NGS’ NG/LNG SNAPSHOT June 16-30, 2025
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City Gas Distribution & Auto LPG
Alternative site for bio-CNG plant identified at Iduvai in Tiruppur
TIRUPPUR: To address the burning issues regarding solid waste management, the Tiruppur City Municipal Corporation has identified eight acres of land in Iduvai to set up a bio-CNG plant with a capacity to handle 200 metric tons of waste daily. This will be an alternative to the proposed similar project on Kangeyam Road where the public strongly opposed the civic plan.
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A bio-CNG plant produces Compressed Natural Gas (CNG), also known as bio-CNG, from organic waste.
Currently, over 300 tonnes of about 600 to 700 tonnes of garbage generated daily in the city are dumped in an abandoned stone quarry in Neruperichal village. Only 110 t is sent to Micro Composting Centres (MCC) every day. Allegedly around 150 t is sent to recycling projects.
The proposed bio-CNG project planned at Iduvai on the outskirts of Tiruppur city is expected to solve to some extent issues regarding solid waste management. The Corporation is now disposing garbage in different stone quarries one after another in view of public protests against the practice.
It recently selected the Neruperichal quarry but the public protested there too and the dumping had to be carried out under police protection on Saturday.
Political parties and the public are likely to oppose the unsafe solid waste management practices.
R Saravanan, TVK’s trade union district secretary, from Neruperichal, said, “Dumping garbage in stone quarries pollutes groundwater and the environment. We have not allowed the vehicles to dump garbage for the past three days. They dumped the garbage under police protection on Saturday. Fearing police action, the public did not come forward to protest.”
R Sathish Kumar, a social activist, said, “Initially, the Corporation dumped garbage in the Mummoorthy Nagar quarry. Then they came to Mudalipalayam. Due to public protests there, they shifted to Kalampalayam. The public fought there too, forcing the civic body to move to Neruperichal now. There too, the public is protesting. Dumping garbage in a stone quarry is an illegal act.”
BJP Women’s National President Vanathi Srinivasan on Saturday demanded a permanent solution be found instead of dumping garbage in stone quarries.
Corporation Commissioner R Maheshwari (in-charge) told TNIE that the issues in solid waste management will be resolved within three months.
“To address the current issues, we have identified eight acres of land in Iduvai to set up a bio-CNG plant with a capacity to handle 200 metric tons of waste daily. Currently, work orders are being given and it will be operational soon. Once this project is implemented, we will manage the remaining 40% of the garbage through alternative projects,” the Commissioner said.
Regarding the protests at Neruperichal she said: “Police were called in to hold talks with the public. We also held talks with them. We requested the public for permission to dump garbage in the quarry for a few more days. They have also agreed to it. Police were not called in to provide security during the dumping of garbage.”
Further, the Commissioner said, “We are planning to make it mandatory for the public to segregate garbage in the wards.”
The Corporation had already planned to set up a bio-CNG project on Kangeyam Road, however, a new location has been identified due to public opposition.
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Sabarmati Gas to supply PNG to Gandhinagar Military Station in Gujarat
The Gandhinagar Military Station at Chiloda will become the first Indian Army facility in Gujarat to have Piped Natural Gas (PNG) connectivity after an agreement in this regard was inked between the Indian Army and Sabarmati Gas Ltd on Saturday.
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According to a Memorandum of Understanding (MoU) signed between the two, Sabarmati Gas Ltd shall provide PNG connectivity to around 600 households and 20 canteens/MESS by laying a total 18 kilometre-long pipeline network. This project will be completed by October 2025 and upon completion, will provide ease of convenience to around 2,000 men and women residing within the campus by giving them access to continuous, safe and economical natural gas, stated an official release.
Sanjay Sharma, managing director of Sabarmati Gas Ltd, and Brigadier Rajesh Kumar and other senior officials from the Indian Army, Chiloda, were present on the occasion. Sabarmati Gas Ltd is a joint venture between GSPC and BPCL that provides piped gas connectivity in five districts of North Gujarat and has 3.25 lakh domestic customers and 1,550 industrial and commercial customers. It also operates 161 CNG pumps.
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Pune to Get 300-Tonne Bio-CNG Plant as Waste-to-Fuel Project Approved
The state government has approved a major initiative to convert the city’s wet waste into bio-CNG, giving a fresh push to waste-to-fuel solutions. The proposed project, with a processing capacity of 300 tonnes per day, will be set up outside Pune by a private contractor. A government order has been issued, and the Pune Municipal Corporation (PMC) is now set to begin the tender process for the facility.
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Swachh Maharashtra Mission being implemented
Modelled on the central government’s Swachh Bharat Abhiyan (Urban) 2.0, the Swachh Maharashtra Mission is now being implemented across the State. The campaign aims to make all urban centres waste-free through scientific management of solid waste, sustainable sanitation and treatment of wastewater.
In line with this objective, a proposal submitted by PMC’s solid waste management department was reviewed and approved during the 17th meeting of the state-level technical committee, chaired by the principal secretary of the urban development department.
Following this approval, a formal government order was recently issued. As per the order, the Pune civic body will now initiate the tender process to execute the project.
The project will be executed with financial support from both the central and state governments. Earlier, Rs 72,62,50,000 had been approved for a composting plant with a daily capacity of 675 tonnes, and Rs 7,86,67,000 for scientific landfill operations. However, the composting project has now been cancelled. Since funds are still available for landfill work, that amount will be repurposed for the upcoming bio-CNG project.
Project cost division
The new facility will process 300 tonnes of wet waste daily to generate bio-CNG. A total budget of Rs 82,10,73,310 has been sanctioned for this project. Of this, Rs 20,52,68,328 will come from the central government, Rs 28,73,75,658 from the State, and the PMC will bear Rs 32,84,29,324.
A large plot of land is required for the bio-CNG project planned outside Pune city limits. Officials have stated that due to the nature of the plant, a buffer zone is mandatory and the site must be located at least 200 metres away from any residential property. Since no such space is available within the city boundaries, the facility will be constructed outside the municipal area.
Approval has already been granted for the project, which will process 300 tonnes of wet waste daily to generate bio-CNG. A private contractor will be appointed to locate suitable land and bear the cost of constructing the plant. A government resolution sanctioning the project has been issued, and the tender process is about to begin.
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Natural Gas/ Pipelines/ Company News
GAIL to invest Rs 844 crore in pipeline capacity
GAIL (India) Ltd will invest ₹844 crore to expand its Dahej-Uran-Dabhol-Panvel natural gas pipeline network capacity to 22.5 mmscmd. The company has also delayed the completion of the Mumbai-Nagpur-Jharsuguda pipeline project to September 2025, increasing its cost by ₹411.12 crore. Additionally, the Srikakulam-Angul pipeline project’s completion is now expected by December 2025 due to pending forest permissions.
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State-owned gas utility GAIL (India) Ltd on Monday said it will invest Rs 844 crore in expanding Dahej-Uran-Dabhol-Panvel natural gas pipeline capacity to meet increased energy demand.
The DUPL-DPPL network, the name Dahej-Uran-Dabhol-Panvel natural gas pipeline network is referred to, currently has 19.9 million standard cubic metres per day capacity. This is being expanded to 22.5 mmscmd, GAIL said in a stock exchange filing.
GAIL said the pipeline capacity will be added in three years.
“Investment required (is) Rs 844 crore,” it said. “It was approved by the Board of Directors of the company in its meeting held today i.e. June 23”.
GAIL also said it has pushed back the completion scheme of its 1,702 km Mumbai-Nagpur-Jharsuguda pipeline project from June 30, 2025 to September 30, 2025.
This would require additional investment of Rs 411.12 crore, it said. “The project cost is anticipated to be increased by Rs 411.12 crore and therefore, the revised project cost for MNJPL is Rs 8,255.37 crore, which is 5.24 per cent higher than the originally approved project cost of Rs 7,844.25 crore.”
The 693-km Mumbai-Nagpur section of the pipeline is mechanically complete except for a 1 km stretch. The 692-km Nagpur-Jharsuguda pipeline is 98 per cent mechanically completed.
“The pipeline laying work is affected due to delay in obtaining forest permission, NBWL clearance and Ministry of Road Transport and Highways permission along NH-44 in Maharashtra,” it said.
