NGS’ NG/LNG SNAPSHOT April 1-15, 2025
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NATIONAL NEWS
City Gas Distribution & Auto LPG
CNG price up by 1.5, piped cooking gas by rupee
Mumbai: After no hike for over three months, the price of Compressed Natural Gas (CNG) across the Mumbai metropolitan region will increase by Rs 1.5 per kg, while the piped cooking gas will also be hiked by a rupee per unit from Wednesday. With the hikes, the revised price of CNG in Mumbai, Thane, and other parts of MMR will be Rs 79.50 per kg. The revised price of piped gas will be Rs 49 per kg.
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A substantial number of public transport vehicles, such as autos, taxis, and buses across the region, depend on CNG for daily fuel. From Feb 1, the fares for autorickshaws and taxis in Mumbai were hiked by Rs 3 in MMR, considering the rising fuel costs as one of the factors. The CNG price was hiked twice in Nov and for a third time in Dec last year. This is the fourth hike in CNG rates in six months.
A senior official from Mahanagar Gas Limited (MGL) said, “On account of the increase in the price of domestic gas coupled with an increase in the exchange rate, MGL is constrained to increase domestic PNG price by one rupee/unit and CNG price by Rs 1.5/kg in and around Mumbai from April 9.”
The official stated, “Even after the above revision, CNG offers attractive savings of about 47% and 12% as compared to petrol and diesel respectively at current price levels in Mumbai, while piped cooking gas continues delivering unmatched convenience, safety, reliability, and environmental friendliness to consumers.”
MGL now has 358 CNG stations across its operational areas in MMR. The private car population on CNG is approximately 5 lakh across MMR, and many car buyers now opt for dual fuel, which includes petrol and CNG.
Mumbai has about three lakh autos and around 20,000 kaali peeli taxis which depend on the green fuel. More than 24 lakh househelds in MMR depend on pipe gas supply for cooking.
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CNG Price Hike Incoming As India Raises APM Gas Price For The First Time In Two Years
Natural gas produced by ONGC Ltd. and Oil India is supplied as piped natural gas to kitchens and turned into compressed natural gas for automobiles. India has raised prices of domestically produced natural gas for the first time in two years, indicating that a CNG price hike is around the corner.
Effective April 1, the APM gas price has been raised to $6.75 per million british thermal units from $6.50 per MMBtu, according to a notification of the petroleum planning and analysis wing of the Ministry of Petroleum and Natural Gas.
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APM gas is the natural gas produced by Oil and Natural Gas Corp. Ltd. and Oil India Ltd. from fields alloted to them on a nomination basis. This gas is then sold to customers at “administered pricing mechanism”.
This gas is supplied as piped natural gas to household kitchens and turned into compressed natural gas for automobiles.
The hike, a first in two years, is in accordance with the roadmap that was laid out by the government.
In April 2023, the Union Cabinet accepted an expert committee report to price the bulk of domestically produced natural gas at 10% of the monthly average import price of crude oil with a floor of $4 per million British thermal unit and a cap of $6.5.
In doing so, the government had tinkered with the recommendation of a $0.50 per mmBtu annual increase till full deregulation in 2027. The Union Cabinet decided that rates will not change for two years and will be increased by $0.25 annually thereafter.
The hike announced on Monday is in line with that decision.
According to the Petroleum Planning and Analysis Cell, the APM gas price for April 1 to April 30, 2025, should have been $7.26 per MMBtu, going by the 10% indexation to the crude oil price. But this was subject to the ceiling price. The ceiling price has been raised from $6.50 per MMBtu to $6.75. This ceiling will be effective from April 2025 to March 2026 and will rise by another $0.25 per MMBtu in April next year.
Prior to April 2023, the price of gas produced from fields covered under the APM regime, which accounts for 70% of domestic gas production, was determined semi-annually based on formula that benchmarked it to average international prices at four gas trading hubs.
Subsequent to the April 2023 decision, APM gas prices are revised on a monthly basis but are subject to ceiling and floor prices. The ceiling price now is $6.75 per MMBtu.
APM gas prices had seen wide fluctuations in the years running up to the April 2023 decision. From a low of $1.79 per mmBtu in 2021 to a high of $8.57 for the six-month period ending March 2023.
According to the key recommendation of the committee accepted by the government, the APM formula is now revised and determined as a 10% slope to crude oil prices, but with a floor and ceiling price of $4 per mmBtu and $6.5, respectively.
Two different formulas govern rates paid for gas produced from legacy or old fields of national oil companies like ONGC and OIL and for newer fields lying in difficult-to-tap areas like deepsea.
The rate for difficult fields like KG-D6 of Reliance Industries Ltd. has been set at $10.04 per MMBtu for six months beginning April 1 compared to $10.16 in the preceding six-month period, according to the PPAC.
https://www.ndtvprofit.com/law-and-policy/biz-gas-price-11
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MP asks GGL to prepare master plan for progress of piped natural gas distribution project
Dakshina Kannada MP Capt. Brijesh Chowta on Monday instructed the GAIL Gas Ltd. (GGL) to prepare a master plan for the smooth progress of on-going piped natural gas distribution project within the jurisdiction of Mangaluru City Corporation (MCC). In addition, he said, a co-ordination committee should be formed for the hassle free implementation of the project, Capt. Chowta said.
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The MP was speaking at a meeting called by him to review the overall progress of the project in the district. He instructed the GGL to complete the city gas distribution project (CGD) on priority.
The co-ordination committee, headed by the Deputy Commissioner, should have senior officials of MCC, MESCOM, BSNL, KUIDFC as those departments have their underground utility lines whose safety also matters while GGL lays its underground gas distribution pipelines. The committee should meet periodically to sort out issues with mutual co-ordination, the MP said.
The city MLAs, D. Vedavyasa Kamath and Y. Bharat Shetty, highlighted that GGL should cover the trenches dug up for laying its pipelines once the civil works got over. Leaving the trenches open for long has been causing inconvenience to people, they said.
The GGL should also repair water supply lines damaged during the implementation project immediately, they said.
The MP and MLAs instructed the GGL to work in co-ordination with stakeholder departments for the fast implementation of the project.
“Now the company has taken up the project in the city in a haphazard manner without proper planning,” the MP pointed out.
The Deputy Commissioner M.P. Mullai Muhilan said that the company should have a road map before taking up the project works in a locality. The road map should be applicable to all 60 wards of MCC, Mr. Muhilan who is also the administrator of MCC said.
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Natural Gas/ Pipelines/ Company News
Mahanagar Gas Limited announces price hike for domestic PNG and CNG
The Mahanagar Gas Limited (MGL) has announced a price increase for domestic Piped Natural Gas (PNG) and Compressed Natural Gas (CNG) in and around Mumbai, an official statement said on Tuesday. The revised price of domestic PNG will rise by Re 1 per Standard Cubic Meter (SCM), while the price of CNG will increase by Rs 1.50 per kilogram, the official statement said.
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With this revision, the revised delivered prices, inclusive of all taxes, for DPNG will be Rs. 49 per SCM, while CNG will be priced at Rs. 79.50 per kilogram. The increase comes in response to the rising cost of domestic gas, as well as the impact of the fluctuating exchange rate.
It said, “On account of increase in the price of domestic gas coupled with increase in exchange rate, Mahanagar Gas Limited (MGL) is constrained to increase domestic PNG price by Re. 1/SCM and Compressed Natural Gas (CNG) price by Rs.1.50/Kg in and around Mumbai effective midnight of April 08, 2025/morning of April 09, 2025. Accordingly, the revised prices inclusive of all taxes of DPNG will be Rs. 49/SCM and CNG will be Rs 79.50/Kg in and around Mumbai.”
The statement said, “Even after the above revision, MGL’s CNG offers attractive savings of about 47% and 12% as compared to petrol and diesel respectively at current price levels in Mumbai, while MGL’s domestic PNG continues delivering unmatched convenience, safety, reliability and environmental friendliness to consumers.”
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GSPL Commissions Chhara Gas Pipeline, Enhancing India ‘ s Natural Gas Supply
Gujarat State Petronet (GSPL) has commissioned an 18 MMSCMD natural gas pipeline linking the 5 MMTPA LNG regasification terminal at Chhara, Gir-Somnath, to the national gas grid.
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Built at a cost of Rs 6.5 billion, the 36-inch-diameter pipeline, developed by Mumbai-based Ace Pipeline Contracts, runs near the eco-sensitive Gir National Park. Advanced construction techniques, including automatic welding, were used to accelerate completion.
The Chhara terminal, operated by HPCL LNG, a subsidiary of HPCL, strengthens India’s push to increase natural gas usage to 15 per cent of its energy mix by 2030.
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Regulator moots tweaks in gas pipeline tariffs
PNGRB proposes changes in gas pipeline tariffs, aiming to reduce costs for CNG and PNG users across zones, boosting investments and gas consumption. Startups like Swiggy, FirstCry, and Ola Electric underperform in FY25. The Petroleum and Natural Gas Regulatory Board (PNGRB) has proposed a new framework for determination of tariffs for pipelines carrying gas to users. It also recommended charging city gas entities selling CNG and piped cooking gas to households at the lowest rates in order to bring investments and increase gas consumption.
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The regulator floated a public consultation document for changing the zonal tariffs levied on pipelines that carry natural gas from fields producing it or from import ports, to users such as power plants, fertiliser units, or city gas entities.
“The proposed changes are progressive and make delivered domestic gas costs for CGDs nearly uniform. However, as overall transmission costs are low versus gas costs, the impact is small. CGDs in the hinterland, such as IGL, will benefit. They will be largely neutral for MGL and marginally positive for GAIL,” said Kotak Institutional Equities. The firm noted that as unified tariffs are already in place across the national gas grid, and as the pipeline tariffs are a small part of the overall gas costs for end-customers, the impact is relatively small.
“For IGL, we estimate an overall benefit of Rs 42/mmbtu (US$0.5/mmbtu), with EBITDA benefit of Rs 1.6/scm. This will bring some respite for IGL, which has struggled to raise price in Delhi NCT. For MGL, the impact will be minimal,” the brokerage said.
PNGRB is responsible for regulating the transmission tariffs for natural gas pipelines which are fixed to provide a 12% normative return on capital employed. The tariffs were allocated along the length of the pipeline which increased further with the growing distance from the gas source, resulting in higher tariffs for consumers located at a farther distance.
“A public consultation document has been webhosted for seeking comments from stakeholders on various aspects of tariff regulations like reducing the unified tariff zones to two from three, levying zone one unified tariff to all the CNG and piped natural gas (PNG)-domestic customers,” the regulator said.
In November 2020, a unified tariff for all consumers connected to the natural gas grid was proposed which was later implemented from April 1, 2023.
PNGRB divided the entire length of a pipeline carrying natural gas into three zones – up to 300 km, from 300 km to 1,200 km, and more than 1,200 km, with tariffs of 52.5% of unified tariff for Zone 1 and 75% for Zone 2, against the usual practice of every incremental 300 km of pipeline from the gas injection point being classified as the successive zone with successively higher tariffs.
Under the new proposal, 66.17% of the unified tariff will be charged for the first tariff zone and the 100% for users on either size of the zone-1. However, CNG and PNG-domestic users anywhere in the country, irrespective of the distance from the source, will be charged zone-1 tariff.
“This is expected to make natural gas even more competitive to liquid fuels,” PNGRB said.
The proposals also include incentivising the isolated network operators/ pipelines, equal distribution of benefit of volumes beyond the normative threshold with the consumers and pipeline operators and usage of such benefits by pipeline operators for creation of pipeline infrastructure, policy for long term procurement of system use gas (SUG) by the pipeline operators, etc.
The country plans to have 120 million PNG connections and 17,500 CNG stations by 2030. As of December 2024, the country has 7,395 CNG stations and 14 million PNG domestic connections.
Earlier in 2020 and 2022, PNGRB brought various amendments to boost investment and gas consumption in far away regions. Before this, pipeline tariffs increased with distance, especially from gas fields in eastern and western offshore.
In 2023, PNGRB implemented the unified tariff system to standardise natural gas transportation charges across the national gas grid. The levelised unified tariff for 2023-24 was set at ₹73.93 per million British thermal units, with zonal tariffs apportioned as ₹39.45 per mmBtu for Zone-1, ₹74.97 per mmBtu for Zone-2, and ₹99.90 per mmBtu for Zone-3.
https://www.financialexpress.com/business/regulator-moots-tweaks-in-gas-pipeline-tariffs-3794574/
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Guwahati: Pipes laid, but the flow of gas remains a non-starter
Years after ambitious promises of a citywide piped natural gas (PNG) network, Guwahati residents are still waiting for gas to flow through the pipelines. GUWAHATI: Years after ambitious promises of a citywide piped natural gas (PNG) network, Guwahati residents are still waiting for gas to flow through the pipelines. Despite widespread installation of infrastructure by Purba Bharti Gas Private Limited (PBGPL), there has been no progress on actual gas supply-leaving citizens exasperated and questioning the project’s viability.
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The PNG project, touted as a cleaner and more economical alternative to traditional LPG cylinders, was expected to revolutionise domestic energy use in the city. PBGPL had earlier announced that gas supply would begin in early 2025, starting with the Zoo Road area. Pipelines have since been laid in multiple localities, including Narengi, Six Mile, Beltola, Bhetapara, and Beharbari.
But with no gas flowing, residents are left staring at unused infrastructure and a series of broken promises.
Speaking to this reporter, a PBGPL official said, “We have laid pipes from Zoo Road to Narengi, Six Mile, Beltola, Bhetapara, and Beharbari. In the first phase, we plan to provide gas in the Zoo Road area. But GAIL is yet to provide the gas.”
The company has cited lack of gas supply from GAIL as the primary reason for the delay, but the explanation has done little to ease public concern.
Meanwhile, multiple civic projects across the city have further complicated the situation. In areas where pipelines were installed, roadworks and infrastructure development have disrupted or damaged the network, raising fears that the pipes may become obsolete before they are ever put to use.
A resident of Guwahati expressed, “The roads were dug up for months, and we dealt with traffic congestion and inconvenience. Now, the pipelines are lying unused. What was the point of this entire thing if there is no gas supply?”
Adding to the confusion is the lack of a fixed timeline. While the initial rollout was expected this year, PBGPL has not committed to any specific date for when households can expect to receive piped gas. “There are several factors involved, and until GAIL provides the gas, we cannot move forward,” said a company representative.
Consumer rights groups and citizen forums are now demanding greater accountability from both PBGPL and the Assam government. They argue that the public has been misled, and without transparency, the project risks becoming yet another infrastructural failure in the city’s growing list of unmet development promises. With no clear path forward, residents are left waiting-caught between unfulfilled assurances and a lack of coordination that threatens to turn the piped gas project into a missed opportunity.
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GAIL opens fresh round of inviting proposals for equity investment in start-ups
GAIL on Tuesday launched the 10th round of its initiative ‘GAIL Pankh’ through which interested Start-Ups can apply for equity investment New Delhi: Continuing its commitment to support innovative Start-Ups, GAIL (India) Limited on Tuesday launched the 10th round of its initiative ‘GAIL Pankh’ through which interested Start-Ups can apply for equity investment from the Maharatna PSU.
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They can apply through the link ‘GAIL Pankh’ on GAIL website https://gailonline.com. The 10th round will remain open from April 1, 2025 till May 31, 2025. Start-Ups operating in focus areas which mainly include Natural Gas, Petrochemicals, Energy, Project management, E-commerce, Fintech, IoT and Data mining, Environment, Health, Social, Security and Safety, may apply for funding.
GAIL has a corpus of Rs 500 crore for its Start-Up initiative.
‘GAIL Pankh’ underscores GAIL’s dedication to drive excellence through innovation, collaboration and meaningful community engagement. It was launched in 2017 and till date, GAIL has conducted nine rounds for solicitation of investment proposals.
Recently, GAIL received the prestigious ‘Start-Up Excellence Award’ in the ‘Investment in Start-Ups’ category at the Governance Now 11th PSU Awards. The award recognises GAIL’s significant contribution and commitment in supporting and investing in innovative Start-Ups.
