasing out of dependence on russian gas. From terminals on the Baltic Sea and Mediterranean, we are working with Lithuania and US partners to develop cost-effective routes to get more gas flowing into Ukraine and neighbouring countries,“ said DTEK CEO Maxim Timchenko.
U.S. Ambassador to Lithuania Kara C. McDonald praised the shipment, saying, “the United States and Lithuania are firm partners in bringing reliable energy to the region – American natural gas strengthens the national security of the United States and our partners.”
KN Energies CEO Darius Šilenskis emphasizes that the decisions made more than a decade ago during the preparation of the LNG terminal project regarding the terminal’s operating model now make it possible to meet the energy needs of Lithuania, neighbouring countries, and also Ukraine, which is shaken by the aggressor’s war.
“Klaipėda LNG terminal was among the first in the world to apply the open-access principle and a multi-user regime in its operations. The pipeline interconnections with continental Europe that emerged a few years later proved the sense and benefit of the chosen model in every respect: a regional market has been created, and the terminal’s services can be used by those who need them most at a given time. The cooperation established with D.TRADING is also a commitment for us to ensure reliable terminal operations, as in this way we contribute in every possible way to Ukraine’s goal of diversifying energy supplies from reliable sources and overcoming emerging energy security challenges,” said D. Šilenskis.
Six clients from Lithuania, Poland, Latvia, Norway, and Estonia currently use the Klaipėda LNG terminal and have signed long-term contracts. KN Energies has also signed framework agreements with 18 potential clients, on the basis of which such companies may compete for spot regasification capacities allocated by the terminal operator up to four times per year, or for LNG terminal capacities offered on the secondary market.
In 2025, a total of 30 conventional-size LNG cargoes reached the Klaipėda LNG terminal, and 23,9 TWh of gas were regasified. The majority of the gas — 71% — was delivered by LNG carriers from natural gas liquefaction plants in the United States, while the remaining part reached Lithuania from Norway, Mauritania, Senegal, Trinidad and Tobago.
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Technological Development for Cleaner and Greener Environment Hydrogen & Bio-Methane
Aerzen to launch large hydrogen compressors
German air and gas compression supplier Aerzen is set to launch large compressors for the hydrogen industry. Speaking on the Energy Gang podcast from Wood Mackenzie, Sascha Sissiou, Sales Director for the Middle East and Africa at Aerzen, said, “We developed one of the biggest hydrogen compressors. It will be released in a month’s time [and is] a real step forward.”
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He said the business splits between compressors and blowers and covers a wide range of industrial applications.
Aerzen, with sales that topped €658.6m in 2024, is drawing on decades of experience with hydrogen compression. For compression in the low-pressure range, Aerzen believes screw compressors are a sensible solution or supplement to high-pressure compressors.
https://www.gasworld.com/story/aerzen-to-launch-large-hydrogen-compressors/2168433.article/
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SwRI Expands Hydrogen Testing Capabilities to Assess Gas Pipeline Compatibility
SwRI has expanded its Metering Research Facility to test hydrogen–natural gas blends, adding new injection and safety systems to study how hydrogen affects pipeline infrastructure, flow measurement and equipment performance. HOUSTON (P&GJ) — Southwest Research Institute (SwRI) has expanded its Metering Research Facility (MRF) to support the growing need to evaluate how natural gas pipelines and related infrastructure perform when blended with hydrogen.
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The upgrades, funded internally, allow SwRI to test hydrogen–natural gas mixtures across a range of operating conditions. The initiative draws on the Institute’s experience in energy, power and automotive engineering to help utilities, pipeline operators and equipment manufacturers understand how hydrogen blending affects system performance and safety.
“Blending hydrogen into natural gas pipelines could prove to be a promising, cost-effective pathway to reduce greenhouse gas emissions using existing natural gas infrastructure,” said MRF Manager Adam Hawley. “SwRI’s goal is to have a research test bed to support these activities.”
SwRI repurposed an existing gas loop at the MRF — originally designed for flow measurement and compression studies in low-pressure natural gas service — to accommodate hydrogen blends. The expanded setup includes a hydrogen injection system and new safety systems to detect both hydrogen and natural gas leaks.
“SwRI originally designed the MRF to accurately measure natural gas flow, and we’ve now adapted the facility to include hydrogen,” said Assistant Program Manager Matthew Godush. “This leverages years of research and infrastructure already in place.”