The 317-km Nagpur-Jabalpur pipeline is 97 per cent mechanically completed. “The pipeline laying work is affected due to delay in acquisition of right of use (RoU), permanent land parcels for valve stations and local resistance.”
“The entire Mumbai-Nagpur-Jharsuguda pipeline is expected to be completed progressively by September 2025,” GAIL said.
GAIL said it has also revised the schedule for the 744-km Srikakulam-Angul pipeline project from June 2025 to December 2025.
“Entire mainline of 422 km has been mechanically completed and commissioning has been started. Out of 322 km (spur lines), lowering of 252 km has been completed. Further, work on the pipeline was affected due to delay in obtaining forest permission and till date, working permission of 45 km has been received out of total required permission of 56 km,” it added.
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ONGC set to foray into imported liquefied natural gas business by Q4FY26
State-run Oil and Natural Gas Corporation (ONGC) is all set to foray into the imported liquefied natural gas (LNG) business by the fourth quarter of 2025-26 (Q4FY26), sourcing gas from Henry Hub or West Asia on spot deals to cater to the city gas distribution (CGD) sector, a senior ONGC official said. Henry Hub is a natural gas pipeline hub located in Erath, Louisiana.
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The company is planning to source 3 million tonnes per annum (mtpa) of LNG by FY27, with the option to go for long-term, low-priced sourcing deals, said Arunangshu Sarkar, director of strategy and corporate affairs at ONGC. Through this, the company will come in direct competition with players like GAIL (India) and Petronet LNG. ONGC already has a 12.5 per cent stake in Petronet along with partners like Bharat Petroleum Corporation Ltd (BPCL), GAIL (India), and Indian Oil Corporation Ltd (IOCL), who too hold the same amount of stake each.
“Projections indicate that by 2030, natural gas demand may reach approximately 210 billion cubic metres (BCM), requiring LNG imports of nearly 124 MTPA to meet the shortfall. This highlights a substantial supply gap and underscores the need for strategic intervention. In this context, we are actively exploring opportunities in the LNG business,” Sarkar told Business Standard.
“We have a mandate to secure around 3 MTPA of regasified LNG (R-LNG), which may be sourced through spot market deals from hubs such as Henry Hub or the Middle East (West Asia),” Sarkar said.
He added that the plan was to start with spot deals within the next two quarters, and the company might opt for long-term deals later. India’s annual natural gas requirement stands at approximately 70 BCM, of which around 30 BCM is currently met through LNG imports. Presently, natural gas accounts for around 6.7 per cent of the country’s energy mix, and there is a national target to increase this share to 15 per cent by 2030.
“As the share of gas in the energy mix rises, overall demand is expected to grow significantly. The CGD network is also undergoing rapid expansion, further driving demand. We have a plan to supply it especially to the key CGD sector. For that particular sector, we are planning to go for a long-term, low-priced deal. We are in the process of getting approval for that,” Sarkar said.
LNG terminals expanding
Analysts say ONGC’s plans to enter the R-LNG business come at an opportune time when LNG terminal capacities are expanding in India. “HPCL’s Chhara terminal was commissioned in January. The nearest project completion on the horizon is Petronet’s expansion of Dahej terminal to 22.5 MTPA in the next three-four months. Subsequently, GAIL’s expansion of Dabhol’s capacity to 6.3 MTPA will complete by mid-2027, which is also roughly when Petronet’s greenfield terminal in Odisha’s Gopalpur will come up,” an analyst said on the condition of anonymity.
India currently has eight operating LNG terminals, of which state-owned Petronet’s 17.5 MTPA facility in Gujarat’s Dahej is the largest. The rest have capacities of 5 MTPA each. Of these, Petronet operates a terminal in Kochi, while GAIL, IOCL, and HPCL run terminals in Maharashtra’s Dabhol, Tamil Nadu’s Ennore, and Gujarat’s Chhara, respectively. In the private sector, Adani Total Gas operates two terminals at Mundra in Gujarat, and Dhamra in Odisha, while Shell operates a facility at Hazira in Gujarat.
Petronet controls 50 per cent of India’s 52.7 MTPA R-LNG capacity, and most of its capacities are currently tied, the analyst pointed out. According to a Crisil report from January, Petronet’s capacity at Dahej is almost tied up through take-or-pay contracts or tolling agreements. “Of the total tied-up capacity, 7.5 MTPA at Dahej and 1.42 MTPA at Kochi are under take-or-pay contracts with suppliers/customers. Additionally, 8.25 MTPA is under tolling arrangements,” the report said.
“Beyond Dahej, most R-LNG terminals have struggled with low capacity utilisation due to insufficient pipeline connectivity, a gas market that is still developing, and lack of coordinated planning. But another crucial factor is the limited number of long-term contracts signed between terminals and major offtakers. A large and experienced entity like ONGC can easily strike a deal for regasification capacity,” an industry expert said.
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HPCL’s Rs 2,000 Cr Push For 24 New CBG Plants To Power India’s Green Energy Drive
Meerut: SATAT, a major bet by the Ministry of Petroleum and Natural Gas on transforming organic waste into clean-burning biofuel. Under SATAT, the Indian oil marketing companies like HPCL, BPCL and IOCL are calling on entrepreneurs to set up CBG plants since its inception on 1st October 2018. The bio-fuel is made by capturing methane from biomass, purifying the methane and compressing it, and then it becomes a bio-fuel for vehicles and cooking at home. There are already 106 CBG plants commissioned, and 82 facilities are now under construction; SATAT is no longer aspirational, it is operational.
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“SATAT provides an opportunity to combine sustainability, circular economy, rural jobs, and clean air,” said Vikas Singh, a Director in the Ministry of Petroleum and Natural Gas (MoPNG), at the event. “We want to aim for this credible alternative to traditional gas supplies of all sorts.”
The ambition is audacious
Increase the domestic CBG blend in CNG and PNG supplies from 1% now to 5% by 2029. This increase is expected to reduce the country’s reliance on imported liquefied natural gas (LNG), which currently contributes 50% of domestic demand, and will help decrease carbon emissions to align with India’s net-zero ambitions by 2070.
Biogas in Action: The HPCL Blueprint
HPCL is one of the major players propelling the CBG movement forward. According to Mohit Dhawan, head of HPCL’s renewable energy arm, the company plans to invest Rs 2,000 crore (about $ 231 million) over the next two to three years to establish 24 new CBG plants. Two are already operational.
“Each of these plants will have a capacity to produce 10–15 tonnes of biogas daily using agricultural residue, cattle dung, municipal waste, and sewage water,” Dhawan explained.
Currently, HPCL operates facilities with a combined production capacity of 106 tonnes per day (TPD). The 82 upcoming plants will each add approximately 6.5 TPD on average, pushing daily output well beyond 600 TPD in the next three years. Importantly, these numbers translate into massive reductions in crop burning and greenhouse gas emissions.
“In Haryana alone, 20 of our plants are effectively using stubble that would otherwise be burnt,” an HPCL official said. “It’s a classic case of turning a problem into a resource.”
Inside the Tech: Turning Biomass into Fuel
CBG production involves anaerobic digestion of biomass to generate raw biogas, which is then cleaned and enriched to 97–98% methane purity, comparable to commercial natural gas. This purified gas can be directly injected into city gas distribution (CGD) pipelines, used to power vehicles, or piped into homes for cooking.
The by-products, fermented organic manure (FOM) and liquid slurry, are rich in nutrients and serve as an excellent replacement for chemical fertilisers. According to Arun Jaggi, Director of Circle CBG, “This is not just about energy. It’s about rejuvenating soil, reducing pollution, and creating wealth from waste.”
HPCL’s model relies on two key distribution strategies
CGD Integration: CBG is pumped into city pipelines under offtake agreements with gas distributors.
Retail Dispensing: Select fuel stations have been upgraded to dispense CBG directly to vehicles.
HPCL hailed Uttar Pradesh’s role as a frontrunner in the CBG mission. The state already hosts 22 operational plants, with 24 more under construction. Punjab, another high-potential region, has 16 running units and plans for 25 more.
“Meerut and western UP are central to our expansion,” said Dhawan. “We’re leveraging the proximity to sugar mills and agricultural hubs to source raw material like pressmud and crop residues.”