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IGL board clears ₹2,066 crore solar project in Rajasthan through JV with RVUNL
New Delhi: Indraprastha Gas Limited (IGL) said its board has approved the establishment of a 500 MWp solar power plant in Rajasthan with an estimated investment of ₹2,066 crore. The project will be implemented through a joint venture with state-run Rajasthan Vidyut Utpadan Nigam Limited (RVUNL).
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The solar plant will be located in Bikaner district. IGL will hold 74 per cent equity in the proposed joint venture company while RVUNL will retain the remaining 26 per cent. The joint venture will receive land from RVUNL in its upcoming solar park and will facilitate power evacuation infrastructure.
The project will be financed through a combination of debt and equity and is expected to be completed within 18 months from the formation of the joint venture. The proposal has been approved by the RVUNL Board and is currently awaiting clearance from the Rajasthan state cabinet.
IGL stated that it has formally identified renewable energy as a key business segment in its diversification strategy. The 500 MWp solar project is part of its plan to build a 1 GW renewable energy portfolio over the next 2 to 4 years.
“By leveraging strategic partnerships and investing in sustainable technologies, IGL is poised to redefine the energy paradigm,” the company said in a statement.
IGL, India’s largest city gas distribution company, currently handles approximately 10 Million Metric Standard Cubic Meters Per Day (MMSCMD) of gas. The company said it continues to invest in infrastructure and marketing to strengthen its position in the energy sector.
The project will be implemented through a joint venture with state-run Rajasthan Vidyut Utpadan Nigam Limited (RVUNL).
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IGL, Mahanagar Gas, Adani Total Gas shares decline; ONGC gains after government hikes APM gas price
APM gas is provided to city gas distributors for supply to CNG and residential PNG segments, which together account for 60 per cent of their sales volume. Shares of the city gas distribution companies such as Indraprastha Gas Limited (IGL), Mahanagar Gas Limited (MGL), GAIL India (GAIL) and Adani Total Gas edged lower in trade on Tuesday, April 1 after the government on Monday increased price of natural gas produced from old legacy fields called APM – the key input used to make CNG.
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On the flipside, shares of Oil and Natural Gas Corporation (ONGC) and Oil India (OIL) rose 2.06% and 0.61% respectively as they produce APM gas from fields that were given to them on a nomination basis.
APM gas is provided to city gas distributors for supply to CNG and residential PNG segments, which together account for 60 per cent of their sales volume.
Following April 2023 decision, APM gas prices are revised on a monthly basis but are subject to ceiling and floor prices. The ceiling price now is $6.75 per MMBtu.
APM gas prices had seen wide fluctuations in the years running up to the April 2023 decision. From a low of $1.79 per mmBtu in 2021 to a high of $8.57 for the 6-month period ending March 2023.
As per the key recommendation of the committee accepted by the government, the APM formula is now revised and determined as a 10 per cent slope to crude oil prices, but with a floor and ceiling price of $4 per mmBtu and $6.5, respectively.
This is the first increase in the APM gas price in two years and in accordance with the roadmap that was laid out by the government.
In April 2023, the Union Cabinet accepted an expert committee report to price the bulk of domestically produced natural gas at 10 per cent of the monthly average import price of crude oil with a floor of $4 per million British thermal unit and a cap of $6.5.
In doing so, the government had tinkered with the recommendation of a $0.50 per mmBtu annual increase till full deregulation in 2027. The Cabinet decided that rates will not change for two years and will be increased by $0.25 annually thereafter.
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GAIL (India) commissions 96.6% of Jagdishpur – Haldia – Bokaro – Dhamra Pipeline project
GAIL (India) has completed laying of over 97.6 % of the integrated Jagdishpur Haldia Bokaro – Dhamra Pipeline (JHBDPL), popularly known as Pradhan Mantri Urja Ganga, carrying Natural Gas to Eastern and North-Eastern part of India. Of this, almost 96.6 % has been put under commercial operations.
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The integrated JHBDPL including Barauni Guwahati Pipeline having an authorized pipeline length of 3,306 km passes through Uttar Pradesh, Bihar, Jharkhand, Odisha, West Bengal and Assam. Presently, 3,227 km of pipeline section has been laid and 3,119 km of Pipeline Section including Phulpur Dobhi Bokaro Durgapur, Bokaro Angul Dhamra, Dobhi Barauni Guwahati Pipeline sections have already been put under commercial operation.
The pipeline is presently transporting 12.26 Million Standard Cubic Meter Per Day (MMSCMD) of Natural Gas including supplies to four fertilizer plants, two refineries (Barauni and Paradip refineries), industrial consumers and 32 City Gas Distribution (CGD) networks including Varanasi, Patna, Ranchi, Jamshedpur, Bhubaneshwar, Cuttack, Kolkata etc. along pipeline route.
With respect to Durgapur Haldia Section (294 km), GAIL has already put 132 km of Pipeline section upto Kolkata under commercial operation. Further out of balance 162 km of pipeline section to Haldia, 103 km of pipeline laying has been completed. GAIL is also laying Dhamra Haldia Section having an authorized pipeline length of 240 km of which GAIL has already laid 198 km of pipeline. Due to limited availability of Right of Use (RoU), the completion of Durgapur Haldia Section and Dhamra – Haldia Section of JHBDPL expansion is being extended from March 2025 to December 2025.
With the completion of balance section of Durgapur Haldia and Dhamra Haldia Pipeline, GAIL will transport Natural Gas to Haldia refinery, CGD Howrah, Hooghly, Purba Medinipur, Paschim Medinipur and other industrial consumers along the pipeline route.
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Policy Matters/ Gas Pricing/ Others
MoPNG sets April gas price at $7.26/mmBtu; deepwater cap till Sept $10.04
The ministry of petroleum and natural gas has notified the price of domestic natural gas for the period from April 1 to April 30, 2025, as $7.26 per million British thermal units (mmBtu) on a Gross Calorific Value (GCV) basis. New Delhi: The ministry of petroleum and natural gas has notified the price of domestic natural gas for the period from April 1 to April 30, 2025, as $7.26 per million British thermal units (mmBtu) on a Gross Calorific Value (GCV) basis.
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The Petroleum Planning & Analysis Cell (PPAC), in a notification dated March 31, 2025, said, “In accordance with MoPNG’s Notification No.L-12015/1/2022-GP-I dated 7 April 2023, the price of domestic natural gas for the period 1st April 2025 to 30th April 2025 is notified as US$ 7.26 /MMBTU on Gross Calorific Value (GCV) basis.”
It further stated that for gas produced by Oil and Natural Gas Corporation (ONGC) and Oil India Ltd (OIL) from their nomination fields, the price shall be subject to a ceiling of $6.75/mmBtu on GCV basis for the same period, in accordance with Para 4 of the notification dated 7 April 2023.
In a separate notification issued on the same date, the ministry also announced the ceiling price for gas produced from difficult fields such as deepwater, ultra deepwater, and high-pressure-high-temperature (HPHT) areas. The price ceiling for such gas has been set at $10.04/mmBtu for the period from April 1 to September 30, 2025.
The second notification stated, “In accordance with Ministry of Petroleum and Natural Gas, Govt of India, Notification no. O-22013/27/2012-ONG-D-V (Vol-II) dated 21.03.2016 for marketing including pricing freedom for gas being produced from discoveries in Deepwater, Ultra Deepwater and High Pressure-High Temperature areas, the gas price ceiling for the period 1st April 2025 – 30th September 2025 is US$ 10.04/MMBTU on Gross Calorific Value (GCV) basis.”
The notifications were sent to the Director General of Hydrocarbons and the Chairmen and Managing Directors of ONGC and OIL, with copies marked to officials including the Petroleum Secretary, Additional Secretary, and Joint Secretaries in the Ministry.
These price levels are revised periodically by the government based on prevailing market dynamics and policy guidelines.
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Natural gas to cost more as govt raises price cap after 2 years, jury out on CNG hike
NEW DELHI: The price of natural gas produced from legacy fields of state-run ONGC and Oil India Ltd. will increase by nearly 4% from today (April 1) after the government raised the cap. This move will have a marginal impact on city gas operators, but the jury is out on whether it will immediately lead to an upward revision in retail rates of CNG and PNG.
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According to a notification from the oil ministry’s market tracker, Petroleum Planning & Analysis Cell, the price of gas has been reduced to $7.26 per unit (million British thermal unit) for April from $7.8 in March. Still, the effective price for consuming industries has increased by 25 cents because the Centre simultaneously raised the cap of $6.50 unit to $6.75.
The government had in April 2023 linked domestic gas pricing to the ‘Indian basket’ — or the mix of crude bought by the Indian refiners — after scrapping the earlier formula based on benchmark rates in gas-surplus markets such as the US, Canada, Europe and Russia. The revised formula, based on recommendations by a panel led by eminent economist Kirti Parikh, set the domestic gas price at 10% of the monthly average of the Indian Basket in the previous month, with a floor of $4 and a cap of $6.50 per unit to protect producers and consumers from volatility.
The government, however, tempered the Parikh panel’s recommendation to raise the price cap by 25 cents annually till deregulation by 2027. It locked the cap for a period of two years and reduced the annual increase to 25 cents from April 2025. The cap kept the effective price for consuming industries steady at $6.50 per unit despite higher notified rates. The upward revision in the cap, as expected, will now lead to the first increase gas prices in two years.
The government allots legacy gas from old fields for mostly fertiliser units and PNG operations. Due to a reduction in allocation as a result of falling production, the share of legacy gas in the overall portfolio of city gas operators has dropped sharply over the years, making them dependent on imported fuel as demand rises. Fertiliser units will also not feel the pinch due to government subsidy.
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India’s natural gas consumption to rise 60% by 2030 under ‘Good to Go’ scenario
India’s natural gas consumption is expected to climb by nearly 60 per cent by 2030, pushed by growing demand in the city gas distribution (CGD) sector and increased use across transport, cooking, and industry. A new study by the petroleum and natural gas regulatory board (PNGRB) revealed that daily gas consumption are likely to rise from 188 million standard cubic metres per day (mmscmd) in 2023–24 to 297 mmscmd by 2030 under the “Good-to-Go” scenario.
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This scenario assumed moderate economic growth and policy progress in line with current trends and government commitments. Looking further ahead, demand is projected to reach 496 mmscmd by 2040 under the same scenario.
However, under a more optimistic “Good-to-Best” outlook, factoring in favourable policies, faster development, and greater investments, consumption could jump to 365 mmscmd by 2030 and hit 630 mmscmd by 2040.
The CGD sector, which includeds supplying compressed natural gas (CNG) to vehicles and piped natural gas to homes and businesses, is set to be the biggest driver of demand. It is expected to account for 50 mmscmd of the 110 mmscmd incremental demand by 2030 and 129 mmscmd of the 198 mmscmd increase between 2030 and 2040 in the moderate growth scenario.
“The CGD sector is expected to be the primary growth driver, with consumption projected to grow 2.5 to 3.5 times by 2030 and 6 to 7 times,” the study noted.
India is targeting a rise in the share of natural gas in its energy mix to 15 per cent by 2030, up from the current 6–6.5 per cent, as part of its efforts to shift towards cleaner energy and meet net-zero emission goals by 2070.
So far, the PNGRB has awarded city gas licences covering 307 geographical areas (GAs), extending gas infrastructure to most parts of the country.
Refineries and the petrochemical sector are also expected to see a rise in gas usage, helped by a growing focus on petrochemical integration. This sector is projected to account for an additional 21 mmscmd of gas demand by 2030, and another 10 mmscmd by 2040.
While growth in power generation and fertiliser usage is expected to be moderate, given existing high consumption levels, the transition towards cleaner energy is expected to keep gas relevant in both sectors.
India currently imports around half of its gas needs, a reliance that is set to increase as demand outpaces domestic production. Liquefied natural gas (LNG) imports are projected to more than double by 2030.
The study highlights the potential of LNG in reducing diesel usage in long-haul transport, noting, “LNG as a long-haul transportation fuel could be a game changer, with the potential to play a pivotal role in replacing diesel. LNG trucking is projected to gain momentum post 2030, with the potential to emulate China’s success in reducing diesel dependency,” PTI quoted.
With global LNG supply expected to increase, the report suggests this could present India with an opportunity for long-term supply deals at more competitive prices.
However, the PNGRB warned that several risks remain. “Achieving India’s projected natural gas targets for 2030 and 2040 will require a continued commitment from entities towards infrastructure expansion, favourable LNG pricing, and conducive policies,” the study said. “However, geopolitics, policy uncertainty, and volatility in gas prices cannot be ignored.”
From 2015-16 to 2023-24, India’s natural gas consumption rose by 45 per cent, from 131 mmscmd to 188 mmscmd. While power sector demand contracted slightly due to sensitivity to price changes, CGD usage more than doubled, with a compound annual growth rate (CAGR) of 12 per cent. The fertiliser sector saw 3.4% annual growth, while the refinery sector posted 1.8 per cent.
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Govt plans cheap gas lifeline for LNG trucks; aims to revive closed outlets
Indian Oil, the largest operator of LNG truck outlets, has shut five of its six outlets for lack of business, with only one in Sriperumbudur, an industrial area outside Chennai, still operational The government is considering the allocation of cheap, locally produced natural gas to trucks running on liquefied natural gas (LNG) — India’s new gas demand centre and a cleaner alternative to the country’s polluting diesel-based transport — after state-run refiner Indian Oil was forced to shut nearly all its LNG retail outlets due to high costs and a low customer turnout, industry sources told Business Standard.
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Indian Oil, the largest operator of LNG truck outlets, has shut five of its six outlets for lack of business, with only one in Sriperumbudur, an industrial area outside Chennai, still operational. Another seven-eight outlets are ready but have not started operations due to a shortage of LNG-fuelled trucks, a company official said. The firm hopes to restart the outlets if it can secure adequate refuelling demand, the official added. Indian Oil declined to comment.
Oil-ministry officials are considering the allocation of 500,000 cubic metres of gas per day (mmcm/d) — about 0.5 per cent of India’s stagnant domestic gas production and half of what the industry had sought — from fields under the administered pricing mechanism (APM) to LNG retail outlets, according to documents reviewed by Business Standard and two industry participants.
At $6.75 per million British thermal units (mmBtu), APM gas costs about half as much as imported LNG. LNG needs to be delivered at $8-9 per mmBtu to break even operationally, officials from a state-run refiner said — a third lower than spot LNG prices. The government’s allocation should meet the annual fuel needs of 5,000 trucks, industry sources said. There are hardly 700 trucks plying today in India, compared to nearly 900,000 in China, and industry officials say with the right push from the government India can put 100,000 LNG trucks on the road, eliminating millions of tons in emission and adding gas demand of around 11 mmcm/d.
After Indian Oil’s closures, there are fewer than 20 LNG fuel retail outlets in operation for what was until recently seen as a sunshine industry and a pollution cleanser.
China, by comparison, has around 6,000 outlets. It recently announced a subsidy scheme for purchasing LNG trucks along with plans to increase LNG retailing stations to 8,000 in the next few years, industry data showed.
The new Chinese subsidies would apply from January 1, 2025, to December 31, 2025, with a truck owner getting a maximum subsidy of 110,000 yuan ($15,100) to scrap a heavy-duty truck and buy an LNG truck, United Kingdom-based market intelligence agency Energy Intelligence said. India gives zero subsidy to the LNG truck sector.
Indian Oil was forced to stop operations as losses from running the facility far outweighed the benefits of having a presence in the sector, industry sources said.
Capital costs were high and so were operational losses. LNG retail outlets cost ₹5-8 crore, several times more than a petrol retail station, burdening operators with huge sunk costs. But operational costs are a killer because LNG, a cryogenic fuel stored at -162 degree centigrade, presents a unique problem. The liquefied fuel tends to evaporate in a process called “boiloff”. ‘’We lose 500-600 kg of fuel because of lack of customers,’’ an official at a state-refiner said.
Indian Oil’s Chennai outlet has a fuelling contract with Concor and manages average sales of 2-3 tonnes a day, with extreme volatility.
“You need consistent sales of 5-6 tonnes per outlet on a daily basis to cover boiloff costs for an operational breakeven and twice those volumes to make profits,’’ the official said.