Initial studies will focus on blends containing 5% to 25% hydrogen. The facility can simulate transmission, distribution and end-use scenarios and provide flow measurement testing, gas analysis, compatibility evaluations, endurance testing, and leak detection studies.
“Our goal is to show, through testing and research, the process needed to upgrade natural gas infrastructure to accommodate hydrogen,” Godush said. “Demonstrating the efficiency and feasibility of these applications creates a large and economically viable case for hydrogen as a reliable fuel source.”
SwRI plans to expand its multidisciplinary hydrogen research program to support broader industry decarbonization efforts.
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Germany: The Czech Republic and Germany Are Strengthening Cooperation to Build a Joint Hydrogen Infrastructure
The Ministry of Industry and Trade (MIT) is strengthening cooperation with the German Federal Ministry of Economic Affairs and Energy to build an interconnected hydrogen infrastructure between the two countries. The first meeting of the joint working group, which will coordinate the project to connect the hydrogen gas transport systems of the Czech Republic and Germany, took place in Berlin.
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“Hydrogen can significantly contribute to the energy transformation and strengthen our energy security. Together with Germany, we want to build an infrastructure that will connect our industries, strengthen regional self-sufficiency and enable the use of clean energy sources across Europe,” says Minister of Industry and Trade Lukáš Vlček , adding: “The Czech Republic thus confirms its ambition to be an active partner in the development of the European hydrogen economy.”
The working group was established on the initiative of the Ministry of Industry and Trade and the Federal Ministry of Economic Affairs and Energy and also brings together representatives of gas system operators and energy regulators. Its task is to jointly address the project, legislative, regulatory and economic aspects of hydrogen transport between the two states.
“The import of hydrogen via Germany can significantly contribute to the decarbonization of the Czech chemical industry and other segments. The planned connection of the Czech and German hydrogen networks represents an important step towards connecting the main European hydrogen corridors,” says Tomáš Ehler, Senior Director of the Nuclear Energy and New Technologies Section.
“A reliable hydrogen infrastructure does not end at national borders. With this working group, we are laying the foundations for a strong and shared energy future in Central Europe – climate-neutral, interconnected and secure,” adds Bernhard Kluttig, Director General of the Federal Ministry of Economic Affairs and Energy.
The establishment of the working group follows the joint declaration on cooperation in the field of hydrogen infrastructure, which both ministries signed on April 25, 2025. This step translates political commitment into concrete measures and confirms the will of both countries to develop a closely linked hydrogen strategy in Europe – focusing on security of supply, economic efficiency and technological sovereignty.
The working group also includes NET4GAS, the operator of the Czech gas transmission system, which has been preparing for its future use for hydrogen transport using the existing pipeline for a long time. “Our company is actively involved in the preparation of a reliable cross-border hydrogen infrastructure. We are part of the Czech-German Hydrogen Interconnector (CGHI) initiative, which is preparing a project to interconnect hydrogen systems between the Czech Republic and Germany,” said Michal Slabý, CEO of NET4GAS .
The planned interconnection of hydrogen systems is also an important prerequisite for ensuring available renewable hydrogen for Czech industry and for the Czech Republic’s involvement in European hydrogen corridors, which will form the backbone network of new emission-free energy.
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US: BASF and ExxonMobil plan hydrogen pyrolysis plant in Texas
Chemicals company BASF and oil and gas firm ExxonMobil have unveiled plans for a demonstration plant that uses methane pyrolysis technology to produce up to 2,000 tonnes of low-carbon hydrogen and 6,000 tonnes of solid carbon product a year.
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The proposed plant would be located at ExxonMobil’s Baytown complex in Texas and would use existing natural gas infrastructure.
The two companies have signed a joint development agreement to co-develop the methane pyrolysis technology and advance it toward commercial scale.
Methane pyrolysis uses electricity to split natural gas or biomethane into hydrogen and solid carbon without generating carbon dioxide, and it uses about five times less electricity than water electrolysis and requires no water.
BASF has worked on the technology for more than a decade and has developed what it refers to as a superior reactor concept, validated at its test plant in Ludwigshafen, Germany.
The project received funding from the German Federal Ministry of Research, Technology and Space (BMFTR).
Dr Stephan Kothrade, Chief Technology Officer at BASF, said, “By combining BASF’s process innovation with ExxonMobil’s scale-up expertise, we are bringing this cost-efficient low-emission hydrogen solution closer to economically viable industrial deployment.”
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