The company noted that one CBG plant typically requires 5–10 acres of land and a capital outlay of ₹15–20 crore. To reduce the burden on entrepreneurs, stamp duty waivers and subsidies under central schemes like BAM (for machinery) and DPI (for pipelines) have been introduced.
Market Economics: A Green Fuel that Makes Sense
On average, the cost of producing CBG stands at ₹40–42 per kg. The selling price, however, ranges from Rs 70 to Rs 78 per kg, depending on input and logistics costs. This margin, though currently supported by government subsidies, makes the business viable and scalable.
HPCL noted that the ecosystem has recorded a 117% year-on-year growth in production and sales. Last year alone, 42,000 tonnes of CBG were sold across India through 349 retail outlets and CGD networks in 64 geographical zones.
As demand rises from vehicles, industries, and households, the revenue potential will only increase. Operators can also monetise bio-manure, earn carbon credits, and sell recovered CO₂ and sulfur for industrial uses.
National Targets and the Global Context
India is the world’s third-largest energy consumer and among the top greenhouse gas emitters. Natural gas currently accounts for only 6% of the country’s energy mix, far below the global average. The government wants to raise this to 15% by 2030.
Vikas Singh of MoPNG said, “India uses around 28 million standard cubic meters of gas daily for transport and cooking. By 2029, this figure will grow to 44 MMSCMD. CBG can bridge this gap with a domestic, renewable source.”
He emphasised that public sector units (PSUs) are expected to set up 195 of the 480 CBG plants required by 2029. “This is not a pilot, it’s a movement,” Singh said.
The initiative also aligns with India’s pledges at the UN Climate Conference (COP26), including cutting projected emissions by 1 billion tonnes and achieving net-zero by 2070.
Ground-Level Impact: Farmers and Entrepreneurs
Perhaps the most transformative impact of the CBG ecosystem is at the grassroots. Farmers now find value in agricultural waste. Cow shelters and gaushalas are emerging as feedstock providers. Rural youth are becoming plant operators and technicians.
“We are witnessing a silent revolution,” said Mohit Dhawan. “Villages that once saw waste as a liability are now seeing it as a resource.”
In Punjab, for instance, the government has identified land for new plants aimed at tackling stubble burning. Experts believe that if the 25 proposed units come up, the annual air quality crisis in Delhi and surrounding regions could ease substantially.
The HPCL event also heard from stakeholders like Vikas Singh (MoPNG) and Arun Jaggi, who called for more participation from private players and local bodies.
“This is a win-win. Farmers earn, cities breathe easier, and India saves on costly imports,” Jaggi said.
Challenges Ahead
Despite impressive strides, hurdles remain. Feedstock logistics, land acquisition, seasonal availability of raw materials, and lack of awareness among local entrepreneurs are key challenges.
According to HPCL officials, there are also aggregation issues, especially for biomass feedstocks, which are more geographically dispersed. Other stakeholders expressed the need for standard pricing norms and cemented offtake contracts to create more certainty for investors.
There is also the technology problem: biogas power generation is at a very nascent stage, and most producers want to sell purified gas instead of using it to generate electricity, for a better return.
“We need scale, policy support and patience,” said one senior HPCL executive, “but we have made a start. With standardised pricing, clear offtake models, and capital support, we are on the path to a green energy revolution,” said an HPCL spokesperson.
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Mahanagar Gas top pick among CGDs, Gujarat Gas least preferred: Nomura
Nomura has maintained a ‘Reduce’ rating on Gujarat Gas Ltd (GGL), citing intense competition in the I&C space, subdued volume growth prospects, and constrained pricing power.
Nomura on CGDs:Japan-based brokerage Nomura has reiterated its bullish view on Mahanagar Gas Ltd (MGL), upgrading the stock to ‘Buy’ from ‘Neutral’ and naming it the top pick among city gas distributors (CGDs). The upgrade is driven by MGL’s robust volume growth outlook, limited exposure to the volatile industrial and commercial (I&C) segment, and attractive valuation. The target price has also been raised to ₹1,680 from ₹1,345 earlier.
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“We prefer Mahanagar Gas (MAHGL IN, Buy) due to its highest expected volume growth among peers, limited exposure to volatile industrial and commercial (I&C) segments, and attractive valuation compared to peers. MGL is also better placed than IGL on EV-related regulatory challenges, in our view,” said Bineet Banka, research analyst at Nomura, in a note dated June 16.
In contrast, Nomura has maintained a ‘Reduce’ rating on Gujarat Gas Ltd (GGL), citing intense competition in the I&C space, subdued volume growth prospects, and constrained pricing power. The target price for GGL has been cut to ₹406 from ₹470.
For Indraprastha Gas Ltd (IGL), Nomura retained a ‘Neutral’ rating, with a revised target price of ₹210, up from ₹199.
On the bourses, around 10:15 AM, Mahanagar Gas was trading 1.68 per cent higher at ₹1,413; Indraprastha Gas was down 0.38 per cent at ₹211.45; and Gujarat Gas was trading 0.45 per cent higher at ₹480.40.
While the recent 18-20 per cent cut in Administered Price Mechanism (APM) gas allocation has emerged as a short-term headwind for CGDs, Nomura noted that companies have already initiated moderate price hikes of over 2 per cent in both the compressed natural gas (CNG) and domestic piped natural gas (PNG) segments to offset the shortfall.
Among the three key players, Indraprastha Gas Ltd (IGL) has been most affected due to its high CNG exposure (about 73 per cent of sales). MGL, with a relatively balanced portfolio, is seen managing the disruption more effectively.
GGL, on the other hand, has limited exposure (about 44 per cent) to the priority sectors impacted by APM cuts but faces its own set of challenges. Its considerable presence in the I&C segment (about 56 per cent of total volumes) is under pressure from low-cost propane, especially in Gujarat’s Morbi ceramics cluster. With CNG adoption in new vehicles already high at around 31 per cent in the state—compared to 22 per cent in Delhi and Maharashtra—GGL also has limited headroom for growth in the CNG business.
State EV policies to weigh on CNG growth
Nomura flagged policy developments around electric vehicles (EVs) as another important trend impacting the sector. While Delhi and Mumbai continue to tighten their EV policies to combat air pollution, MGL is seen as better positioned than IGL to navigate this transition. Mumbai’s comparatively lower air pollution levels, combined with a policy focus that may initially target liquid fuels over CNG, could offer a temporary reprieve for MGL.
Moreover, MGL’s representation in the Maharashtra High Court-monitored EV committee indicates its proactive approach, with the management optimistic about CNG’s role under the new state EV policy.
Apart from that, a key catalyst across the sector, analysts said, could be the inclusion of natural gas under the Goods and Services Tax (GST) regime. Currently, gas is taxed under a patchwork of indirect levies like state VAT, central excise, and sales tax. Bringing gas under GST would streamline taxation, reduce cost burdens, and enable industrial customers to claim input tax credit—especially beneficial in price-sensitive regions like Morbi, where propane already enjoys GST benefits. Nomura believes GGL stands to gain the most from this reform, given its major I&C customer base.
That said, Nomura prefers MGL for its superior volume outlook, low regulatory risk from EV policies, and attractive valuation. GGL is rated ‘Reduce’ due to demand headwinds in the I&C segment and a challenging competitive landscape, though GST inclusion remains a key upside risk.
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India’s plastic pipes industry set for strong growth, may hit Rs 80,500 crore by FY27: Report
Plastic pipe manufacturers have seen strong performance during real estate rebounds. In FY24, sales rose 1.8x over FY20, reaffirming the sector’s responsiveness to housing cycles. Notably, plumbing and irrigation segments contributed 84% to the industry’s applications in FY14–24, with CPVC, HDPE, UPVC, and PPR pipes witnessing strong growth.
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India’s plastic pipes industry is poised for accelerated expansion, with a projected compound annual growth rate (CAGR) of 14% over FY24–FY27, according to a recent report by Motilal Oswal Financial Services Ltd. The market is expected to scale up from Rs 54,100 crore in FY24 to an estimated Rs 80,500 crore by FY27, driven by strong demand across housing, irrigation, water supply, and sanitation sectors.
The report highlights replacement demand as a significant growth catalyst. Despite challenges in residential launches—down 38% during calendar years 2012–2020—PVC and CPVC pipes have shown consistent momentum, with FY20 sales up 46% compared to FY12. The durability and affordability of plastic pipes, which constitute just 2–3% of total building costs, have further boosted their uptake.