Another state-run refiner pointed to a paucity of trucks and long lead times for new orders at Essar’s Blue Energy, Tata Motors, and Volvo.
The Essar group is planning to create an LNG-trucking ecosystem. GreenLine Mobility Solutions, an Essar venture, has announced a $275 million equity investment to decarbonise heavy trucking in India, including a $20 million investment from broker Zerodha founder Nikhil Kamath, to deploy over 10,000 LNG and electric trucks.
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Gas meters must be verified before use in commerce under new draft rules: Govt
The Department of Consumer Affairs has proposed draft rules mandating the verification, testing and stamping of all gas meters used for domestic, commercial and industrial purposes before they are put to use, in a move aimed at promoting accuracy in gas measurement across India’s trade and commerce sectors.
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New Delhi: The Department of Consumer Affairs has proposed draft rules mandating the verification, testing and stamping of all gas meters used for domestic, commercial and industrial purposes before they are put to use, in a move aimed at promoting accuracy in gas measurement across India’s trade and commerce sectors.
According to the draft framed under the Legal Metrology (General) Rules, 2011, re-verification of gas meters in use will also be mandatory to ensure ongoing accuracy and prevent faulty or manipulated usage. The move is intended to strengthen consumer protection, reduce billing disputes and align with global standards.
“These rules make it mandatory for all gas meters…to undergo testing, verification and stamping prior to their use in trade and commerce,” the department said in a statement. It added that the step aims to ensure “accuracy, transparency, and reliability in the measurement of gas.”
The rules follow extensive consultations with stakeholders, including manufacturers, testing laboratories, city gas distribution companies, and state legal metrology departments. Inputs were incorporated from the Indian Institute of Legal Metrology (IILM), Regional Reference Standard Laboratories (RRSLs), industry experts and Voluntary Consumer Organizations (VCOs). The Bureau of Indian Standards (BIS) was also consulted for technical evaluation.
As per the Ministry, the draft rules are aligned with the standards of the International Organization of Legal Metrology (OIML) and aim to provide a structured compliance framework for both manufacturers and gas distribution firms. The department stated that a transitional period has been included to help stakeholders prepare for implementation.
The Legal Metrology Division is responsible for ensuring the accuracy of weighments and measurements used in trade and commerce.
The department said the initiative marks a step forward in modernizing India’s measurement ecosystem in line with international practices and contributes to efficient and accountable consumer services.
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LNG Use / LNG Development and Shipping
GAIL Secures Five-Year LNG Deal to Boost Energy Supply from April
To meet India’s rising energy demands, state-owned GAIL (India) Ltd will start receiving liquefied natural gas (LNG) shipments next month under a five-year agreement with Qatar Energy Trading. The LNG deal, which includes twelve cargoes per year, will commence in April, according to GAIL’s Managing Director and Chairman, Sandeep Kumar Gupta.
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Qatar Energy Wins LNG Supply Tender
GAIL had awarded the LNG purchase tender to Qatar Energy Trading in December last year. The agreement secures 12 LNG cargoes annually from April 2025 for five years. This strategic move ensures a steady LNG supply to support India’s growing energy needs.
Expanding LNG Portfolio with Long-Term Agreements
In addition to the Qatar Energy deal, GAIL has signed multiple long-term LNG procurement agreements. The company has entered a ten-year contract with commodity trader Vitol Asia, securing approximately one million tons of LNG annually starting in 2026. Vitol will supply LNG from its global portfolio to various locations across India.
Additionally, GAIL has finalized a decade-long agreement with ADNOC Gas in the United Arab Emirates to procure 0.5 million tonnes of LNG per year, beginning in 2026. The agreements support India’s goal of increasing natural gas consumption. Currently, it accounts for 6-7% of the energy mix. The target is to reach 15% by 2030.
Future Plans for LNG Expansion
GAIL is actively exploring additional medium- and long-term LNG contracts to ensure a stable natural gas supply across various industries. The company currently manages an annual LNG portfolio of 14 million tonnes, diversified across multiple indices. As reported by psuconnect.in, GAIL plans to secure an additional 7-8 million tonnes of LNG per year by 2030. So far, 2.25 million tonnes have already been contracted.
https://chemindigest.com/gail-secures-five-year-lng-deal-for-energy-supply-from-april/
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Indian Oil, Petronet LNG & ISPRL sign 3 key MoUs with Odisha at Investors’ Summit
New Delhi: Indian Oil Corporation (IOC), Petronet LNG Ltd (PLL) and Indian Strategic Petroleum Reserves (ISPRL) have signed three pacts with the Odisha government at the Odisha Investors’ Meet in New Delhi on Tuesday. Indian Oil signed a Memorandum of Understanding (MoU) with the government of Odisha to set up a world-class Petrochemical Complex at Paradip. Another MoU was signed by Petronet LNG with the Odisha government for the establishment of a land-based LNG Terminal of 50,000 MT capacity at Gopalpur Port in Ganjam district. Indian Strategic Petroleum Reserves Limited (ISPRL) also signed an MoU for the establishment of 4.0 MMT capacity of crude oil storage facilities in Jajpur district.
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“These projects will prove to be game changers for import substitution, reducing dependency on imports while strengthening India’s energy & petrochemicals infrastructure,” said Minister for Petroleum and Natural Gas Hardeep Singh Puri in a post on X.
Indian Oil’s petrochemical complex to cost Rs 61,077 cr
With an investment of Rs 61,077 crore, Indian Oil’s Paradip petrochemical complex marks the PSU’s largest-ever investment at a single location and a transformative step in India’s petrochemical and industrial growth. The upcoming complex will house a dual-feed cracker and associated downstream units for the production of a wide range of petrochemicals including Phenol, Polypropylene (PP), Isopropyl Alcohol (IPA), High-Density Polyethylene (HDPE), Linear Low-Density Polyethylene (LLDPE), Polyvinyl Chloride (PVC), Phenol, and Butadiene. These products will serve as key raw materials for specialty chemical sectors like pharmaceuticals, agrochemicals, coatings, and adhesives, significantly reducing import dependency and supporting the Aatmanirbhar Bharat and Make in India missions.
Speaking on the occasion, Puri said, “This state-of-the-art Petrochemicals hub will catalyse the development of Paradip Petroleum, Chemicals & Petrochemicals Investment Region (PCPIR) and create direct & indirect employment opportunities in the region.”
This project builds on Indian Oil’s existing 15 MMTPA Refinery-cum-Petrochemical Complex at Paradip and will boost downstream industries and MSMEs across eastern India.
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Odisha CM Majhi leaves for New Delhi; MoUs with IOCL, Petronet LNG to be signed
Odisha CM Mohan Charan Majhi embarked on a visit to New Delhi today, where the State Govt is set to sign key MoUs with leading industry players, including IOCL, Petronet LNG, and Indian Strategic Petroleum Reserves Ltd Bhubaneswar: Odisha Chief Minister Mohan Charan Majhi embarked on a visit to New Delhi today, where the State Government is set to sign key Memorandums of Understanding with leading industry players, including Indian Oil Corporation Ltd (IOCL), Petronet LNG, and Indian Strategic Petroleum Reserves Ltd, among others.
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Per official sources, these strategic collaborations underscore Odisha’s commitment to becoming a major hub for the petrochemical and chemical industries. The MoUs aim to strengthen the existing industrial ecosystem, attract significant investments, generate employment opportunities, and boost the State’s overall economic development.
During a two-day event in New Delhi, the Chief Minister will engage in high-level discussions with various stakeholders and industry leaders. He is expected to outline the State’s vision for industrial growth, highlighting key reforms and initiatives implemented by the Odisha Government to create an investor-friendly environment.
In addition to attending industry meetings, CM Majhi is scheduled to visit the HCL Tech campus in Noida. He will also hold one-on-one meetings with prominent business leaders from diverse sectors to explore potential partnerships that can further enhance Odisha’s industrial landscape.
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GAIL India issues EOI to source LNG with equity portion in USA NG Liquefaction Project
The state-run firm would acquire 26% equity in the plant which is having up to 5 MMTPA Capacity. With more than 5MMTPA to Less than 10 MMTPA capacity it would acquire around 15% equity, while for more than 10 MMTPA capacity it will own around 10%.
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State-owned GAIL (India) Ltd has issued an Invition of Expression of Interest to source 1 Million Metric Tons Per Annum (MMTPA) of LNG from an existing or upcoming Natural Gas (NG) liquefaction project in the United States of America (USA) on Free on Board (FOB) basis for a period of 15 years on mutually acceptable terms and conditions.
The state-run firm would acquire 26% equity in the plant which is having up to 5 MMTPA Capacity. With more than 5MMTPA to Less than 10 MMTPA capacity it would acquire around 15% equity, while for more than 10 MMTPA capacity it will own around 10%.
According to the issued tender, the contract period for LNG supply may be extended further by 5 / 10 years on a mutual basis. LNG supply / offtake shall commence tentatively in Calendar Year (CY) 2029 to 2030 from existing Project and in CY 2030 from upcoming Project.
The company will source LNG from the inviting bidding unit which has the right to sell LNG from the Project.
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Electric Mobility/ Hydrogen/Bio-Methane
India’s First Green Hydrogen Use in Float Glass Industry Takes Off in Rajasthan
India has marked a significant milestone in its clean energy transition with the commissioning of the country’s first green hydrogen plant for the float glass industry. INOX Air Products (INOXAP), a leading industrial gas manufacturer, has launched the plant at Asahi India Glass Ltd’s (AIS) greenfield float glass facility in Soniyana, Chittorgarh, Rajasthan.
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This initiative introduces green hydrogen into float glass manufacturing for the first time in India, positioning the sector for a cleaner, low-carbon future. Powered entirely by solar energy, the plant is capable of producing up to 190 tonnes per year of green hydrogen through electrolysis. In the first phase, INOXAP will supply 95 tonnes per year to AIS under a 20-year offtake agreement.
INOXAP has designed, engineered, and installed the plant, and will manage its operations and hydrogen supply for the entire contract period. AIS, meanwhile, has invested in the dedicated solar power infrastructure and will use the hydrogen in its glass production processes—setting new benchmarks in sustainable industrial operations.
Siddharth Jain, Managing Director, INOX Air Products, noted, “This is a proud moment as our first green hydrogen plant will contribute directly to reducing carbon emissions in India’s glass industry. It’s a step forward in our national journey toward net zero.”
Rupinder Shelly, COO of AIS Architectural Glass, added, “We aim to meet 94% of our power needs from green sources at Soniyana. Green hydrogen strengthens our sustainability goals and our focus on circularity and decarbonisation.”
The move is expected to set a precedent for other energy-intensive industries exploring green hydrogen adoption.
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Construction major L&T incorporates arm to develop green hydrogen projects
Green hydrogen is a clean, renewable form of hydrogen gas produced by using electricity from sources like solar, wind, or hydropower Construction giant Larsen & Toubro (L&T) on Friday announced the incorporation of a new subsidiary, L&T Green Energy Kandla Private Limited (LTGEK), to spearhead the development of green hydrogen projects.
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“We wish to inform you that L&T Energy Green Tech Limited, a wholly owned subsidiary of the Company, has incorporated a new wholly owned subsidiary—L&T Green Energy Kandla Private Limited (LTGEK)—on April 4, 2025,” L&T said in a filing to the National Stock Exchange (NSE).
The newly-formed entity will focus on the development of green hydrogen and its derivatives, including green ammonia, as well as other related business activities, the company added.
Green hydrogen is a clean and sustainable form of hydrogen produced through electrolysis powered by renewable energy sources such as solar, wind, or hydropower. It gets its ‘green’ nomenclature from the fact that its production does not emit carbon dioxide (CO₂) or other harmful greenhouse gases, making it an environmentally-friendly alternative.
L&T also noted that L&T Energy Green Tech Limited, along with its nominee shareholder, has fully subscribed to the equity shares of LTGEK, amounting to Rs 1,00,000.
This move aligns with L&T’s broader green energy ambitions. In February 2024, Derek Shah, senior vice president at L&T and head of Green Manufacturing and Development, announced plans to commercially roll out 150–200 megawatts (MW) of electrolyser capacity by September 2025.
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Kandla Port To Begin Green Hydrogen Production By August: DPA Chairman
This initiative will make Kandla a significant contributor to the goal of achieving net-zero greenhouse gas (GHG) emissions set by the International Maritime Organization. Kandla (Gujarat): Sushil Kumar Singh, Chairman of Deendayal Port Authority (DPA), Kandla, said on Saturday that the authority will begin the production of green hydrogen by the end of August this year.
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“Under the National Green Hydrogen Mission, an ecosystem is being developed in Kandla for green hydrogen, green ammonia, and methanol. We have allocated space to major industry partners to set up giga-scale plants here. Kandla Port will also set up a 1-megawatt demonstration plant for green hydrogen,” Singh said.
He added, “With the support of L&T, we have started setting up a plant here. We aim to begin green hydrogen production by the end of August. We have signed an MoU with NTPC, under which eleven hydrogen-powered buses will replace diesel buses. This initiative will make Kandla a significant contributor to the goal of achieving net-zero greenhouse gas (GHG) emissions set by the International Maritime Organization.”
Singh further stated, “We are working to position ourselves as a methanol bunker point for the Rotterdam-Singapore corridor. This would make Kandla Port the first in India to feature in the world’s green shipping corridors.” He also highlighted the port’s operational achievements, saying that DPA has surpassed its cargo-handling target for the financial year 2024-25.
“We have achieved our target of 150 million tonnes for this year. We closed FY 2024-25 at 150.16 million tonnes, registering a 13 percent year-on-year growth — a significant leap compared to other major ports in the country,” Singh said. Highlighting the port’s efficiency, Singh noted that these results were achieved using existing infrastructure without any additional capacity expansion.
“This performance has been delivered using our existing infrastructure, without any new capacity building. We made swift decisions to unlock the potential of our assets by actively engaging with users. Now, our focus is on utilizing the remaining capacity of the existing infrastructure. One major step in this direction will be offering a ‘berthing on arrival’ facility to vessels,” he added.
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BPCL shares in focus after JV with Sembcorp to boost green hydrogen and renewables energy in India
Bharat Petroleum Corporation (BPCL) and Sembcorp Green Hydrogen India have formed a 50:50 joint venture to develop renewable energy and green hydrogen projects across India. This collaboration aims to produce and sell renewable energy, green hydrogen, and its derivatives, potentially including green ammonia.
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BPCL shares will be in focus on Wednesday after Bharat Petroleum Corporation and Sembcorp Green Hydrogen India, a subsidiary of Sembcorp Industries, announced the formation of a 50:50 joint venture to develop renewable energy and green hydrogen projects across India.
The companies had initially disclosed their plans to collaborate in September last year. The JV will focus on the production, operation, and sale of renewable energy, green hydrogen, and its derivatives.
“The JV will also consider projects in green ammonia production and bunkering, emissions reduction for port operations and other emerging green fuel technologies,” it said.
“The potential projects will leverage Sembcorp’s renewables experience and BPCL’s expertise in the petroleum sector and infrastructure.”
Vipul Tuli, President & CEO, Renewables, West, and CEO, Hydrogen Business, Sembcorp, said, “Sembcorp’s collaboration with BPCL seeks to support renewable energy and green hydrogen development in India. With Sembcorp’s renewables expertise and BPCL’s strength in the petroleum sector, we look forward to identifying opportunities to help decarbonise hard-to-abate sectors. Sembcorp is committed to delivering scalable, low-carbon solutions for a sustainable future.”
Sembcorp is pursuing the use of green hydrogen and ammonia as key decarbonisation pathways. With 6 GW of renewable assets in India, Sembcorp is well-positioned to enable large-scale, low-cost green hydrogen production.
G Krishnakumar, Chairman & Managing Director, BPCL, said, “BPCL will leverage its combined aspirations, expertise and resources, to jointly explore the development of innovation-led, best-inclass renewable energy and green hydrogen solutions for supporting India’s ambitious climate goals and our own aspiration to achieve net-zero emissions by 2040 in Scope 1 and 2.”
BPCL shares price target
As per Trendlyne data, the average target price of the stock is Rs 1,621, which shows an upside of 41% from the current market prices. The consensus recommendation from 22 analysts for the stock is a ‘Hold’.
BPCL shares price performance
On Tuesday, BPCL shares closed at Rs 285.7 on the BSE, up 4.12%, while the benchmark Sensex surged 1.49%. The stock is down 16% in the last six months but gained 72% over the past two years. Its market capitalisation currently stands at Rs 1,23,950 crore.
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Samridh Bio Energy, GAIL, and Torrent Gas Sign Deal to Boost CBG Supply and Distribution
Under the agreement, Samridh Bio Energy will produce 12 TPD Compressed Biogas (CBG), which will be facilitated by GAIL to ensure a seamless supply chain. Torrent Gas will transport and integrate the supplied CBG into its City Gas Distribution (CGD) network, enabling efficient distribution to end consumers.
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A Tripartite Agreement signing ceremony took place at GAIL’s Lucknow office between Samridh Bio Energy, GAIL, and Torrent Gas under the CBG-CGD Synchronisation Scheme.
Under the agreement, Samridh Bio Energy will produce 12 TPD Compressed Biogas (CBG), which will be facilitated by GAIL to ensure a seamless supply chain. Torrent Gas will transport and integrate the supplied CBG into its City Gas Distribution (CGD) network, enabling efficient distribution to end consumers.
The Samridh Bio Energy and Organics plant is currently under development, with CEID Consultants and Engineering serving as the EPC (Engineering, Procurement, and Construction) partner. As the EPC provider, CEID will design, procure, and construct the plant so that it meets industry standards and operates effectively once it’s ready. The plant will have the capacity to produce 30,000 cubic meters per day of biogas, which, after purification, yields 12 TPD CBG.
CEID Consultants is committed to ensuring smooth project implementation, incorporation of cutting-edge technology, and adherence to environmental and safety standards. Their experience with biogas infrastructure will enable the optimal functioning of the plant and support India’s effort toward eco-friendly energy solutions.
Speaking at the signing ceremony, Anup Maheshwari, CEID Consultants and Engineering Pvt Ltd., said, We at CEID Consultants are proud to be the EPC partner for the Samridh Bio Energy and Organics plant, a project that aligns with India’s vision for sustainable energy. This agreement marks a milestone towards the inclusion of Compressed Biogas into the City Gas Distribution network, and we look forward to the successful operation of the plant with the best industry standards.”
According to Ashwani Chib, Director of Samridh Bio Energy and Organics, “The Tripartite Agreement is a significant step towards India’s clean energy transition. By integrating Compressed Biogas into the City Gas Distribution network, we are ensuring a sustainable and efficient energy supply. GAIL is committed to facilitating seamless transportation of CBG from the Samridh Bio Energy plant in Village Hasanpur Patti, Tehsil Bilari, Distt Moradabad, U.P. This initiative strengthens the CBG ecosystem and supports India’s vision for greener energy solutions.
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INTERNATIONAL NEWS
Natural Gas / Transnational Pipelines/ Others
US: FERC Approves 122-Mile Ridgeline Gas Pipeline Expansion in Tennessee
(P&GJ) — The Federal Energy Regulatory Commission (FERC) has approved The Enbridge Inc.-sponsored Ridgeline Expansion Project, a 122-mile natural gas pipeline system designed to serve the Tennessee Valley Authority’s (TVA) new combined-cycle power plant in Morgan County, Tennessee. FERC issued the certificate on April 2, 2025, following an application by East Tennessee Natural Gas LLC, a subsidiary of Enbridge Inc., under sections of the Natural Gas Act. The $1.1 billion project will provide up to 300,000 dekatherms per day (Dth/d) of firm transportation service and 95,000 Dth of Customized Delivery Service to TVA.
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The pipeline expansion includes:
110 miles of 30-inch mainline and 4 miles of 30-inch header pipeline
An 8-mile lateral pipeline
Three new crossover pipelines
A new compressor station in Trousdale County with 14,600 horsepower capacity
Modifications to interconnects with other major pipelines (Texas Eastern, Columbia Gulf, and Midwestern Gas Transmission)
The infrastructure is critical to TVA’s plan to retire nine coal-fired units at its Kingston Plant by 2027 and replace them with a 1,500 MW natural-gas-fired plant, plus solar and battery storage systems.
East Tennessee signed a precedent agreement with TVA for 100% of the project’s capacity. The utility also proposed a new Customized Delivery Service feature to provide no-notice, flexible gas delivery up to 95,000 Dth/day, enabling rapid generation ramp-ups.
Pending regulatory approvals, the Ridgeline Expansion Project is on track to begin construction soon to meet TVA’s timeline.
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Bulgaria : Bulgaria, Turkey to Explore Adding Gas Flow Capacity at Border
Bulgaria and Turkey will explore options to increase natural gas transit capacity at their joint border, a move that may allow greater flows from Russia and the Caspian region to reach central Europe. (Bloomberg) — Bulgaria and Turkey will explore options to increase natural gas transit capacity at their joint border, a move that may allow greater flows from Russia and the Caspian region to reach central Europe. The two countries will hold expert-level talks to renegotiate current agreements by May 2, before seeking a political decision to expand the border transit options, Bulgaria’s energy ministry said in a statement on Saturday, after a meeting of the two countries’ energy ministers in Baku, Azerbaijan.
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Bulgaria hosts the only active pipeline route for Russian gas flowing to Europe, after Ukraine ended a long-term contract with Russia’s Gazprom PJSC to transit up to 40 billion cubic meters annually at the end of last year. Bulgaria’s route, which currently transfers about 16 billion cubic meters a year and is used at near-full capacity, is an extension of TurkStream, a Black Sea pipeline designed to bypass Ukraine that was completed before Russia’s invasion in 2022.
Some European countries that have maintained ties with the Kremlin, including Hungary, Slovakia and Serbia, depend on Gazprom for most of their supplies, although some have weighed alternative sources such as Azerbaijan since Russia’s war disrupted deliveries. Slovakia has said it would multiply deliveries of Russian gas from TurkStream from April.
Turkey “is our strategic partner in fulfilling our priorities related to diversification and energy security,” Bulgarian Energy Minister Zhecho Stankov said, according to the statement.
Bulgaria also has access to gas from Azerbaijan, via Turkey, as well as Turkish terminals for liquefied natural gas, under a deal with state-owned Botas.
Turkey has repeatedly suggested it is ready to increase supplies to Europe, including by creating its own gas blend as some of its long-term contracts with Gazprom expire this year.
High prices have made it close to impossible for Bulgargaz, Bulgaria’s state-owned distributor, to make use of the Botas deal, under which it has to pay regardless of the quantities used. A possible renegotiation of that agreement will also be a subject of the talks.
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Malaysia: Amirudin assures no cover-up in gas pipeline inferno probe
The Selangor government has assured that the investigation into the Putra Heights gas pipeline fire in Subang Jaya will be carried out transparently and no parties will be protected.
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Menteri Besar Amirudin Shari said that audit teams from both the federal and state governments have been deployed to the Selangor Utility Corridor (KuSel) and the Subang Jaya City Council (MBSJ) following allegations of negligence on the part of both entities that may have led to the incident.
https://www.malaysiakini.com/news/739251
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Japan: Japan’s Tokyo Gas expands in US shale gas with Chevron deal
TG Natural Resources LLC (TGNR), co-owned by Tokyo Gas (9531.T), opens new tab and Castleton Commodities International, has bought a 70% stake in east Texas gas assets from Chevron for $525 million, the company said on Tuesday, as it expands its U.S. gas business.
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TGNR is already the fourth biggest producer in the Haynesville shale basin and the deal would allow it to reap synergies of over $170 million during the asset’s development, Craig Jarchow, the company’s chief executive, said in a statement.
Haynesville’s location in east Texas and northwest Louisiana is ideal for exports from liquefied natural gas (LNG) facilities and projects clustered on the nearby Gulf Coast, and has investors’ attention as U.S. President Donald Trump aims to boost gas exports.
Yoshihisa Yamada, senior general manager at Tokyo Gas, told reporters on Tuesday that the new investment had been under consideration since before Trump’s return to the office, but that the deal is in line with both countries’ common aim to strengthen energy security by boosting LNG supplies from the U.S. to Japan.
The asset is expected to produce 1.4 billion cubic feet of gas per day in 2030, he said, adding that Tokyo Gas is considering investing in LNG liquefaction in the United States but no specific decisions have been made.
Tokyo Gas, Japan’s largest city gas provider, said last week it wanted to increase coordination between its LNG trading and shale gas businesses in the U.S. and expand there, as it sees shale gas as a major profit pillar in the coming years.
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Malaysia: Malaysia’s gas pipelines should be no-go zones after explosion, experts say
Experts emphasised the necessity for strict protection zones following a blast in Malaysia, prohibiting unauthorised work The area around gas pipelines must be strictly safeguarded at all times, following the recent gas pipeline fire in Selangor, Malaysia, experts said, emphasising that no unauthorised work should be permitted. Even simple tasks like trimming grass within the designated area require permission and supervision from the owner.
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A former Petronas safety officer said that residents should be safe if protection zones are respected.
“As long as the gas pipeline area is not disturbed and the gazetted area is respected, there is no reason for residents living near underground gas pipelines to worry,” Zakariah Yusoff said.
Zakariah, who maintained gas pipelines for 24 years, said Petronas prioritised public safety when laying out the pipelines.
The blast affected 1,254 people from 308 families in the area, with 87 houses suffering a “total loss” and an additional 148 houses requiring repairs.
Zakariah said the owner of the gas pipelines should have the final say on any work done in the gazetted area.
“If the owner of the pipelines – which in Malaysia is mostly Petronas – says no works or development should be done in that area, no one should go against that decision. They know best about the dangers.
“If there is any digging to be done within the vicinity of the gas pipelines, the local authorities need to bring Petronas in to ensure that it is safe to do so.
“Based on my experience, the central control room of that area would also monitor the pressure inside the pipeline. The moment there is low pressure, we would know there is a problem and detect the point of drop in pressure.
“This way, a leak can be detected. The standard operating procedures include evacuating residents and people nearby immediately,” he said, adding that the system put in place to monitor the pipelines and the gazetted area used the highest technology.
He said any possible encroachment near gas pipelines was always done with coordination between the local authorities and Petronas.
Terengganu local government, housing and health committee deputy chairman Saiful Azmi Suhaili said that since most methane gas channelled throughout the peninsula came from the state, there was a lot of pressure on the state government to ensure gas pipelines were safe.
“The gases from offshore are first piped to Kerteh in Trengganu and then processed into clear methane, before this safe-to-use gas is transported to Segamat in Johor via gas pipelines using 36 foot diameter pipes.
“The gas is then moved to destinations throughout the peninsula to industrial areas. These gas pipelines are highly secure to ensure there is no leakage. Generally, they run underground through areas which are away from any possible disturbances. If there are residential areas nearby, the monitoring and maintaining system is optimal,” he said.
“No development is allowed in these areas unless there is clearance from Petronas.
“For example, when we wanted to build the East Coast Rail Link which runs through areas where gas pipelines are buried, the stakeholders were ordered to work with Petronas.
“A bridge crossing over the gas pipeline area in Kemasik, Terengganu could only be built after much study. It took much time as Petronas had to assess any dangers in such a development,” Saiful Azmi, an electrical engineer, said.
He said all local authorities must be extra careful about any development or work near gas pipelines to prevent any catastrophes like what happened on Tuesday.
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Oman: Oman Gas Pipeline Network Aims to Drive Down Hydrogen Costs & Support Green Energy Push
OQ Gas Networks (OQGN), Oman’s national gas pipeline infrastructure provider, said it is leveraging its expertise to reduce the levelized cost of hydrogen (LCOH) production and support the country’s burgeoning green hydrogen economy. The majority state-owned company, part of OQ Group, announced its collaboration with government and public sector stakeholders to develop hydrogen pipeline infrastructure.
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These announcements were made during a recent discussion session focused on OQGN’s 2024 financial and operational performance.
“OQGN has been one of the leading companies working with the government and other main stakeholders to grow and enable the energy transition, and specifically to enable the green hydrogen economy in Oman,” an official said.
Oman has set ambitious targets to become a major exporter of green energy, including hydrogen and its derivatives. And OQGN aims to be the primary infrastructure provider for hydrogen transportation.
As the designated National Infrastructure Provider for hydrogen pipelines, OQGN is working closely with Hydrom, the entity overseeing Oman’s green hydrogen industry, on pipeline network master planning.
“OQGN is actively involved in Hydrom’s feasibility study, aligning on technical, commercial, financial, and legal considerations,” the company said in a presentation.
The company signed a memorandum of understanding with Hydrom and is supporting the national goal to produce and export 1 million metric tons of green hydrogen annually by 2030, with a target of 8 million metric tons by 2050.
OQGN is also collaborating with Hydrom on a pre-front-end engineering and design (FEED) study for a Common Use Infrastructure (CUI) system. This system will support green hydrogen projects across allocated and future government-awarded land blocks.
Additionally, the company will develop and operate pipeline networks to transport green hydrogen from these land blocks to a dedicated zone near the Port of Duqm for processing into derivatives, such as green ammonia and green methanol, for export. Some of the hydrogen will fuel hard-to-abate industries like steel and aluminum.
OQGN currently owns and operates Oman’s 4,235-kilometer natural gas transportation network, supplying fuel and feedstock to 130 major customers.
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South Africa: Chinedu Okeke: A trailblazer in sustainable energy financing and the adoption of CNG in Nigeria
In an era where climate change is an undeniable global challenge, Dr. Chinedu Okeke has emerged as a key figure in driving Nigeria’s transition to a more sustainable and environmentally friendly energy future. Through his groundbreaking work in sustainable energy financing and his pioneering efforts in promoting the adoption of Compressed Natural Gas (CNG) in Nigeria, Dr. Okeke has contributed significantly to reducing the nation’s carbon footprint, while simultaneously reshaping the future of energy consumption for the transportation sector.
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Dr. Okeke, a visionary in sustainable energy solutions, has dedicated his career to bridging the gap between technological innovation, financial accessibility, and environmental responsibility. His work on CNG adoption has especially had a profound impact on Nigeria’s transportation sector, where the dependency on conventional fuel sources has long been a major contributor to air pollution and greenhouse gas emissions.
Championing sustainable energy financing
Dr. Okeke’s work centers on creating innovative, sustainable financing models that facilitate the transition to cleaner energy alternatives. One of his most notable achievements has been the development of a retail financing model designed specifically to enable Nigerian drivers to make the switch from conventional fuel to CNG. This initiative has provided a lifeline to thousands of drivers who previously found it financially challenging to adopt cleaner energy solutions.
The model works by offering affordable financing options to individuals and small businesses, ensuring that the upfront costs associated with converting vehicles to CNG are within reach. Through partnerships with financial institutions, government agencies, and private sector stakeholders, Dr. Okeke has successfully created a robust framework that makes CNG adoption both economically viable and environmentally impactful.
“Access to clean energy shouldn’t be a luxury,” says Dr. Okeke. “With the right financing structures, we can make the switch to CNG both affordable and sustainable for all drivers, contributing to Nigeria’s energy transition and a cleaner, healthier environment.”
The role of CNG in reducing carbon footprint
CNG is considered one of the most viable alternatives to petrol and diesel for vehicles, due to its lower carbon emissions, greater efficiency, and the abundance of natural gas reserves in Nigeria. By championing the widespread adoption of CNG, Dr. Okeke has not only helped reduce the environmental impact of Nigeria’s transportation sector but has also created a model for other nations in the region to follow.
In a country where traffic congestion and air pollution are persistent challenges, Dr. Okeke’s advocacy for CNG adoption has sparked a movement toward cleaner, greener energy practices. Studies have shown that CNG-powered vehicles emit significantly fewer pollutants than traditional fuel-powered vehicles, including carbon monoxide and nitrogen oxides. As a result, the shift to CNG is seen as one of the most effective ways to reduce the carbon footprint of Nigeria’s transportation sector, contributing to the country’s climate goals and improving air quality for millions of Nigerians.