Historically, plastic pipe manufacturers have seen robust performance during real estate rebounds. In FY24, sales rose 1.8x over FY20, reaffirming the sector’s responsiveness to housing cycles. Notably, plumbing and irrigation segments contributed 84% to the industry’s applications in FY14–24, with CPVC, HDPE, UPVC, and PPR pipes witnessing strong growth.
Public infrastructure schemes such as the Jal Jeevan Mission (with a Rs 67,000 crore outlay), PM Krishi Sinchayee Yojana (PMKSY), and smart city initiatives are also driving demand. The report emphasizes the untapped potential in rural irrigation—around 52% of India’s cultivated land still lacks proper irrigation—presenting a significant opportunity for PVC pipe deployment.
Urban infrastructure and energy distribution are also undergoing transformation, led by high-performance polymer pipes. HDPE, MDPE, and PEX pipes are gaining traction in city gas distribution (CGD) due to their flexibility, cost-effectiveness, and corrosion resistance. With the government aiming for 70% CGD coverage by 2030 and an increase in the gas share in India’s energy mix from 6.7% to 15%, this segment is set to expand rapidly.
Technological advancements are also redefining applications. CPVC pipes are enabling efficient hot and cold water systems, OPVC is replacing ductile iron pipes in sewage networks, and HDPE pipes are playing a key role in micro-irrigation and urban projects. These developments are expected to widen market opportunities and ensure long-term growth.
The housing sector remains a core driver, with strong launch pipelines and recurring replacement needs ensuring sustained demand for plastic piping solutions, the report concludes.
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ONGC takes control of Rudrasagar Well in Assam to control gas blowout
The ONGC started working on the safety protocol soon after the detection. A team reached the venue and started the restoration work. Oil and Natural Gas Corporation (ONGC) has taken operational control of Well RDS 147 in its Rudrasagar field in Sivasagar, Assam, to control gas blowout, the state-owned energy PSU said on Saturday. Earlier on Friday, gushes of gas were seen erupting from the Well RDS-147 of the ONGC’s Rudrasagar field.
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The ONGC started working on the safety protocol soon after the detection. A team reached the venue and started the restoration work.
“As of 16:00 hrs, a team led by the Director (Technical & Field Services) has taken over operational control of Well RDS#147,” the ONGC said in an official release.
“All necessary fluids and equipment have been mobilised to the site. A comprehensive well control plan has been formulated, and pumping operations commenced following the successful installation and testing of essential connections,” the PSU added in the release.
“A team from ONGC Assam Asset and the district administration is actively engaging with local residents who were evacuated from nearby areas as a precautionary safety measure. All necessary arrangements are being made to ensure their welfare and well-being,” ONGC added in the release.
Maharatna ONGC is the largest crude oil and natural gas Company in India, contributing around 71 per cent to Indian domestic production. Crude oil is the raw material used by downstream companies like IOC, BPCL, HPCL and MRPL (Last two are subsidiaries of ONGC) to produce petroleum products like Petrol, Diesel, Kerosene, Naphtha, and Cooking Gas LPG.
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Policy Matters/ Gas Pricing/ Others
“There will be stability in prices”: Union Minister Puri on shortage fear over India’s energy supplies amid Israel-Iran conflict
New Delhi [India], June 18 (ANI): Amid escalating tensions between Israel and Iran, Union Minister for Petroleum and Natural Gas Hardeep Singh Puri on Wednesday assured that India has sufficient petrol and diesel reserves and that country has nothing to worry about, as it also has enough energy supplies for the coming months.
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When asked about potential oil and gas shortages due to the conflict, Union Minister Hardeep Singh Puri, speaking exclusively to ANI, emphasised that India’s energy strategy focuses on availability, affordability, and sustainability.
“I assure you that there will be no shortage of crude oil. In the last three years, prices have not increased, but have decreased. India is a country that does not increase the price of petrol and diesel. There were three such occasions in November 2021, May 2022 and March 2024. We reduced the prices, so now it would be better if it remains like this. I would not anticipate any disruption in this, I think there will be stability in prices,” he stated.
Earlier on June 16 this year, Union Minister Hardeep Singh Puri revealed positive news about India’s potential oil and gas reserves in the Andaman Sea.
He stated that the region might hold massive reserves comparable to Guyana’s significant oil discoveries. Puri was optimistic about the ongoing exploration efforts, suggesting the Andaman area could be home to multiple large oil and gas reserves.
This potential discovery could be a game-changer for India, reducing its reliance on imported energy, boosting the economy, and improving energy security amidst global tensions like the Israel-Iran conflict. (ANI)
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CNG demand in India may grow along with EV adoption, despite policy pressure: Report
New Delhi [India]: Compressed Natural Gas (CNG) could continue to grow as an auto fuel in India, even as electric vehicle (EV) adoption gathers pace across key states, according to a recent report by Nomura. The report highlighted that state governments, especially Delhi and Mumbai, are expected to roll out aggressive EV policies to address the problem of rising air pollution. While this could put some pressure on the growth of CNG, analysts believe both fuel types could still co-exist in the coming years.
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It stated, “CNG as an auto fuel could grow alongside EVs…. EV policies by states to continue pressuring CNG growth.”
The report added that Delhi, which had already banned diesel vehicles older than 10 years nearly a decade ago, may now consider placing restrictions on CNG vehicles as a next step in its clean fuel transition.
The state is seen to be intensifying its focus on cleaner mobility solutions to tackle worsening air quality.
In contrast, Mumbai, being a coastal city, usually records better air quality index (AQI) levels. In the short term, the EV policy focus in Mumbai could shift more towards reducing the use of liquid fuels like petrol and diesel, rather than targeting CNG.
The report noted that this could work as a policy tailwind for both CNG and EV adoption in Mumbai.
Further, the report mentioned that the ongoing High Court-monitored committee on EV adoption in Maharashtra includes participation from Mahanagar Gas Limited (MGL), a key supplier of CNG in the region.
During its recent investor day, MGL’s management expressed confidence that CNG could benefit under the state’s upcoming EV policy. The company sees potential in policies that promote a multi-fuel transition instead of focusing only on electric vehicles.
The report also pointed out another key development that could benefit gas suppliers, the possible inclusion of natural gas under the Goods and Services Tax (GST) regime.
Currently, natural gas is subject to a combination of state VAT, central excise duty, and central sales tax. Moving it under GST would simplify the tax structure by eliminating these cascading taxes and potentially lowering the overall tax burden for businesses. (ANI)
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LNG Use / LNG Development and Shipping
LNG cheapest option for buses, heavy goods vehicles till 2040
Liquefied natural gas (LNG) is among the cheapest fuel options for the transport and logistics sector, particularlyfor buses and heavy goods vehicles (HGVs), for the next decade and a half. According to an independent series of studies by the Council on Energy, Environment and Water (CEEW), for medium goods vehicles (MGV) and HGV, EVs currently remain more expensive than diesel, compressed natural gas (CNG) or liquefied natural gas (LNG) in 2024.
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“LNG is expected to remain the cheapest option for buses and trucks until 2040. Therefore, for HGVs, large-scale adoption of EVs and green fuels like green hydrogen will require targeted R&D, supporting infrastructure, and cost reductions,” the think tank said.
In contrast, electric vehicles (EVs) are already cost-competitive across key segments — especially two and three-wheelers, taxis, and private cars in states with supportive EV policies. E-two-wheelers already offer the lowest total cost of ownership (TCO), at ₹1.48 per km versus ₹2.46 for petrol models.
EVs also lead in the three-wheeler segment-three-wheeler EVs cost ₹1.28 per km versus ₹3.21 for petrol. Further, EVs deliver major savings for commercial taxis, where daily operating costs matter most.
Heavy vehicles
The HGVs category follows a similar pattern to light goods vehicles (LGVs), where EVs are the most impacted by distance travelled, while diesel is the least affected.
As distance increases, the cost gap narrows between EV and other fuels, but even with a 50 per cent higher distance than the base case, EVs still remain the most expensive option, whereas LNG remains the most affordable option across all scenarios, the CEEW study pointed out. “LNG and CNG are the most sensitive to maintenance cost variations, while EVs are the least affected. For every 50 per cent variation in maintenance costs, the impact on TCO is 19 per cent for LNG, 17 per cent for CNG, 14 per cent for diesel, and 7 per cent for EV,” it explained.
As maintenance costs increase, the cost gap narrows between EVs and other fuels, yet LNG remains the most economically viable option in all cases. In the case of buses, CEEW said that similar to four-wheelers, EVs experience the highest total cost of ownership (TCO) increase when distance decreases, while diesel is the least affected.
Conversely, the reduction in TCO due to higher distances is highest for EVs and lowest for diesel. Diesel, CNG, and LNG remain in a similar cost range if the distance is lowered, with CNG and LNG being the cheapest and EV the most expensive, it explained.
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Half of India’s LNG imports come from Qatar and UAE, relying on Strait of Hormuz for supplies
India imports around 50 percent of its total natural gas requirement, out of which over 50 percent is supplied by two Gulf countries that ship LNG to India via the Strait. Half of India’s total natural gas requirement is met via imports that come through the Strait of Hormuz – supplied by Qatar and the UAE – and thus stands exposed to a higher risk of disruption, according to experts who track movement of energy supplies.
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Out of this total import, over 50 percent is supplied by the two Gulf nations that ship LNG to India via the Strait of Hormuz route. Qatar – India’s largest LNG supplier – exports around 11.4 million metric tonnes (mmt) of LNG, which is over 40 percent of New Delhi’s total annual import. A closure of the shipping lines of the Strait of Hormuz poses a critical threat to these exports, as nearly all of Qatar’s outbound cargoes transit the strait to reach Asian markets, said Harshraj Aggarwal, analyst at Yes Securities.
“While no shipments have been disrupted so far, QatarEnergy has instructed tankers to delay Gulf entry until just before loading, reflecting heightened risk perceptions. For India, any prolonged disruption could lead to supply delays, higher spot reliance, and upward pressure on LNG prices, directly impacting Petronet LNG’s portfolio economics,” Aggarwal added. India’s state-run gas major Petronet LNG has a long-term contract with QatarEnergy for supplying 7.5 million tonnes per annum of LNG until 2048.
Asian spot LNG prices have already jumped around 11 percent Week-on-Week (WoW) to $14 per mmbtu (million metric British thermal unit) on fears of disruption.
To shield India from potential supply shock in the Middle East, New Delhi also sources LNG from countries that are logistically detached from the Gulf, including the US, Russia and Australia, among others.
Risk of Costlier Freight
Though energy supplies from the Middle East nations have remained largely undisrupted until now, freight costs for the India’s energy companies have shot up. Oil Minister Hardeep Puri on June 22 said the government is closely monitoring the evolving geopolitical situation in the Middle East and would take all necessary steps to ensure stability of fuel supplies to Indian consumers.
Middle East Conflict
With Middle East nations being large energy suppliers to India, the escalation of the Iran-Israel conflict over the weekend poses serious risk for New Delhi. US President had bombed Iranian nuclear facilities on June 21, increasing risks for vital shipping routes in the region.
India’s critical energy supplies are at risk as it is not only a big consumer but also primarily reliant on imports of crude oil (around 90 percent) and liquified natural gas (around 50 percent).
LPG: Another fuel at risk?
Not only oil and gas, but New Delhi is also highly dependent on imports of liquefied petroleum gas (LPG), which is India’s primary cooking fuel. The nation imports around 60 percent of its total LPG requirements. Data from global trade analytics firm Kpler says of the total LPG imports, India buys around 90 percent of the fuel from West Asian nations including UAE, Qatar, Kuwait and Saudi Arabia. The closure of the Strait of Hormuz would also cripple India’s LPG supplies shipped by the Middle East nations through the route. India’s LPG consumption have risen by 5.5 percent in FY24 from last year, government data showed.
Oil vs Gas
Though not immune, but India’s natural gas import exposure via the Strait of Hormuz is lower than the risk to crude oil. This is on account of two reasons – India’s higher reliance on imports for crude than LNG, and oil constituting a major share in the nation’s total energy basket versus natural gas.
According to Oil Ministry data, India is dependent on imports for nearly 90 percent of its crude oil supplies from countries such as Russia, Iraq, Saudi Arabia. In comparison, New Delhi imports around 50 percent of its natural gas requires.
Secondly, in India’s energy basket, oil and petroleum products form a significant portion – around 26 percent – as against natural gas’ share of 6 percent. India’s crude oil consumption too has continued to grow while the nation’s appetite for natural gas has stayed stagnant. India crude oil imports rose to 5.64 million barrels per day (bpd) in 2024 as against around 5 million bpd in the previous year. The International Energy Agency (IEA) expects this to further grow to 6.66 million bpd by 2030, the agency said in a report earlier this month.
India’s gas consumption, on the other hand, is growing at a slow pace. Domestic gas consumption grew only 7 percent in FY24 from last year, showed oil ministry data.
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Electric Mobility/ Hydrogen/Bio-Methane
Green Hydrogen Mission May Miss Production Target
Chennai: India is likely to miss its target of becoming the global hub for green hydrogen production as almost 85 per cent of projects announced under the mission since 2022 are yet to be commissioned. The National Green Hydrogen Mission (NGHM) launched on January 4, 2022, underscores India’s strategic vision to become a global hub for Green Hydrogen production. This initiative is designed to foster production, exports, create employment, reduce dependence on fossil fuels and decrease greenhouse gas (GHG) emissions. The NGHM envisions the use of Green Hydrogen across key sectors—refineries, fertilisers, city gas, steel, heavy duty transport, and shipping—by 2030. These industries contribute over 25 per cent of the country’s total GHG emissions.
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The Mission targets an annual production capacity of 5 million tonnes of Green Hydrogen, aiming to scale up to 10 million tonnes by 2030.
Since the NGHM’s launch in January 2022, several states have initiated Green Hydrogen policies or taken initiatives towards its production. Around 10 states, which contribute to 80 per cent of the GHG emissions, were expected to take initiatives towards usage of clean energy, according to ICRA.
Projects with more than 12 million tonnes per annum (MTPA) of Green Hydrogen production capacity have been announced, which are enough to meet the NGHM’s targeted production capacity.
However, out of the 164 projects for Green Hydrogen production and electrolyser manufacturing, more than 140 projects or 85 per cent of the projects are yet to be commissioned.
In FY22, the Centre had initially allocated Rs 19,700 crore for the mission. The budgetary allocation for NGHM in FY2026 Budget Estimates (BE) is twice as high as that in FY2025 Revised Estimate (RE). However, only 5 per cent of the initial budget of Rs 19,700 crore is estimated to be utilised by FY2026.
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India’s CV industry quietly begins shift to hydrogen-powered vehicles
Ashok Leyland, Tata Motors and Daimler lead India’s shift to hydrogen-powered commercial vehicles as pilot trials expand under the National Green Hydrogen Mission. From the industrial sprawl of Reliance Industries’ Jamnagar refinery to the frost-bitten heights of Leh and the traffic-choked avenues of New Delhi, a quiet shift is underway in India’s commercial vehicle (CV) sector. Hydrogen-powered trucks and buses — once a speculative future — are now rolling out onto the country’s roads, driven by auto giants like Ashok Leyland and Tata Motors. Others are not far behind.
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While many of these efforts are aligned with the government’s National Green Hydrogen Mission, original equipment manufacturers (OEMs) are also shaping their own road maps to remain future-ready. Ashok Leyland, for instance, made headlines in 2023 when it unveiled the country’s first hydrogen internal combustion engine (H2-ICE) truck, developed in collaboration with Reliance Industries Ltd (RIL). Since then, over 20 of these heavy-duty vehicles have clocked nearly 250,000 kilometres, and have rivalled the efficiency of traditional ICE vehicles.
The company has partnered with NTPC Green to deploy hydrogen fuel cell buses in key locations, including Delhi and Ladakh.
“Among the alternate fuels, the ultimate destination of the CV market is going to be hydrogen. However, it needs the cost structure to be right,” Sanjeev Kumar, president and head of the medium and heavy commercial vehicle division at Ashok Leyland, told Business Standard. “As an organisation, we are ready with technology; it is only a question of when and how, as the cost of hydrogen continues to be very high. Recently, we have also delivered one 55-tonne fuel cell vehicle to Adani (group) for its mining application in Chhattisgarh.”