Engaging stakeholders for impactful change
One of Dr. Okeke’s most impressive qualities is his ability to engage with a wide range of stakeholders—government agencies, private sector players, environmental organizations, and the public—to create a unified approach to sustainable energy adoption. His research and advocacy have played a critical role in shaping policy discussions around energy transition, particularly with regard to the integration of CNG into Nigeria’s energy mix.
Through seminars, policy roundtables, and collaborations with key stakeholders, Dr. Okeke has helped to create an ecosystem where CNG adoption is not only seen as a practical solution but as an imperative for the nation’s environmental future. His work has also led to the establishment of several pilot projects that demonstrate the feasibility and long-term benefits of adopting CNG, further building confidence among both consumers and industry players.
A legacy of change
Dr. Okeke’s contributions to sustainable energy financing and the promotion of CNG adoption go beyond just technological innovation. His commitment to creating lasting, positive change has resonated with both local communities and international organizations. He has shown that sustainability and economic growth can go hand in hand, and that cleaner energy solutions do not have to be out of reach for the average Nigerian.
As Nigeria continues to grapple with the challenges of climate change, energy access, and environmental degradation, Dr. Okeke’s efforts serve as a beacon of hope for a cleaner, more sustainable future. His work is a testament to the power of innovation, collaboration, and dedication in creating solutions that not only benefit the environment but also the people who live in it.
In recognition of his outstanding contributions, Dr. Chinedu Okeke has rightfully earned his place as one of the leading advocates for sustainable energy in Nigeria. His legacy of environmental stewardship, economic empowerment, and transformative change will undoubtedly continue to inspire future generations to take bold steps toward a more sustainable world.
Ademola write from Dutse, Abuja
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Nigeria: Ekpo Touts Natural Gas Role in Energy Transition at Akwa Ibom CNG Project Site
As the global energy landscape shifts towards cleaner sources, Nigeria is positioning its substantial natural gas reserves as a key driver of a just and equitable energy transition. This was highlighted by the Minister of State Petroleum Resources (Gas), Ekperikpe Ekpo, during the groundbreaking ceremony for Guelph Gas Limited’s Compressed Natural Gas (CNG) Mother Station in Ibesikpo, Akwa Ibom State. The project aligns with the federal government’s initiative to expand CNG availability across the country.
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Last July, Mele Kyari, former Group Chief Executive Officer of Nigerian National Petroleum Company (NNPC) Limited, affirmed the commitment to bringing CNG closer to Nigerians.
During the commissioning of 12 CNG stations in Abuja and Lagos, Kyari stated, “There is simply no way to turn back on delivering CNG for all Nigerians. It is the right thing to do… we will cover the gap in order to ensure that the volatility we see with petrol does not apply to gas.” He also acknowledged President Bola Tinubu’s support for domestic gas utilization.
Kyari emphasized NNPC’s dedication to delivering strategic gas projects, stating, “NNPC will continue to deliver more strategic gas projects for the benefit of Nigerians in line with the Presidential CNG Initiative of bringing prosperity to all Nigerians,” and reaffirmed the determination of NNPC to guarantee the nation’s energy security.
NNPC Retail Limited Managing Director, Huub Stokman, revealed plans to launch over 100 CNG sites within a year, including 16 NNPC Gas Marketing and NIPCO Gas JV sites.
“CNG provides Nigeria with affordable alternatives to existing available fuel products. It will be about 40% cheaper than petrol in Nigeria and with continued investments, it will become a significant part of our energy mix,” Stokman stated.
Minister Ekpo emphasized the broader impact of these CNG stations, noting they will “not only provide economic benefits by creating jobs and stimulating local economies, it will also contribute significantly to Nigeria’s national goals of reducing emissions and combating climate change.”
Pius Akinyelure, then Chairman of the NNPC Board of Directors, pointed out that increased CNG adoption will lower fuel costs for both consumers and businesses.
The development of Auto-CNG Stations across Nigeria, led by NNPC Gas Marketing Limited in partnership with NIPCO Gas Limited, follows the removal of fuel subsidies and the launch of the Presidential Compressed Natural Gas (CNG) initiative. This initiative aims to mitigate the effects of the subsidy removal.
The removal of fuel subsidies led to a substantial increase in the price of petrol, necessitating the exploration of alternative fuel sources such as CNG and electric vehicles (EVs).
While Nigeria is also pursuing electric vehicle adoption, with targets of 30% local EV production by 2032 and 13 million EVs by 2050, Minister Ekpo highlighted the immediate benefits of CNG.
Ekpo described CNG as “a cleaner alternative to traditional fuels that will play a crucial role in reducing carbon emissions and promoting a healthier environment.”
The minister commended Guelph Gas Limited’s investment in the CNG project, attributing it to the government’s commitment to fostering private sector participation.
He assured that the Ministry of Petroleum Resources (Gas) will provide the necessary support for the project’s success, which is expected to “significantly boost the country’s income earnings, stimulate economic growth, and generate vast employment opportunities for Nigerian youths.”
Ekpo also praised Akwa Ibom State Governor Umo Eno, for supporting investments that drive economic growth and create employment. “As someone who hails from this great state, I have seen firsthand the dedication of our people to development and innovation,”
Ekpo said. “With its strategic location, resource wealth, and commitment to development, the state is positioned to be a key hub in Nigeria’s gas revolution.”
Emmanuel Bassey, Managing Director of Guelph Gas Limited, expressed gratitude to President Tinubu for policies like the “Gas to Prosperity” and “Decade of Gas” initiatives, which encourage private sector investment in the gas sector. Bassey also thanked Minister Ekpo for his support.
The Ibesikpo CNG mother station project, with a capacity of three million standard cubic feet per day, aims to supply CNG to commercial and industrial customers in the South-South and South-Eastern regions, areas currently outside the national gas pipeline network.
Bassey reported that the company has completed its pre-development phase, securing necessary licenses and approvals, and expects to finalize a Gas Sales Agreement (GSA) soon. Offtake agreements are already in place.
Bassey pledged to deliver the project on schedule and to specification, and assured the host community of corporate social responsibility initiatives, while seeking their support and cooperation.
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Malaysia : ‘Country’s gas pipeline network key to industrial growth’
Citing the Peninsular Gas Utilisation (PGU) project, a nationwide pipeline system developed by PETRONAS in the 1980s and 1990s, he said it was constructed to ensure the country’s growing energy needs were met in an efficient and sustainable manner. “The PGU project was launched as part of a national strategy to industrialise and use gas more efficiently,” said Kang, who has over 30 years of experience in pipeline corrosion control.
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“It ensured the energy demands of the country were met, especially by feeding natural gas into all major power stations at the time.”
In addition to powering power stations, the gas pipeline system evolved to meet the heating needs of Malaysia’s manufacturing sector, he said.
“From around 1993, lower-pressure gas was channelled to factories, especially those requiring consistent heating, such as ceramic manufacturers and bakeries,” Kang said. Beyond the industrial sector, gas pipelines also support district cooling systems, a technology used to provide central air conditioning to major buildings.
“Buildings such as KLCC, KLIA, Putrajaya and Cyberjaya rely on these pipelines to power their cooling systems,” he added.
He said transporting natural gas through pipelines remains far more efficient and cost-effective compared to using tankers.
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Natural Gas / LNG Utilization / Bio-LNG
Canada: Kitimat and Terrace hospitals receive diagnostic equipment with support from LNG Canada
LNG Canada has funded new diagnostic equipment for hospitals in Kitimat and Terrace through donations to two local health foundations.“The partnerships with both the Kitimat General Hospital Foundation and the Dr. REM Lee Hospital Foundation are examples of how we work with local organizations to foster healthier, more resilient communities in the region in which we operate,” LNG Canada stated.
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The company pledged $25,000 to the Kitimat General Hospital Foundation and $100,000 to the Dr. REM Lee Hospital Foundation. The donations were first announced nearly 18 months ago, but both hospitals proceeded with purchasing the equipment based on those commitments, and the technology has since been in regular use.
The contributions from LNG Canada complemented broader fundraising efforts by the foundations, which also received support from many local organizations and individuals.
The new ECG machine in Kitimat is supporting timely diagnosis by expanding access to heart monitoring services. “It’s the same equipment used in the ER, making it easier for staff to work with a single piece of equipment across departments. Additionally, the leads used are compatible with patients coming from outside agencies who are being transferred to a higher level of care, ensuring seamless continuity of care across the community,” the Kitimat foundation said.
In Terrace, the Pegasus Dual Retort Processor is allowing the lab to handle more tissue samples on-site.
“The Pegasus Dual Retort Processor has allowed our department to process urgent samples same-day,” said Dana Randrup, Pathology Section Head at Ksyen Regional Hospital. “This has resulted in a shorter turn around time for our North West Regional histology samples. This tissue processor also has a built-in reagent management system that has resulted in higher quality tissue processing which, in turn, ensures a quality diagnosis.”
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Australia: ‘Substantial’ floater sought for Australian LNG project
Viva Energy tasks Poten & Partners to secure FSRU for Geelong scheme. Viva Energy is in the market for a floating storage and regasification unit (FSRU) for its long-touted liquefied natural gas import project in Victoria, Australia.
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ASX-listed Viva on Monday confirmed it has engaged experienced LNG consultant Poten & Partners to secure a FSRU for its proposed LNG import terminal in Geelong, south of the state capital city Melbourne.
Poten & Partners is casting a wide net, seeking expressions of interest from the global maritime industry to supply an existing FSRU or retrofit an LNG carrier into an FSRU for the terminal.
https://www.upstreamonline.com/lng/substantial-floater-sought-for-australian-lng-project/2-1-1800386
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Canada: Public input requested for proposed tweaks to Canada’s $4B LNG project
Shortly after a liquified natural gas (LNG) project got picked to get millions in support from the Canadian government, the Impact Assessment Agency of Canada (IAAC) has set the wheels in motion to kick off a public comment period on proposed amendments to the decision statement for the project’s floating LNG (FLNG) processing facility and marine export terminal near Kitimat in British Columbia, Canada.
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The government of Canada revealed on March 21, 2025, its support for Cedar LNG in the form of a contribution agreement under the Strategic Innovation Fund (SIF) of up to CAD 200 million ($139.8 million) toward a CAD 5.963 billion ($4.17 billion) project with Cedar LNG Partners LP (Cedar LNG). Innovation, Science and Economic Development Canada describes this as an initiative set to be the country’s largest Indigenous majority-owned infrastructure project.
When the Cedar LNG project was approved in 2023, the Minister of Environment and Climate Change issued a decision statement with legally binding conditions that Cedar LNG Partners have to comply with throughout the life of the project, including advising IAAC of proposed changes to the project that would have potential adverse effects within federal jurisdiction.
The project’s partners are proposing to expand the marine terminal area to encompass the mooring lines and anchors for the facility’s mooring system and add a new distribution powerline alongside the option of an alternate transmission line route, which would have a wider right of way.
While these things would not result in changes to the production or storage capacity of the LNG facility, IAAC has invited Indigenous Peoples and the public to review and provide feedback on the draft analysis of these proposed changes, which includes amendments to the decision statement.
As the project approval cannot be amended, this comment period is strictly for the proposed amendments to the decision statement. Comments need to be submitted by 11:59 p.m. on April 30, 2025. The Cedar LNG project entails the construction, commissioning, and operation of a new FLNG processing facility and marine export terminal in Kitimat, powered by clean hydroelectricity from British Columbia’s grid to produce ultra-low-carbon LNG.
Such LNG is believed to have the potential to displace the use of high-emitting forms of energy in Asia. This project is set to have the capacity to process and liquefy 400 million standard cubic feet of natural gas per day and produce 3.3 million tons of liquefied natural gas per year for international markets.
Cedar LNG has experienced its fair share of issues already by running into opposition from climate change activists and facing legal challenges thanks to Steelhead LNG, which accused Cedar LNG and Samsung Heavy Industries of infringing its Korean patents.
The company embarked on a patent infringement litigation in Korea to seek a halt to the construction of FLNG facilities, damages for the alleged unauthorized use of its patents, and an injunction prohibiting further infringement.
Steelhead LNG followed this up with further legal proceedings against Cedar LNG, Pembina Pipeline Corporation, and ARC Resources in British Columbia, with the lawsuit filing alleging that each of the defendants “willfully and improperly exploited information” it supplied to ARC Resources.
A recent survey by KPMG concerning the ongoing trade war with the U.S. has found that 80% of Canadian energy and natural resources chief executive officers (CEOs) are confident they can withstand a sustained tariff war.
However, they are pressing for government action to eliminate interprovincial trade barriers and commit to building a national infrastructure backbone that will protect the country’s sovereignty and drive economic growth.
Doug Ewing, a partner in KPMG’s Global Infrastructure Advisory practice who leads the firm’s Major Project Advisory Services, points out that megaprojects are crucial to Canada’s economic development and infrastructure growth but require meticulous planning, robust governance, and effective stakeholder engagement.
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Canada: Canada Minister Wants LNG Canada Doubled, Eyes Western Pipeline Upgrade
Canada’s government supports doubling the scale of an already-huge natural gas project on the west coast and now sees it as “likely,” according to its resources minister, as the country pushes to diversify exports away from a hostile US. The LNG Canada consortium, which includes Shell Plc and Petronas, is expected to send its first shipments of liquefied natural gas within months. Then the group will have to make a final investment decision on whether to proceed with a second phase.
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“Yes, we would like to see a positive FID from LNG Canada 2,” Jonathan Wilkinson, the natural resources and energy minister, said in an interview.
LNG Canada represents tens of billions of dollars in investment in investment and is one of the largest private sector projects in Canadian history. Phase 2 would double its capacity to 28 million metric tons per year. It’s important in Canada’s efforts to diversify trade, but it’s also important to fit it within the government’s “climate architecture,” Wilkinson said.
In one of his first speeches after becoming prime minister in March, Mark Carney said LNG Canada is a “project of national significance.” That shows a “commitment” to try to get a positive decision on the second phase, Wilkinson said in an interview at his North Vancouver office.
LNG Canada Vice President Teresa Waddington said the company and its five joint-venture investors continue to explore pathways to a phase 2 expansion, and that the decision will factor in competitiveness, affordability, speed, future greenhouse gas emissions, and stakeholder needs. It would mean more revenue for governments and help countries with energy transition goals, she said.
“As world events continue to demonstrate, a reliable supply of responsibly produced energy should never be taken for granted,” Waddington said by email. “We’re proud to be part of the effort to deliver that energy while helping Canada diversify its export markets. LNG Canada’s proposed Phase 2 expansion would further support those objectives.”
The minister outlined a series of west coast projects that he said would – if all were built – make Canada the fifth biggest LNG exporter in the world, allowing it to find buyers for 50% of the gas it currently sends exclusively to the US. They included LNG Canada, as well as Cedar LNG and Woodfibre LNG.
President Donald Trump’s barrage of tariffs on Canada and threat to use “economic force” to make it a 51st US state have sparked profound political upheaval and prompted the country to seek new partners and markets. It’s a dominant subject in a national election scheduled for April 28.
Canada doesn’t want to escalate the tariff dispute, Wilkinson said. It’s trying to respond tactically, or even mirror US import taxes when it can, as it did with auto tariffs. But it has further retaliatory measures it can explore if necessary.
“Everything is on the table, all the way down to looking at some of the kinds of things like critical minerals that they use, and those could potentially be points of leverage both ways — to hurt them as they’ve hurt us, or potentially to leverage them into a more reasonable approach,” Wilkinson said.
“There certainly are opportunities to think about some of the things that they use in large quantities that they need.” Asked if nickel was an example, he agreed.
Trans Mountain Boost
Canada’s trade war with the US has triggered a fresh conversation about finding new buyers for the country’s vast natural resources, including its oil, almost all of which goes to the US, where it sells at a substantial discount to global crude prices, as well as strategically reducing its exposure to US infrastructure.
There’s a debate about shipping that oil from the western province of Alberta to Canada’s east coast. Such a pipeline is “on the table,” but a “very challenging route,” Wilkinson said, citing companies he’s spoken with, because it would take a long time and cost C$40 billion to C$50 billion, probably require significant federal government financial support, and eastern refineries aren’t currently set up for it.