Tata Motors, too, is carrying out trials of hydrogen-powered CVs. Since March, the company has been testing two trucks — one powered by H2-ICE, the other by hydrogen fuel cell — across a 24-month pilot programme. A total of 16 hydrogen-powered vehicles, with varying payloads and configurations, will ply on some of India’s busiest freight routes in Mumbai, Pune, Delhi-NCR, Surat, Vadodara, Jamshedpur, and Kalinganagar.
“We’ve also started shipping our first hydrogen trucks, which are now going to ply on specific lanes,” P B Balaji, group chief financial officer at Tata Motors, said during a recent post-earnings call.
The pilot, undertaken in partnership with Indian Oil Corporation, aims to gather on-ground data — both to finetune the vehicles and to map out hydrogen availability along key transport routes. At the Bharat Mobility Global Expo earlier this year, Tata Motors Executive Director Girish Wagh signalled that the company was targeting a commercial launch window within the next 12 to 24 months. The company did not wish to share further updates at the moment.
The momentum isn’t limited to Indian firms. Daimler Truck, one of the world’s leading CV manufacturers, is preparing to enter the Indian hydrogen race. “On the path towards decarbonising transport, Daimler Truck is entering the next development phase of its fuel cell trucks,” said Pradeep Kumar T, president of product engineering and chief technology officer, Daimler India Commercial Vehicles.
Following extensive testing, both on tracks and public roads, Daimler’s Mercedes-Benz GenH2 trucks are now approaching the customer deployment phase. “We are currently evaluating customer readiness, infrastructure availability, and local operating conditions to ensure that when our hydrogen trucks enter Indian roads, it will be with full commitment to the quality, safety and reliability that define Daimler Truck worldwide,” he added.
The central government, too, is ramping up its hydrogen play. Through the Ministry of New and Renewable Energy, five pilot projects have been allocated to a group of private players — Tata Motors, RIL, NTPC, Ashok Leyland, Hindustan Petroleum Corporation Ltd, Bharat Petroleum Corporation Ltd, and Indian Oil Corporation Ltd. Together, these projects will put 37 hydrogen-powered vehicles (a mix of buses and trucks) on the road, supported by nine hydrogen-refuelling stations.
The vehicles include 15 powered by hydrogen fuel cells and 22 by hydrogen ICEs. The trials will take place on 10 routes across the country — from Delhi to Thiruvananthapuram.
Launched in January 2023, the National Green Hydrogen Mission has an allocated budget of ₹19,744 crore through to the end of the decade. It is the centrepiece of India’s push towards becoming aatmanirbhar (self-reliant) in clean energy and serving as an inspiration for the global clean energy transition.
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EcoYou Powers 125 Bio-CBG Plants Worldwide, Reinforcing India’s Green Tech Footprint
Mumbai (Maharashtra) [India], June 16: Several Indian companies are setting up CBG plants in India, which include Indian Oil Corporation, Bharat Petroleum, Adani Group, EcoYou – Energy Division, Reliance Bioenergy and Oil India to name a few. In a landmark stride toward sustainable industrial development, the Energy Division of EcoYou – Ecoboard Industries Limited, has emerged as a global leader in executing large-scale Biogas/CBG (Compressed Biogas) projects. With over 125 ultra-large-scale biogas digestor installations worldwide, EcoYou’s installed projects process a cumulative annual capacity of 20 million cubic meters of industrial effluents–including dairy waste, spent-wash, and agro-waste–setting new benchmarks in environmental conservation and resource recovery.
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India, an agriculture-rich and rapidly industrializing nation, faces increasing challenges from untreated solid waste like agro-fibers and liquid waste from industries. These issues pose serious threats to ecological health and public well-being. The need for efficient, large-scale waste treatment has never been more critical.
EcoYou’s energy division is addressing this challenge head-on through proven technology collaborations. Its Dry Digestor systems, in partnership with Ruckert Naturgas (Germany), tackle solid waste, while Wet Digestor systems–based on Swiss technology–process high-load liquid waste. The company has also partnered with KP Engineering to deliver Zero Liquid Discharge (ZLD) solutions. Through these innovations, EcoYou transforms industrial waste into bio-CBG, contributing directly to environmental protection, energy security, and economic development.
EcoYou’s Indian clients are now actively participating in the Government of India’s SATAT (Sustainable Alternative Towards Affordable Transportation) scheme, converting raw biogas into purified bio-CBG for industrial and vehicular use.
“At EcoYou, we help our customers turn waste into wealth. This is not just about meeting compliance–it’s about preserving nature, protecting communities, and building a sustainable future,” said G. Ramakrishna Raju, Managing Director at EcoYou. “Effluent treatment is no longer optional–it’s essential for reducing dependence on fossil fuels like LPG and enabling circular economy practices. Our digestors alone help save approximately 0.5 million tons of coal annually, substantially cutting greenhouse gas emissions.”
EcoYou’s advanced biogas systems are powered by Sulzer-based Continuous Stirred Tank Reactor (CSTR) technology, known for its robust, energy-efficient performance in complex industrial environments.
“In India, where industrial growth is accelerating, responsible solid and liquid waste management is vital to protect our rivers, groundwater, and ecosystems,” added Praveen Gottumukkala, Technical Advisor at EcoYou. “Globally, our systems are helping industries reduce their carbon footprint while embracing circularity. This is not just environmental stewardship–it’s sustainable progress that benefits the planet, people, and profits.”
Beyond energy production, EcoYou’s projects have far-reaching environmental and economic benefits. By enabling reuse of treated water, industries reduce their freshwater dependency and operational costs. The systems also support organic composting and sludge-to-energy conversion, aligning with India’s sustainability priorities including the National Water Mission, Swachh Bharat, and multiple UN Sustainable Development Goals (SDGs).
Globally, countries like Germany, Japan, and the Netherlands have stringent discharge norms and high adoption of biogas and ZLD systems. Technologies such as membrane bioreactors (MBRs), advanced oxidation processes (AOPs), AI-enabled monitoring, and real-time analytics are increasingly common. Treated wastewater is reused in agriculture, and sludge is processed into energy or compost, supported by strong digital infrastructure and regulatory enforcement.
India is fast catching up. Adoption of dry and wet digestors and ZLD technologies is growing, especially among large industries. However, challenges such as cost sensitivity and limited awareness hinder adoption in Tier 2 and Tier 3 cities. Although the government mandates Online Continuous Emission Monitoring Systems (OCEMS), consistent data integrity and enforcement still require strengthening.
Despite these gaps, the shift toward resource recovery and renewable energy like CBG is gaining traction. More corporates are integrating bio-CBG projects into their ESG and CSR frameworks, making sustainability part of their core strategy.
Headquartered in Pune, Maharashtra, EcoYou is playing a pivotal role in shaping India’s environmental and industrial future. By serving clients in sectors such as chemicals, pharmaceuticals, textiles, distilleries, and food processing, EcoYou is ensuring that industrial progress and ecological responsibility go hand in hand.
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NTPC hands over five hydrogen fuel cell buses to eco-fragile Himalayan region of Ladakh
This initiative represents the first-ever commercial deployment of hydrogen-powered buses in India, and that too at the highest altitude anywhere in the world, making it a globally significant milestone in green mobility, an official spokesperson said In eco-fragile Himalayan region of Ladakh, the National Thermal Power Corporation (NTPC), on Wednesday, handed over hydrogen fuel cell-based buses to the State Industrial Development Corporation (SIDCO).
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“In a landmark move towards clean and sustainable transportation, a formal handing and taking over ceremony was held today at the NTPC Green Hydrogen Mobility Station, Palam, Leh, marking the transfer of five hydrogen fuel cell-based buses from NTPC Limited to the State Industrial Development Corporation (SIDCO),” said an official spokesperson.
This initiative represents the first-ever commercial deployment of hydrogen-powered buses in India, and that too at the highest altitude anywhere in the world, making it a globally significant milestone in green mobility, he added.
The ceremony was held in the presence of administrative secretary, transport department, Bhupesh Chaudhary, the additional deputy commissioner, Leh, along with senior officials from NTPC, SIDCO and other departments.