An easier first step in increasing Canada’s oil-export capacity would be to upgrade the Trans Mountain pipeline that runs from Alberta to the British Columbia coast, Wilkinson said. Modifications would help the pipeline carry an additional 200,000 to 300,000 barrels a day. Trans Mountain Corp., which is owned by the government, is looking at that, Wilkinson said.
Canada is assessing other options to reduce its reliance on a section of pipeline that goes through the US Midwest before reentering Canada through Ontario. That may include bringing more oil in from Newfoundland to ports in Atlantic Canada and Montreal, or moving some through existing infrastructure from Quebec into Ontario, he said.
Questions remain about the Liberal Party’s approach to hydrocarbon projects in light of policies implemented under previous Prime Minister Justin Trudeau, whose government tightened environmental rules to mitigate climate change.
Beyond energy, Canada needs “to brace ourselves for some impacts” from US softwood lumber tariffs from the White House, Wilkinson said. Canada can try to sell more to Asian markets and use more wood internally, he said, citing a Carney campaign commitment to use mass timber in modular homes.
But the US is “never going to be able to produce enough lumber to be able to meet the housing demand” domestically, he added.
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US: Venture Global’s Calcasieu Pass LNG terminal gets FERC approval for full operations
This approval marks the final step before the US LNG developer transitions to commercial operations, enhancing its contribution to the global LNG market. The Federal Energy Regulatory Commission (FERC) has approved Venture Global’s request to commence full operations at its Calcasieu Pass liquefied natural gas (LNG) facility and TransCameron pipeline in Louisiana, US.
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This approval marks the final step before the US LNG developer transitions to commercial operations, enhancing its contribution to the global LNG market.
Venture Global has confirmed that the facilities were constructed in line with FERC’s standards and are expected to operate safely and reliably, according to a report by Reuters.
The company plans to begin commercial operations on 15 April, three years after shipping its first LNG cargo from the Calcasieu Pass plant.
The Calcasieu Pass project spans 432 acres with approximately one mile of deep-water frontage.
It features 18 626,000 tonnes per annum liquefaction trains in nine blocks, three gas pre-treatment trains, two ship loading berths for vessels up to 185,000m³, and two 200,000mm³ LNG storage tanks.
The project also features a 720MW combined cycle gas turbine power plant, including an additional 23MW (nominal) gas-fired aeroderivative turbine.
The TransCameron Pipeline, a 42in diameter, 24-mile-long (38.6km) lateral pipeline, connects the facility to interconnection points near Grand Cheniere Station in Cameron Parish, Louisiana.
It received FERC authorisation in February 2019 and links to the ANR, TETCO and Sabine Pipelines, providing access to more than two billion cubic feet per day of natural gas supplies.
Last month, Venture Global received non-free trade agreement export authorisation from the US Department of Energy for its Calcasieu Pass 2 (CP2) LNG project in Cameron Parish.
The CP2 terminal, located on a 1,150-acre site adjacent to the Calcasieu Pass facility, is the company’s third LNG venture.
The CP2 LNG facility is in the advanced engineering stage and is expected to have an export capacity of 20 million tonnes per annum.
https://www.offshore-technology.com/news/calcasieu-pass-lng-terminal-ferc-approval-full-operations/
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Global LNG Development
Malaysia : PETRONAS and PV GAS strengthen strategic LNG co-operation
At the headquarters of PetroVietnam Gas Corp. (PV GAS), a delegation from Malaysia’s National Oil and Gas Corporation, PETRONAS, led by Shamsairi M. Ibrahim – Vice President of the Corporation, paid a visit and held discussions with PV GAS. The meeting aimed to explore opportunities for further co-operation under the memorandum of co-operation (MoC) signed be-tween Vietnam Oil and Gas Group (Petrovietnam) and PETRONAS. Representing PV GAS at the meeting were Nguy?n Phúc Tu? – Vice President of PV GAS, along with representatives from relevant divisions and units.
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PETRONAS is one of the world’s leading energy corporations, operating comprehensively across the oil and gas value chain from upstream to downstream. In the LNG sector, PETRONAS is currently one of the largest global suppliers, with an annual production volume of approximately 33 million t with multiple LNG projects worldwide.
During the meeting, both sides discussed potential cooperation opportunities not only in LNG supply but also in expanding investment in gas/LNG infrastructure development and other related sectors to meet Vietnam’s growing energy demand.
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Nigeria: P-CNGi, LNG Arete sign pact for $27.3m gas plant project
The Presidential Compressed Natural Gas Initiative (P-CNGi) and LNG Arete Ltd. on Friday, April 4, 2025, signed a Memorandum of Understanding (MoU) on $27.3 million gas plant project to boost CNG infrastructure investment, expansion and availability. The Programme Director/Chief Executive Officer, P-CNGi, Mr. Michael Oluwagbemi, said the partnership aimed at constructing a Liquefied Natural Gas (LNG) plant with a processing capacity of seven million standard cubic feet per day (MMSCFD).
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The P-CNGi (investing $6 million) is co-investing alongside the LNG Arete (investing $12 million) and the Midstream Downstream Gas Infrastructure Fund, under the Nigerian Midstream and Downstream Petroleum Regulatory Authority (NMDPRA).
Oluwagbemi said the project, which would employ over 100 Nigerians, would accelerate CNG infrastructure development in the north, securing a 25 per cent equity stake in LNG Arete’s seven MSCFD mini-LNG facility located in Ajaokuta, Kogi State.
According to him, the project which will become operational in the next 12 to 16 months, will establish a critical supply hub for CNG across Northern Nigeria, and beyond.
He said it would ensure stable cost-competitive CNG supply for industry and residential users in the north which was underserved.
Oluwagbemi said due to increasing demands to access gas for transportation and industrialisation, the President was determined to bring affordable transportation programmes by leveraging abundant gas resources and boost steady supply to the end users.
“Gas is cheaper, it is safer, and more reliable.
“Of course, the previous administration and this administration have been committed to moving gas from the region where it is primarily produced today, which is the southern part of the country, to the rest of the country.
“That is why the Nigerian National Petroleum Company Limited (NNPC Ltd.) and its partners have been investing in the Ajaokuta-Kaduna-Kano (AKK) gas pipeline.
“From the producing fields, the project will focus on a liquefaction plant and implant storage at Ajaokuta, and eventual pipeline trucks which will be able to move gas over further distances across the north of Nigeria,’’ he assured.
He said the LNG which would be transformed to CNG could be utilised by our power plants, as well as our vehicles and other industries, boosting industrialisation.
The P-CNGi boss said many industries across the north, ranging from textile, agriculture, processing to manufacturing, would benefit hugely from the project.
“The logistics, of course, of moving goods and food items from the north down to the south, especially, processed and manufactured products, will also be cheaper because of this project.
“And even more importantly, is that even when the north gets piped by natural gas in a few years’ time, this plant is still going to be very critical to enable LNG trucks that run more efficiently on LNG, even better than CNG.
“Those LNG trucks will begin to move Nigerian products from Nigeria to Ghana, and to Senegal, ensuring Nigerian products are very competitive and creating jobs,’’ he said.
Also speaking, Hajara Pitan, Project Director, LNG Arete, expressed appreciation to President Bola Tinubu, the management of P-CNGi and other enablers that ensured the reality of the agreement.
“A major reason for the lack of development of the gas sector has been the fact that infrastructure and gas is expensive, but with the mini-LNG technology, we’re able to participate as Nigerians in this sector in a major way.
“Our aim is clear in LNG Arete to support the Federal Government in deepening gas utilisation across Nigeria, and especially in the underserved regions of northern Nigeria.
“LNG is liquefied natural gas, and so what that means is that we take gas from where it originates, we liquefy it by reducing the quantity and allow it to move around more easily,’’ she said.
https://www.environewsnigeria.com/p-cngi-lng-arete-sign-pact-for-27-3m-gas-plant-project/
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Papua New Guinea: TotalEnergies attracts more competitors for major Papua LNG contracts
New bidders are stepping forward for EPC contracts as operator seeks improved capital costs. TotalEnergies has introduced a leading Chinese oilfield services company into the bidding mix for at least one major contract on the Papua LNG project in Papua New Guinea, as the operator seeks improvements to the liquefied natural gas schemes’ capital costs.
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The French supermajor one year ago suspended the project because the quotes it received for the engineering, procurement and construction contracts were too high.
The final investment decision was delayed as TotalEnergies began a new process in a bid to improve the EPC costs.
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Australia: Buru executes strategic development agreement with Clean Energy Fuels Australia
Buru Energy Ltd has provided the following update regarding the progress of its 100% owned Rafael gas project located in the Canning Basin, approximately 150 km east of Broome and approximately 85 km south of Derby in the Shire of Derby-West Kimberley, Western Australia. The Rafael gas project is targeting the replacement of long-haul trucked or imported fuel used for power generation and mining in the northwest of Western Australia with a local source of trucked LNG and liquids, supporting the development of new market opportunities in the region, and delivering projected long term cashflows from 2H27.
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Buru has executed a strategic development agreement (SDA) with Clean Energy Fuels Australia Pty Ltd (CEFA) to co-develop the Rafael gas project. The SDA provides a clear pathway to building a valuable long-term gas and condensate business in the northwest of Western Australia, combining Buru’s upstream resource and expertise with CEFA’s strong downstream and midstream capabilities, strong financial backing and incumbency in the Western Australian domestic LNG market.
CEFA, an Octa Group portfolio company, has a track record of developing and operating small scale LNG infrastructure assets in Australia. Octa Group is owned by I Squared Capital (ISQ), a top five global infrastructure fund with US$40 billion in assets under management.
Buru and CEFA have agreed a business model as the basis for future binding agreements, expected to be executed in late 2025. CEFA will fully finance, build, own and operate an LNG plant with a capacity of up to 300 tpd and associated condensate infrastructure on the Rafael 1 wellsite.
CEFA/Octa Group will be responsible for the midstream elements of the project involving the distribution of LNG and condensate to end users. Buru and CEFA will work together to conduct sales and marketing with customers.
CEFA’s investment in the Rafael gas project will be recovered through gas processing fees charged to Buru over an estimated 20-year production life, the terms of which will be negotiated over the coming months.
Buru is responsible for the financing, construction, and operation of the upstream elements of the project, which currently consist of two wells (including the Rafael 1 discovery well), Native Title negotiations and Western Australian State Government environmental approvals for the small footprint project.
Buru is pursuing several options to fund its 2025 Rafael 1 well recompletion and testing programme to support independent certification of the Rafael reserves, and the drilling of a development well in 2026. Reserves certification is a key condition precedent to binding agreements with CEFA.
Final investment decision for the project is planned for late 2025/early 2026, with robust cashflows targeted to commence from 2H27.
Buru CEO, Thomas Nador, said: “The agreement with CEFA is a watershed moment for Buru and the Rafael Gas Project. It marks a clear demonstration of the Company’s gas strategy and transition from explorer to developer and long-term producer.
“Rafael is the only confirmed source of conventional gas and liquids in onshore Western Australia north of the North West Shelf Project. It is a unique opportunity to provide energy to a growing market that is not connected to a gas pipeline and currently faces challenges with high energy costs and security of supply.
“Combining forces with the I Squared backed CEFA/Octa Group is a material development on the path to commercialising the Rafael resource. I look forward to our collective effort to deliver the economically attractive Rafael Gas Project.”
CEFA/Octa Group CEO and Director, Basil Lenzo, added: “We are very pleased to be working with Buru on the Rafael Gas Project as part of our Energy Transition Platform. Our proven virtual pipeline or ‘trucked LNG’ model lowers long-term regional energy costs and emissions and provides a viable alternative to diesel for new and existing energy users.”
Executing the SDA with CEFA is a significant development for the Rafael gas project. The terms of the SDA outline the respective and joint roles and responsibilities of Buru and CEFA in working toward the execution of binding agreements in late 2025.
Buru and CEFA will develop gas pricing arrangements to enable competitive LNG sales to customers, provide robust economic returns for each party and include a mechanism to share upside value that may be captured. The parties will also collaborate on condensate production, transport and sales.
Under the binding agreements, CEFA will finance, build, own and operate a small scale LNG plant with a capacity of up to tpd and condensate facilities situated on the existing cleared Rafael 1 well pad. A processing tariff to be paid by Buru to CEFA will be negotiated.
This structure will materially de-risk the downstream/midstream capital components of the Rafael gas project for Buru. It means Buru’s upfront costs are limited to the upstream components of the Project which currently consist of two wells (including the Rafael 1 discovery well) and the gas and condensate upstream processing facilities.
This LNG processing tariff model will enable predictable, regular long-term cash flows for both Buru and CEFA, which can be beneficial for financing and operational planning. It also provides greater flexibility in managing operational costs and adjusting to market conditions, as fees can be structured to reflect changes in demand or operating expenses.
A processing tariff model will incentivise efficient processing operations, encouraging CEFA as downstream operator to optimise plant performance to minimise costs and maximise throughput.
Under the SDA, Buru and CEFA have agreed an in-principle business model for collaboration and the basis for future binding agreements for the Rafael gas project. The binding agreements will cover:
Gas and condensate supply arrangements by Buru.
LNG production arrangements and facilities by CEFA.
Conditions Precedent (CP) for binding agreements covering Buru, CEFA and Joint CPs. For Buru, these consist of Independent Reserves Certification, Production Licence over EP 428, Regulatory approvals and Native Title approvals. CEFA CP’s relate to works and development approvals, and Joint CPs relate to LNG and condensate sales and marketing activities.
Supply commencement window and telescoping window arrangements targeting 2H 2027 commencement and a supply period of 20 years.
Gas and condensate pricing framework.
LNG and condensate marketing.
Other standard industry terms and conditions.
Next steps
Buru continues to expedite Native Title and regulatory approvals in support of the Rafael gas project development timeline.
Preparations are underway to conduct the recompletion and extended flow testing of Rafael 1 in the 3Q25. This activity is required to support Independent Reserves Certification, a key Condition Precedent under the SDA.
Buru continues to mature the 2026 drilling programme and has defined the second well for the development (Rafael B) to be drilled from the existing Rafael 1 well pad during next year’s operating window to provide further appraisal, flow assurance and backup for the Rafael LNG plant.
Buru is pursuing a number of funding strategies including the introduction of a farm-in party to fund the forward drilling program for the Rafael gas project.
The timeline is indicative and is subject to capital availability, future discussions with potential asset partners, offtake arrangements, land access, and regulatory approvals.
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Africa: ADNOC Finalizes Farm-In to Mozambique’s Area 4 LNG Project
ADNOC’s investment subsidiary, XRG, has closed on the acquisition of Galp’s 10% interest in Mozambique’s Area 4 concession in the Rovuma basin—Mozambique Romuva Venture (MRV), led by ExxonMobil and Eni. The acquisition announced in May 2024 gives ADNOC a share in the project’s 25 mtpa of liquefied natural gas (LNG) production across combined assets including the operational Coral South Floating LNG (FLNG), as well as the Coral North FLNG development and Rovuma LNG onshore facilities that are currently in planning stages.
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“For over 50 years, ADNOC has been a reliable and responsible global provider of LNG, and we are building on this role with this landmark investment in the world-class Rovuma supergiant gas basin in Mozambique as we deliver on our international growth strategy,” Musabbeh Al Kaabi, ADNOC executive director for low-carbon solutions and international growth, said in the deal’s closing announcement on 22 March.
He added, “… this acquisition supports our efforts to build an integrated global gas business to ensure we continue providing a secure, reliable, and responsible supply of natural gas.”Formed in November 2024 with an enterprise value of $80 billion, XRG focuses on international investments in gas, chemicals, and lower-carbon energy solutions. As lead partners in MRV, ExxonMobil is constructing and operating the onshore liquefaction plant while Eni leads on construction and operation of Area 4 upstream offshore facilities.
Waiting for FID as Contract Awards Fly
In October 2024, ExxonMobil awarded front-end engineering design (FEED) to McDermott through a consortium with Saipem and China Petroleum Engineering and Construction Corp. for Phase 1 of the onshore LNG plant.