Following the formal flag-off of the hydrogen buses, Chaudhary conducted a detailed inspection of NTPC’s green hydrogen plant, including its production, storage, and dispensing systems. He appreciated NTPC’s efforts in implementing such a technologically advanced project in Ladakh’s high-altitude terrain and noted its significance in furthering the UT Administration’s vision of a carbon-neutral Ladakh.
Subsequent to the flag-off, the NTPC team called on chief secretary Pawan Kotwal and apprised him of the project’s successful implementation.
Kotwali lauded NTPC’s pioneering efforts and observed that the successful operationalisation of hydrogen buses in such extreme conditions could usher in a new era of hydrogen fuel cell mobility in India. He also directed the NTPC team to document the entire experiment and operational learnings, so that it may serve as a benchmark for similar initiatives in other regions of the country.
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India launches first commercial hydrogen buses in Ladakh’s high altitudes
Five hydrogen fuel cell buses will soon start running commercially in Leh, Ladakh, an area with some of the world’s highest roads. NTPC Limited officially handed these buses over to the State Industrial Development Corporation at the green hydrogen mobility station in Palam, Leh
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Five hydrogen fuel cell-based buses will soon begin to commercially operate in Leh district of the Union Territory of Ladakh, home to some of the world’s highest motorable roads.
The buses were formally handed over by National Thermal Power Corporation (NTPC) Limited to the State Industrial Development Corporation in a ceremony held at the green hydrogen mobility station in Palam, Leh, on Thursday.
This initiative marks the first-ever commercial deployment of hydrogen-powered buses in India. Officials noted that deploying these clean energy buses on the world’s highest motorable roads makes it a globally significant milestone towards green mobility.
Following the formal flag-off of the hydrogen buses, Transport Department Administrative Secretary Bhupesh Chaudhary conducted a detailed inspection of NTPC’s green hydrogen plant, including its production, storage, and dispensing systems.
He appreciated NTPC’s efforts in implementing such a technologically advanced project in Ladakh’s high-altitude terrain and noted its significance in furthering the administration’s vision of a carbon-neutral Ladakh.
Chief Secretary Pawan Kotwal lauded NTPC’s pioneering efforts and observed that the successful operationalisation of hydrogen buses in such extreme conditions could usher in a new era of hydrogen fuel cell mobility in India.
He also directed the NTPC team to document the entire experiment and operational learnings, so that it may serve as a benchmark for similar initiatives in other regions of the country.
Officials stated that this initiative, developed through the collaborative efforts of the Ladakh administration and NTPC, stands as a testament to India’s growing leadership in renewable energy innovation. It represents a major leap toward sustainable public transport in ecologically sensitive and strategically vital regions.
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Huge Methane Gas Reserve Found in Western Nepal
A preliminary report published on Thursday has revealed that the total methane gas reserves in western Nepal could reach approximately 430 billion cubic metres, enough to possibly meet the Himalayan nation’s demand for gas for around 50 years. The report, prepared by the China Geological Survey (CGS), presented initial findings from just one of the four targeted wells in Jaljale area of Dailekh district, raising the possibility of the Himalayan nation tapping into domestic sources of energy, according to government daily Gorkhapatra.
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The findings were shared with the government of Nepal on Thursday.
The exploration was carried out under a bilateral agreement signed in 2019 between Nepal and China.
“The first drilling operation, launched on May 11, 2021, reached a depth of more than 4,000 metres, revealing an estimated 1.12 billion cubic metres of methane in a single well,” the report said.
“The report represents initial findings from just one of four targeted wells. Based on early estimates, the total reserve in the area could reach 430 billion cubic metres, which could possibly meet Nepal’s demand for gas for around 50 years,” Gorkhapatra said.
Dinesh Kumar Napit, Deputy Director General at the Department of Mines and Geology, and head of the Petroleum Exploration Project said that the site is the deepest and most scientifically advanced exploration carried out in Nepal to date.
The government has allocated 45 ropanis of land equivalent to 2,50,000 sq ft area, which is less than 1 sq km, for the project. Further testing is underway to assess gas quality, commercial viability, and economic potential.
“The final report from the Chinese team is expected by the end of this year, with plans to begin commercial production testing thereafter,” the newspaper said.
This project – entirely grant-funded by the Chinese government – is considered a pilot initiative, with the CGS providing technical and financial support.
The initial estimated cost was Rs 2.5 billion, though delays caused by the COVID-19 pandemic, led to escalation.
https://www.outlookbusiness.com/news/huge-methane-gas-reserve-found-in-western-nepal
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L&T secures land in Gujarat for green hydrogen, ammonia projects
The government is actively promoting green hydrogen as a clean energy source, with initiatives like National Green Hydrogen Mission and pilot projects focused on its use in transportation. Larsen & Toubro (L&T) on Tuesday said it has secured a land in Kandla, Gujarat for development of green hydrogen and green ammonia projects. The government is actively promoting green hydrogen as a clean energy source, with initiatives like National Green Hydrogen Mission and pilot projects focused on its use in transportation.
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Addressing the shareholders, company’s Chairman & Managing Director S N Subrahmanyan said L&T has made significant advances in emerging clean energy segments, particularly green hydrogen and small modular reactors (SMRs).
Electrolyser manufacturing is already in progress, giving the company a first-mover advantage in Green Hydrogen, he said.
“A landmark development was the regulatory approval from US Department of Energy for the transfer of SMR technology to India. With L&T figuring among the only three eligible Indian companies for this, this signals the formal start of our SMR journey empowering us to lead the commercialisation of nuclear energy in the country.
Although we set off with global partners for both green hydrogen and SMRs, our long-term goal is to develop proprietary technology, manufacture core equipment, and deliver cost-effective, innovative solutions tailored for emerging markets,” he said.
Land has been secured in Kandla, Gujarat, for manufacturing green hydrogen and green ammonia units, he said adding that L&T is also capable of executing EPC projects in green hydrogen, ammonia and methanol globally.
Earlier, Larsen & Toubro had announced the incorporation of L&T Green Energy Kandla Pvt Ltd for the development of green hydrogen projects.
Hydrogen produced through the electrolysis of water and powered by renewable energy, is known as green hydrogen.
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INTERNATIONAL NEWS
Natural Gas / Transnational Pipelines/ Others
Oman: OQGN awards $272mln gas pipeline contract
MUSCAT – OQ Gas Networks SAOG (OQGN), the owner and operator of Oman’s gas transportation system, has announced the award of a contract worth RO 105 million for the implementation of the Second Loop Line Fahud-Suhar project – a key initiative to boost the country’s gas supply network.
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In a filing to the Omani bourse on Wednesday, June 18, 2025, OQGN – part of OQ Group – said the contract, covering the engineering, procurement and construction (EPC) of the 193km 42-inch pipeline project, was awarded to the Petroleum Projects Company Petrojet and Partners LLC.
Also as part of the project execution strategy, a related contract for the supply of 193 kilometers of line pipe was awarded to Jindal Saw Limited. The planned execution duration of the project is 24 months.
“The project aligns with the company’s growth strategy and vision in leading the energy infrastructure,” OQGN added.
2022 © All right reserved for Oman Establishment for Press, Publication and Advertising (OEPPA) Provided by SyndiGate Media Inc. (Syndigate.info).
https://www.zawya.com/en/economy/gcc/oman-oqgn-awards-272mln-gas-pipeline-contract-bzd11yys
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Canada Business Group Pushes for Pipeline Expansion in Mexico
Mexico’s Natural Gas Output Has Failed to Keep Up With Demand as It Instead Has Favored Imports From US Suppliers. Canadian companies could help Mexico reduce its lopsided dependency on imported U.S. natural gas by maximizing its own domestic supplies of the fuel, according to the head of Canada’s top business group.While Mexico has for decades been a major oil producer, local natural gas output has failed to keep up with demand as it instead favored imports from U.S. suppliers, mostly across the border in Texas.
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But Canadian firms see opportunities to increase investment in Mexican energy, said Business Council of Canada CEO Goldy Hyder after meeting with Mexican President Claudia Sheinbaum. Executives from major pipeline builders Atco and TC Energy Corp. were present at the sit-down with Sheinbaum at the Group of Seven summit in Kananaskis, Alberta.
“There was a general feeling that it’s in Mexico’s interest to diversify more its sources of energy. It’s dependent on natural gas in the United States. And so obviously Canada can be very helpful in that regard,” Hyder said. “We have projects that are already taking place there that are going to allow Mexicans to have energy security because the gas is in Mexico and it’s being extracted.”