Also related to the onshore plant was an engineering, procurement, and construction (EPC) contract to JGC, Fluor, and TechnipFMC (JFT).
The latest concept for the 18-mtpa Rovuma Onshore LNG liquefaction plant is a modular, electric-drive design which produces LNG with a carbon intensity that compared to industry benchmarks is significantly reduced.
Modules that will make up the facility are to be fabricated offsite and then assembled at Afungi, increasing flexibility and reducing on-site execution risks. The newest design will also reduce greenhouse gas emissions more than the previous concept.
MRV is a joint venture between Eni, ExxonMobil, and CNPC, which holds a 70% interest in the Area 4 exploration and production concession with Eni as operator. Other partners with 10% stakes each include the Korean Gas Corp., Mozambique’s state-owed ENH (Empresa Nacional de Hidrocarbonetos E.P.), and ADNOC through its XRG subsidiary.
Looming Competition Stirs Things Up
ExxonMobil said it will take a final investment decision (FID) when FEED is completed. The company’s FY2024 year-end investor presentation predicts that it will happen in 2026.
Fitch Ratings, however, suggested that MRV’s partners might decide to speed things up after its competitor, TotalEnergies’ Mozambique LNG (Area 1), received US Exim Bank approval of $4.7 billion in loan guarantees for US goods and services related to EPC activities on 13 March.
TotalEnergies CEO Patrick Pouyanné stated that the bank’s 4-year pause on loan guarantee approval was a key issue that needed resolution before the French company could lift the force majeure it declared in 2021 due to the ongoing insurgency in the Afungi peninsula, where the TotalEnergies and MRV projects are located.
Operated by TotalEnergies (26.5% stake), partners in Mozambique LNG (Area 1) include: Mitsui E&P Mozambique Area1 Ltd. (20%), Mozambique’s ENH Rovuma Área 1, S.A. (15%), ONGC Videsh Ltd. (10%), Beas Rovuma Energy Mozambique Ltd. (10%), BPRL Ventures Mozambique B.V. (10%), and PTTEP Mozambique Area 1 Ltd. (8.5%).
https://jpt.spe.org/adnoc-finalizes-farm-in-to-mozambiques-area-4-lng-project
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US: NextDecade signs 20-year deal with Aramco to supply LNG from Rio Grande facility
U.S. liquefied natural gas producer NextDecade (NEXT.O), opens new tab said on Tuesday it had signed an agreement with a subsidiary of top oil producer Saudi Aramco (2222.SE), opens new tab to supply the superchilled gas from its Rio Grande facility for 20 years. The United States is already the world’s largest exporter of LNG and producers have plans in place that would double capacity in coming years.
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Aramco is seeking to become a big player in the LNG market, and had been in discussion about a supply deal with NextDecade for some time. The two signed a non-binding agreement in June 2024.
The Aramco subsidiary will purchase 1.2 million tonnes per annum of LNG from the fourth liquefaction facility, known as a train, at Rio Grande. The deal is subject to NextDecade taking a positive final investment decision (FID) on the project.
The Rio Grande LNG export plant has suffered repeated delays and been in development for years. The first train is expected to reach completion by 2027 at an expected cost of about $18 billion. The company made an FID to construct the project’s first three liquefaction trains in 2023.
LNG developers typically take FIDs on projects when they have lined up enough supply deals to obtain the financing needed to build.
Aramco has shown interest in both taking equity positions in U.S. LNG projects and signing long-term LNG supply agreements with U.S. producers.
Aramco last June signed a Heads of Agreement with Sempra Infrastructure for 5 million tonnes per annum of LNG from its Port Arthur LNG Phase 2 expansion project.
The HoA could also see Aramco taking a 25% stake in the 13.5 million tonne per annum Phase 2 project should it get a financial greenlight.
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LNG as a Marine Fuel/Shipping
US: Cheniere Energy Achieves Landmark 4,000th LNG Shipment
Cheniere Energy (LNG) has reached a significant milestone, marking its 4,000th liquefied natural gas (LNG) cargo shipment. This achievement, loaded onto the Maran Gas Ithaca at the company’s Sabine Pass facility in Louisiana. Notably, the company accomplished this feat in just over nine years since commencing LNG exports in 2016, a record time for the industry.
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Since its inaugural export in 2016, Cheniere Energy has expanded its reach to over 40 markets across five continents, solidifying its position as a critical energy supplier. The company now handles approximately half of all LNG exports from the United States, positioning it as the nation’s leading LNG producer and the second largest globally.
Cheniere’s operations are located along the U.S. Gulf Coast, with two primary export terminals: Sabine Pass in Louisiana, the site of the 4,000th shipment, and Corpus Christi in Texas. The Corpus Christi terminal currently boasts a capacity of 15 million tons per annum (mtpa) across its three operational trains.
Jack Fusco, Cheniere Energy’s President and CEO, attributed the company’s remarkable success to its unwavering commitment to safety and operational excellence. “This milestone is a testament to the dedication and hard work of our team, who have consistently prioritized safety and efficiency,” Fusco stated. “We are immensely proud to have achieved this milestone faster than any other LNG producer and remain committed to reliably supplying LNG to meet the world’s growing energy needs.”
The company is actively expanding its Corpus Christi facility through the Stage 3 project, initiated in 2022. This expansion will add seven new trains, significantly increasing the terminal’s production capacity to over 25 mtpa. A crucial step in this expansion was recently completed with Bechtel, the project’s engineering, procurement, and construction (EPC) contractor, handing over control of the first new train and its associated systems to Cheniere.
Cheniere Energy’s rapid growth is indicative of the increasing global demand for LNG as countries pursue cleaner energy alternatives. The company’s strategic investments and operational efficiency have positioned it to capitalize on this growing market. Fusco emphasized Cheniere’s commitment to maintaining its leadership role while prioritizing safety and reliability for its customers.
“As the world transitions to a lower-carbon future, LNG will continue to play a vital role in ensuring energy security and supporting economic development,” Fusco stated. “Cheniere is committed to being a reliable and sustainable partner in this transition.”
With the achievement of its 4,000th shipment, Cheniere Energy is poised for continued growth and expansion
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Europe: LNG Cargoes Land at Wider Discounts in Europe
It’s getting cheaper to bring a shipment of liquefied natural gas into Europe because of heightening competition between terminals to accommodate extra cargoes. The delivered price of LNG for northwest Europe widened its discount to the continental benchmark Title Transfer Facility in recent weeks, according to data from Spark Commodities Pte Ltd. The price difference was as much as minus 71.5 cents last week, according to the data.
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Imports in western Europe reached their highest level for March in records going back to 2017, according to ship-tracking data compiled by Bloomberg. That’s happening as demand in Asia weakens, most noticeably in China, and Europe prepares to refill depleted inventories during the summer.
Greece’s Public Power Corp. SA last week bought an LNG cargo on a DES basis for May delivery at roughly a 70-cent discount to the TTF benchmark.
The widening difference demonstrates an increase in demand for delivery slots at European terminals, said Qasim Afghan, a commercial analyst at Spark.
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South Korea: Purus signs for LNG carrier newbuild in South Korea
Purus Marine has contracted an LNG carrier newbuild in South Korea. Brokers have named the UK-based owner behind a newbuilding contract announced by HD Korea Shipbuilding & Offshore Engineering (HD KSOE) last week.
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HD Hyundai Samho will build the 180,000 cu m unit for about $262m, with delivery expected in December 2027.
Established in 2020, Julian Proctor-led Purus has been involved in over 60 deals in various shipping segments, including four 180,000 cu m LNG carriers built at Samsung Heavy Industries and delivered in 2024 and 2025.
Prior to the latest newbuild, the company booked a pair of medium-sized gas carriers at Hyundai Mipo Dockyard last September, taking the 45,000 cu m series at the yard to six with deliveries between 2025 and 2027.
https://splash247.com/purus-signs-for-lng-carrier-newbuild-in-south-korea/
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Zimbabwe : ZIM Secures Long-Term Charters for 10 LNG Dual-Fuel Vessels in $2.3B Deal
ZIM Integrated Shipping Services Ltd. announced Tuesday it has entered into new long-term charter agreements for ten 11,500 TEU liquefied natural gas (LNG) dual-fuel container vessels. The total charter hire consideration for these agreements is approximately $2.3 billion, and the vessels will serve across ZIM’s various global trade routes.
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Seven of the vessels will be chartered to ZIM by Containers Ventures Holdings Inc., an affiliate of the TMS Group. The remaining three vessels will be chartered by a shipping company affiliated with Kenon Holdings, Ltd., which was ZIM’s largest shareholder until the end of 2024.
The newbuild vessels will be constructed at Zhoushan Changhong Shipyard in China, with deliveries expected between 2027 and 2028.
Eli Glickman, ZIM President & CEO, stated that these agreements further advance the company’s fleet strategy by securing long-term charters for these 11,500 TEU LNG dual-fuel containerships. He noted that this ensures access to a crucial vessel segment and strengthens ZIM’s core LNG fleet, which he described as a critical commercial differentiator. “Importantly, this versatile capacity is ideally suited for ZIM’s various global trades, enhancing our commercial agility and growth potential,” Glickman said in a statement.
He further emphasized that expanding ZIM’s LNG fleet supports the company’s decarbonization objectives and solidifies its position as an industry leader in carbon intensity reduction. Glickman added that operating LNG capacity has proven commercially advantageous for ZIM, and the company anticipates increased demand for environmentally friendly shipping options, making access to LNG capacity even more beneficial in the future.
“The addition of these ten LNG dual-fuel vessels will help keep our modernized fleet competitive and support profitable growth over the long term, benefiting our shareholders,” Glickman concluded.
The acquisition of these ten LNG dual-fuel vessels follows ZIM’s receipt of 46 newbuilds contracted in 2021 and 2022, which significantly improved the efficiency of its operated capacity. This latest move underscores ZIM’s commitment to modernizing its fleet, enhancing operational efficiency, and pursuing environmentally sustainable shipping solutions. The long-term charters provide ZIM with predictable costs and access to modern, fuel-efficient vessels that can adapt to various global trade demands.
Established in Israel in 1945, ZIM is a prominent global container liner shipping company, operating in over 100 countries and serving around 33,000 customers across more than 330 ports worldwide. The company combines advanced digital strategies with a strong commitment to ESG principles to deliver innovative seaborne transportation and logistics solutions, along with an exceptional customer experience. ZIM’s unique global-niche approach—driven by agile fleet management and strategic deployment—focuses on key trade routes and select markets where it maintains a competitive edge.
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Technological Development for Cleaner and Greener Environment Hydrogen & Bio-Methane
Japan-Australia flagship hydrogen project stumbles
Japan wants to become a hydrogen fuel leader to meet its net-zero goals, but one blockbuster project is hanging in the balance over questions about its climate credentials. Hydrogen’s climate credentials also depend on how it is produced. Tokyo: Japan wants to become a hydrogen fuel leader to meet its net-zero goals, but one blockbuster project is hanging in the balance over questions about its climate credentials. The Hydrogen Energy Supply Chain (HESC) is billed as a billion-dollar attempt to ship liquid hydrogen from Australia to Japan.
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However, cold feet about the project in Australia means HESC will source hydrogen from Japan to meet a 2030 deadline for its demonstration phase.
Hydrogen sounds promising on paper: while fossil fuels emit planet-warming greenhouse gases, burning hydrogen creates only water vapour.
But it has not yet lived up to its promise, with several much-hyped projects globally struggling to overcome high costs and engineering challenges.
Hydrogen’s climate credentials also depend on how it is produced.
“Green hydrogen” uses renewable energy, while “blue hydrogen” relies on fossil fuels such as coal and gas, with carbon-capture technology to reduce emissions.
“Brown hydrogen” is produced by fossil fuels without any carbon capture.
The HESC project aims to produce blue hydrogen in the Australian state of Victoria, harnessing abundant local supplies of lignite coal.
With the world’s first liquid hydrogen tanker and an imposing storage site near Kobe in Japan, HESC had been touted as a flagship experiment showcasing Japan’s ambitions for the fuel.
HESC says it aims to eventually produce enough hydrogen to “reduce about 1.8 million tonnes per annum of CO2 from being released into the atmosphere”.
Japan’s energy sector emitted 974 million tonnes of CO2 from fuel combustion in 2022, according to the International Energy Agency (IEA).
Strong opposition
Japan’s government pledged 220 billion yen (now $1.4 billion) to HESC’s current “commercial demonstration” phase, which has a completion deadline of 2030.
But to meet this deadline, the project will now source hydrogen in Japan.
That has been blamed on cold feet among Australian officials concerned about the project’s environmental payoff.
A spokesman for Japan’s Kawasaki Heavy Industries, one of the companies behind HESC, said the decision to shift production to Japan was taken “chiefly because of delay in procedures on the Australian side”.
The Victoria government did not respond to repeated requests for comment, though Australian officials have told local media that the move was a Japanese “commercial decision”.
Australia’s cooling interest in the project is due to “strong opposition” from environmental activists and energy experts opposed to carbon capture and storage, said Daisuke Akimoto of Tokyo University of Information Sciences.
“The main problem the project faces is the lack of approval of the blue hydrogen project by the Victorian government,” Akimoto said.
Kawasaki said it has not yet decided what type of hydrogen it will procure in Japan and downplayed the project’s challenges.
“We are very positive” about HESC and “there is no change” to the goal of building a new supply chain, the spokesman said, declining to be named.
Evidence gap
However, sourcing the hydrogen locally leaves “a critical evidence gap at the middle of the project” — proving carbon capture and storage work — explained David Cebon, an engineering professor at the University of Cambridge.
That is “difficult and challenging and not being done successfully anywhere”, Cebon said.
Kawasaki has said it will continue “feasibility studies” for the HESC project, but Cebon believes it will “quietly die”, partly because of the cost of shipping hydrogen to Japan.
To be transported by sea as a liquid, hydrogen needs to be cooled to -253 degrees Celsius (-423.4 Fahrenheit) — an expensive, energy-intensive process.
“I think wiser heads in the government just realised how crazy it is,” said Mark Ogge from the Australia Institute think-tank.
Japanese energy company Kansai Electric has separately withdrawn from a different project to produce “green” hydrogen in Australia.
A company spokesman declined to comment on reports that the decision was due to ballooning costs.
It will take decades
Resource-poor Japan is the world’s fifth largest single-country emitter of carbon dioxide.
It already produces some hydrogen domestically, mostly using natural gas and oil or nuclear power, although this is limited and expensive.
Some experts are sanguine about HESC’s challenges.
Noe van Hulst, a hydrogen advisor to the IEA, said it was important to take the long view.
“Pilot projects are undertaken to test innovations in practice: learning-by-doing,” he told AFP.
“Yes, it is hard to develop a low-carbon hydrogen market and it will take decades,” as with wind and solar energy, van Hulst said.
Solar in particular has seen costs plummet and uptake soar far beyond initial expectations and at greater speed.
And for now, “there isn’t really an alternative (to) decarbonise these hard-to-electrify sectors like steel, cement, ships and planes”, van Hulst added.
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Deutsche Bahn and ITM Power boost green hydrogen transport
Deutsche Bahn (DB) partners with ITM Power to pioneer green hydrogen solutions for transport. Their collaboration drives sustainability forward rapidly.
The two companies will actively investigate innovative technologies and evaluate eco-friendly transport systems thoroughly. Moreover, they aim to create efficient supply chains and develop hydrogen-based operations effectively.
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DB already pursues ambitious plans to incorporate hydrogen vehicles into its diverse transportation fleets. For instance, in 2023, the company finalized a $42 million contract with CaetanoBus for 60 hydrogen buses.
The German rail giant also targets replacing its 1,300 diesel locomotives with hydrogen trains by 2050. This initiative reflects DB’s dedication to cutting emissions and modernizing operations significantly.
https://hydrogeneurope.eu/deutsche-bahn-and-itm-power-boost-green-hydrogen-transport/
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Fluxys Begins Construction on Belgium’s First Hydrogen Pipeline Network
(P&GJ) — Fluxys has begun construction on the first phase of Belgium’s hydrogen pipeline network, marking a key milestone in the country’s push toward a low-carbon economy. The project, led by Fluxys hydrogen NV, involves building open-access hydrogen pipelines in the industrial port zones of Antwerp and Ghent, including the corridor from Kallo to Zelzate. The infrastructure will use multi-purpose pipeline technology similar to that of recent natural gas lines, and is expected to be operational by 2026.
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“This infrastructure is essential for decarbonising the industry,” said Pascal De Buck, CEO of Fluxys hydrogen and CEO and Managing Director of Fluxys Belgium. “With this step, Fluxys as an industrial group takes on its role in the energy transition.”
Fluxys hydrogen, a subsidiary launched in 2023, was officially appointed in April 2024 as Belgium’s Hydrogen Network Operator, responsible for planning and managing the country’s open-access hydrogen network. The construction decision follows extensive consultations with government bodies, regulators, and industrial stakeholders, and is supported by the European Union’s Resilience and Recovery Fund.
The network aims to enable connections for both hydrogen producers and consumers, and will expand gradually based on market development and government-backed risk mitigation.
Fluxys hydrogen plans to offer up to 30 TWh of hydrogen transmission capacity annually by 2030.
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Air Liquide Launches China’s First 300-Bar Hydrogen Filling Center in Shanghai
Air Liquide has inaugurated China’s first 300-bar hydrogen filling center in Shanghai, with the capacity to fuel 1,000+ heavy-duty trucks daily. The 12-tonne-per-day site supports both mobility and industrial hydrogen supply, boosts logistics efficiency with 300-bar trailers, and strengthens the Yangtze River Delta’s clean energy goals.
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Air Liquide has officially opened a new 300-bar hydrogen filling center in Shanghai, marking a milestone both for the company and the Yangtze River Delta’s decarbonization efforts. The launch represents the first 300-bar hydrogen facility in China, signaling a boost in industrial-scale mobility and supply chain reliability for hydrogen fuel.
With an initial capacity of 12 tonnes of hydrogen per day, the facility is capable of refueling over 1,000 medium-to-heavy-duty trucks—an impactful move in a region that already deploys approximately 5,000 hydrogen fuel cell vehicles and hosts 18 operational refueling stations.
“Today, I’m happy to celebrate the launch of Air Liquide’s new hydrogen filling center in Shanghai, marking a key development in hydrogen energy infrastructure for the Yangtze River Delta region. This investment represents a significant advancement, as it is China’s very first 300 bar hydrogen facility!” said Erwin Penfornis, Group VP of Hydrogen Energy World Business Line at Air Liquide.
The new center supports a flexible mix of low-carbon and renewable hydrogen supply, helping Air Liquide meet rising demands across sectors. More importantly, it introduces 300-bar trailers to the Chinese market—bringing increased payload capacity and reduced emissions over the legacy 200-bar format. This shift offers greater logistical efficiency, particularly in heavy transport applications where payload economics and range are critical.
“The facility’s initial daily filling capacity of 12 tonnes supports hydrogen mobility across the region, enabling the refueling of over 1,000 medium-to-heavy-duty trucks per day and serving industrial customers. This contributes to enhancing the reliability and efficiency of the local hydrogen supply chain.”
The project aligns seamlessly with Shanghai’s clean energy strategy and broader climate ambitions. Hydrogen is increasingly seen by regional planners as a critical component of industrial decarbonization, clean logistics, and energy independence. The new site will serve as both a mobility hub and a distribution point for industrial applications, further anchoring hydrogen in the region’s green transformation roadmap.
“We have the ability to supply different types of hydrogen from this facility, either low carbon or renewable. Additionally, the introduction of 300 bar trailers will improve logistical efficiency, offering a substantial payload increase and reduced transportation emissions compared to traditional 200 bar trailers.”
Penfornis expressed gratitude to Air Liquide’s partners Shenergy and SCIP, and acknowledged support from SINOPEC, PetroChina, and French Minister Jean-Noël Barrot, who attended the opening ceremony with his delegation.
“This project aligns with Shanghai’s commitment to hydrogen energy development and its broader climate objectives. With the region already deploying approximately 5,000 hydrogen fuel cell vehicles and 18 refueling stations, we are contributing to the ongoing progress in this important sector.”
“Today, I’m happy to celebrate the launch of Air Liquide’s new hydrogen filling center in Shanghai, marking a key development in hydrogen energy infrastructure for the Yangtze River Delta region. This investment represents a significant advancement, as it is China’s very first 300 bar hydrogen facility!” said Erwin Penfornis, Group VP of Hydrogen Energy World Business Line at Air Liquide.
The new center supports a flexible mix of low-carbon and renewable hydrogen supply, helping Air Liquide meet rising demands across sectors. More importantly, it introduces 300-bar trailers to the Chinese market—bringing increased payload capacity and reduced emissions over the legacy 200-bar format. This shift offers greater logistical efficiency, particularly in heavy transport applications where payload economics and range are critical.
“The facility’s initial daily filling capacity of 12 tonnes supports hydrogen mobility across the region, enabling the refueling of over 1,000 medium-to-heavy-duty trucks per day and serving industrial customers. This contributes to enhancing the reliability and efficiency of the local hydrogen supply chain.”
The project aligns seamlessly with Shanghai’s clean energy strategy and broader climate ambitions. Hydrogen is increasingly seen by regional planners as a critical component of industrial decarbonization, clean logistics, and energy independence. The new site will serve as both a mobility hub and a distribution point for industrial applications, further anchoring hydrogen in the region’s green transformation roadmap.
“We have the ability to supply different types of hydrogen from this facility, either low carbon or renewable. Additionally, the introduction of 300 bar trailers will improve logistical efficiency, offering a substantial payload increase and reduced transportation emissions compared to traditional 200 bar trailers.”
Penfornis expressed gratitude to Air Liquide’s partners Shenergy and SCIP, and acknowledged support from SINOPEC, PetroChina, and French Minister Jean-Noël Barrot, who attended the opening ceremony with his delegation.
“This project aligns with Shanghai’s commitment to hydrogen energy development and its broader climate objectives. With the region already deploying approximately 5,000 hydrogen fuel cell vehicles and 18 refueling stations, we are contributing to the ongoing progress in this important sector.”
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Energy Vault Secures $28M for World’s First Green Hydrogen Microgrid for PG&E
Energy Vault Achieves Successful Close of $28 million in Project Financing for the Calistoga Resiliency Center, the World’s First Ultra-Long Duration Hybrid Green Hydrogen Energy Storage Microgrid serving California’s PG&E. $28 million project financing, inclusive of the completed sale of the Investment Tax Credit associated with the project, returns cash back to Energy Vault’s balance sheet for the first resiliency center deployed in California (Calistoga) for PG&E to reduce wildfire risk and manage Public Safety Power Shutoff (PSPS) events
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This strategic financing is the first of other project financings underway and demonstrates successful execution of Company’s ‘Own & Operate’ strategy outlined during May 2024 Investor and Analyst Day
Binding commitments have also been executed for Investment Tax Credits associated with two additional projects owned by Energy Vault nearing COD in Texas which are expected to yield an incremental $25+ million
WESTLAKE VILLAGE, Calif– Energy Vault Holdings Inc. (NYSE: NRGV) (“Energy Vault” or the “Company”), a leader in sustainable, grid-scale energy storage solutions, today announced the successful close of $28 million in project financing for its Calistoga Resiliency Center (CRC). The financing includes the completed sale of an Investment Tax Credit (ITC) associated with the CRC. This marks a significant milestone in the Company’s execution of its growth strategy in owning and operating energy storage assets as first outlined during the May 2024 Investor and Analyst Day.
Currently under site commissioning, the Calistoga Resiliency Center, which Energy Vault developed to serve a tolling contract with Pacific Gas & Electric Company (PG&E), is a state-of-the-art hybrid microgrid energy storage facility that integrates advanced hydrogen fuel cells with lithium-ion batteries, specifically designed to address power resiliency given the growing challenges of wildfire risk in California. As climate change continues to increase the frequency and severity of fire-prone conditions, utilities must occasionally implement Public Safety Power Shutoff (PSPS) events to prevent electrical equipment from potentially sparking fires during extreme weather events.
Energy Vault’s CRC provides a unique fully sustainable solution to this challenge by enabling the isolated Calistoga community microgrid to maintain power during these necessary safety shutoffs. The 293 MWh microgrid system delivers ~48 hours of continuous energy supply with a peak power output of 8.5 MW during PSPS events. When operating in island mode, the CRC utilizes green hydrogen in fuel cells for electricity generation, providing essential power to the community. After supporting black-start and grid forming requirements of the microgrid, Energy Vault’s B-VAULT™ DC battery technology works in concert with the fuel cells, ensuring instantaneous response and maintaining grid stability throughout operation. The CRC achieved mechanical completion, and the system is now under commissioning, with full commercial operation expected in Q2 2025.
This zero-emission system aligns with California’s Renewable Portfolio Standard (RPS) while meeting PG&E’s multi day long duration energy storage requirements. The entire microgrid is orchestrated by Energy Vault’s technology-agnostic VaultOS™ Energy Management System, enabling black-start, grid forming and seamless performance orchestration across all subsystems while communicating with PG&E’s Distribution Control Center.
The CRC serves as a model for Energy Vault’s future utility-scale hybrid microgrid storage system deployments as the only existing zero-emission solution to address PSPS events that is scalable and ready to be deployed across California and other regions prone to wildfires.
“The successful financing of the Calistoga Resiliency Center represents our team’s focus and execution in beginning 2025 by replenishing cash to our balance sheet from the prior year capex spent building the system,” said Robert Piconi, Chairman and Chief Executive Officer of Energy Vault. “This is the first of two energy storage assets expected online this quarter as we execute our ‘Own & Operate’ asset management strategy, and we are looking forward to beginning generating predictable, recurring and high margin tolling revenue streams for the years to come,” Piconi continued. “As California faces increasing wildfire risks, the CRC demonstrates how advanced energy storage technology can help communities maintain critical services and safety during necessary power shutoffs. This facility will play a crucial role in ensuring energy resilience for the Calistoga community during PSPS events while maintaining our focus on innovative and sustainable carbon-free energy solutions.”
The project financing success follows through on initiatives first presented during Energy Vault’s May 2024 Investor and Analyst Day, demonstrating the Company’s ability to execute on its strategic vision while maximizing capital efficiency in its ‘Own & Operate’ strategy. This milestone reflects significant proactive interest from strategic partners and investors given attractive IRR economics, positioning Energy Vault for continued growth in the rapidly evolving energy storage asset infrastructure market. As previously announced, Energy Vault has executed binding agreements to monetize additional ITC tax credits and secure project financing for its Cross Trails and Customer R&D Center microgrid project, both co-located on adjacent land parcels in Snyder, TX.
About Energy Vault
Energy Vault® develops, deploys and operates utility-scale energy storage solutions designed to transform the world’s approach to sustainable energy storage. The Company’s comprehensive offerings include proprietary battery, gravity and green hydrogen energy storage technologies supporting a variety of customer use cases delivering safe and reliable energy system dispatching and optimization. Each storage solution is supported by the Company’s technology-agnostic energy management system software and integration platform. Unique to the industry, Energy Vault’s innovative technology portfolio delivers customized short, long and multi-day/ultra-long duration energy storage solutions to help utilities, independent power producers, and large industrial energy users significantly reduce levelized energy costs while maintaining power reliability. Please visit www.energyvault.com for more information.
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HNO International Signs Agreement with Zhuhai Topower New Energy Co., Ltd. For $5M Scalable Hydrogen Energy Platform (SHEP(TM)) Pilot in China
HOUSTON, TX– HNO International, Inc. (OTC:HNOI), a leader in hydrogen-based clean energy technologies, is pleased to announce a strategic partnership with Zhuhai Topower New Energy Co., Ltd., a prominent Chinese renewable energy company, to initiate a pilot deployment of HNOI’s Scalable Hydrogen Energy Platform (SHEP™) in China.
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Zhuhai Topower, established in 2015, has been recognized as a high-tech enterprise and an innovative SME in Guangdong Province. With investments totaling approximately $340.63 million USD in new energy holdings for power generation, the company has successfully obtained several key projects, including a 100MW wind power project and a 50MW photovoltaic power generation project.
The collaboration aims to leverage HNOI’s innovative SHEP™ technology to enhance the proliferation of hundreds of fairly low cost modular hydrogen production and refueling infrastructure in the province.
“Partnering with Zhuhai Topower represents a significant milestone in our mission to expand the global reach of our hydrogen production and refueling solutions,” said Don Owens, Chairman and CEO of HNO International. “This collaboration not only underscores the versatility of our SHEP™ technology but also aligns with our commitment to supporting sustainable energy initiatives worldwide.”
This initiative marks HNOI’s first foray into the Chinese renewable energy market, reflecting the company’s strategic efforts to promote clean hydrogen solutions on a global scale. By integrating SHEP™ with Zhuhai Topower’s know-how and renewable energy projects, both companies aim to set a precedent for scalable and sustainable energy solutions in the region.
About Zhuhai Topower New Energy Co., Ltd.
Zhuhai Topower New Energy Co., Ltd., established in 2015, is a high-tech enterprise recognized for its innovative contributions to the renewable energy sector in Guangdong Province, China. The company has invested heavily in wind and solar energy projects, including a 100MW wind power project and a 50MW photovoltaic power generation project, demonstrating a strong commitment to sustainable energy development.
HNO International (HNOI) is a company specializing in the design, integration, and development of green hydrogen-based energy technologies. With over 15 years of experience in green hydrogen production, HNOI and its leadership team are on a mission to help lead the renewable energy transition by making energy accessible to businesses and communities worldwide. Their pioneering solutions, including the Scalable Hydrogen Energy Platform (SHEPTM), the Compact Hydrogen Refueling Station (CHRSTM), and the Mobile Hydrogen Refueling System (MHRS) are setting new standards for green hydrogen production.
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EU Launches €600 Million Funding Call for Hydrogen Development
The European Union has today announced a significant step towards bolstering its energy infrastructure with the launch of a €600 million ($665 million) funding call. This initiative, under the Connecting Europe Facility (CEF), aims to support crucial cross-border energy projects, with a particular focus on hydrogen infrastructure, alongside electricity and carbon capture and storage (CCS) projects. The funding, managed by the Climate, Infrastructure and Environment Executive Agency (CINEA), will be available for both project studies and construction works.
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This financial boost is exclusively open to projects that have already been granted the status of Projects of Common Interest (PCIs) or Projects of Mutual Interest (PMIs). These designations provide projects with streamlined permitting and regulatory processes, accelerating their development and implementation.
A significant aspect of this funding call is the strong emphasis on hydrogen infrastructure. The latest list of PCIs and PMIs includes 65 hydrogen projects, highlighting the EU’s commitment to developing a robust hydrogen economy. These projects encompass vital hydrogen interconnections across Western, Central Eastern, South Eastern Europe, and the Balkans, which are essential for creating a pan-European hydrogen network. This network will facilitate the transport and utilization of clean hydrogen, a key element in the EU’s strategy to achieve its ambitious climate and energy targets.
The funding opportunity will remain open until September 16, 2025, and the results of the call are expected to be announced in early 2026. This timeline provides project developers with ample opportunity to prepare and submit their proposals for these strategically important infrastructure developments
Speaking about the funding call, Energy and Housing Commissioner Dan Jørgensen emphasized the urgent need for intensified energy investments within the EU. “Now, more than ever, we must intensify our investments to ensure a genuine Energy Union,” Commissioner Jørgensen stated. “This is key to power our competitiveness, ensure our energy security, and bring down energy costs for all. Constructing the crucial missing links for seamless cross-border energy flows is essential – and the CEF’s contribution is instrumental in this respect.”
The CEF Energy program, with a total budget of €5.88 billion for the period 2021-2027, serves as a vital financial instrument for supporting the development of key energy infrastructure in Europe. By focusing on cross-border projects, the program aims to enhance energy security, promote market integration, and facilitate the transition to a clean energy system. Projects selected as PCIs or PMIs not only gain access to potential funding but also benefit from accelerated permit granting and improved regulatory treatment under the Trans-European Network for Energy (TEN-E) Regulation.
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