State-owned Petroleos Mexicanos, known locally as Pemex, has struggled for years to boost its natural gas output at home. But due to a growing network of pipelines, Mexico’s reliance on gas from Texas sharply scaled up beginning around 15 years ago as U.S. shale projects took off. More than 70% of the Latin American economy’s demand for the fuel is now satisfied via cross-border imports.
Sheinbaum met with the business council June 16 before her meeting with Canadian Prime Minister Mark Carney on June 17. U.S. President Donald Trump’s unexpected return to Washington late June 16 led to the cancellation of what would have been his first in-person meeting with Sheinbaum. That sit-down was seen as one of the primary reasons for the Mexican president’s attendance as an invited guest.
Sheinbaum’s like-minded predecessor, Andres Manuel Lopez Obrador, sought to wean Mexico off of imported fuel supplies while prioritizing more domestic refining capacity. Since she took office in October 2024, Sheinbaum has mostly continued the policy, though she has successfully pushed a reform to encourage private partnerships with Pemex.
“We have the technological know-how, we have the capital to invest and deploy, and you have a desire to not have all your eggs in a single basket about where you get your energy. And so we can help increase your energy security,” Hyder said. “What the president and others were describing is more that we’re looking for ways to promote the participation in an accelerated way of foreign companies to invest in Mexico.”
As Pemex struggles to lift slumping production and dig itself out from under a roughly $100 billion debt burden, tie-ups with private and foreign firms could help if Sheinbaum’s government gets on board.
Mexico imported more than 7.1 billion cubic feet of natural gas per day from the U.S. during peak season in August last year, according to data from the U.S. Energy Information Administration.
TC Energy’s 444-mile Southeast Gateway Pipeline is soon expected to begin delivering up to 1.3 billion cubic feet of natural gas produced in Texas to southern Mexico. The Canadian firm partnered with Mexican state utility Comision Federal de Electricidad on the project. Once online, it will enable two major power plants to burn natural gas instead of oil and diesel.
https://www.ttnews.com/articles/canada-mexico-pipeline
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US: FERC Natural Gas Pipeline Cost Orders Challenged by Utilities
The Federal Energy Regulatory Commission was wrong to grant a pipeline company its requested method for allocating costs for its project, an association of municipal utilities alleged. The commission’s previous records “strongly indicated that FERC’s initial grant of rolled-in rate treatment had been prematurely and improvidently granted,” the East Tennessee Group said in its brief filed Monday with the US Court of Appeals for the D.C. Circuit.
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The group includes utilities in Tennessee, Virginia, and Alabama—some of which also serve as shippers on the natural gas pipeline system.
The association is challenging FERC’s approval of East …
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Canada: Keyera to buy Plains’ Canadian natural gas liquids business for $3.77 billion
Keyera Corp (KEY.TO), opens new tab said on Tuesday it has agreed to buy substantially all of U.S.-based Plains’ (PAA.O), opens new tab Canadian natural gas liquids business for C$5.15 billion ($3.77 billion) in cash. The buyout expands Keyera’s position with a fully connected natural gas liquids corridor stretching from western to eastern Canada and bringing key NGL infrastructure under Canadian ownership, the Canada-based pipeline operator said.
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In February, Keyera and Canada-based energy infrastructure firm AltaGas (ALA.TO), opens new tab entered into long-term agreements for processing liquefied petroleum gases.
This comes at a time when U.S. President Donald Trump has imposed tariffs on Canadian goods, with a 10% levy on energy imports, which include oil, natural gas, electricity, coal, uranium, and critical minerals.
As a result, Canadian companies are aiming to reduce dependence on the U.S. by expansion opportunities within the country or in other markets such as those in Asia.
Keyera said the acquired assets include NGL extraction, fractionation, storage, as well as rail and truck terminals located across Canadian provinces Alberta, Saskatchewan, Manitoba and Ontario.
Plains said in its statement the transaction is expected to close in the first quarter of 2026 and that it will divest its Canadian NGL business.
The company added that as of June 30 this year it will reclassify the NGL assets associated with the transaction as discontinued operations.
Plains said it would retain substantially all those assets in the U.S. and also all crude oil assets in Canada.
It currently estimates it will incur about $360 million of entity-level taxes payable in Canada associated with the sale and the restructuring of the remaining Canadian crude assets.
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Nigeria: PCNGi kicks off CNG supply, pricing framework amid rising demand
The Presidential Compressed Natural Gas Initiative (PCNGi) has launched the implementation of its Concessionary Autogas Supply and Pricing Framework to regulate pricing and streamline supply in Nigeria’s fast-growing auto CNG market. The launch comes amid surging demand for compressed natural gas as an alternative fuel and a rapid expansion of refueling stations across the country, positioning CNG as a key component of the government’s clean energy transition strategy.
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Speaking at the Mobility CNG Supply Framework Kick-Off Event in Abuja, Michael Oluwagbemi, Programme Director, PCNGi, highlighted the significance of the framework as a key component of President Bola Tinubu’s ongoing energy reforms.
He explained that the new pricing structure, approved earlier in 2024 by the Chief Executive of the Nigerian Midstream and Downstream Petroleum Regulatory Authority (NMDPRA), allows for autogas CNG to be priced lower than gas for power generation or industrial use, recognising it as a strategic national industry.
“What we are doing here today is to flag off the implementation of that concessionary pricing framework, because it was necessary, as you can imagine, that in an economy where gas is being used for various purposes, that it’s possible for someone to say, I want to make demands of gas for auto CNG since it’s priced lower, and then go and use it for power.
“So there was a potential opportunity for arbitrage. So we needed to do it in an organised market for autogas CNG, and also then develop the marketplace where people can actually make demand, pay for it, get their gas, use it, sell it into the auto CNG. As you know, that market has been growing tremendously in the last year”, Oluwagbemi said.
The framework also lays the foundation for a regulated and efficient marketplace, ensuring that stakeholders across the value chain from gas suppliers to station operators and vehicle owners can participate transparently and sustainably.
According to Oluwagbemi, the Nigerian auto CNG market has witnessed exponential growth in the past year. From just 20 CNG refueling stations nationwide, the country now boasts over 65, with two newly inaugurated in Ibadan and another 27–28 expected in the coming weeks.
“So there is a growing market. We just got the announcement by Dangote that he’s also adding another 100 data stations to the 175 that we have under construction. So you can imagine that we need to get this going in an organised way”, he said.
Vehicle conversion has also seen an increase, he said “We’ve gone from about 4,000 CNG vehicles, mostly in Edo State, to over 50,000 daily users across the country. And that doesn’t include trucks, which are being converted at a rapid pace every day.”
He added that long queues at CNG stations in cities like Abuja are now a common sight, a clear indicator of rising demand. “It’s a good problem, and we’re here to solve it. The market won’t be perfect from day one, but our job is to make it better every day,”
Looking ahead, PCNGi estimates that Nigeria will have between 125,000 to 200,000 CNG vehicles on the road by the end of 2025, aiming to hit a national target of one million vehicles by 2027. While the PCNGi is spearheading the initiative, Oluwagbemi emphasised that the private sector is responsible for the majority of vehicle conversions two to three times the number carried out by government-supported channels.
“Our role is to incentivize and enable. The government won’t build everything, But by providing targeted incentives like concessionary gas pricing, we can catalyze private investment and deliver a more secure energy future for Nigerians,” he said.
https://businessday.ng/news/article/pcngi-kicks-off-cng-supply-pricing-framework-amid-rising-demand/
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Egypt’s Gas Supply Challenge Amid Iran-Israel War
Egypt has activated an emergency gas supply plan as it frantically tries to cope with the impact of the ongoing Iran-Israel conflict, which has already seen piped exports to Egypt cut from Israel’s offshore Leviathan field. The Egyptian Petroleum Ministry said in a Jun. 13 statement that it would halt gas supply to “some industrial activities while raising the consumption of diesel power plants to the maximum available quantity and … to operate some solar plants.” In the meantime, it is seeking to connect new floating import terminals to the grid.
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US Chevron, operator of the 22 trillion cubic foot Leviathan and 11 Tcf Tamar offshore gas fields, confirmed that Tamar flows continue despite the temporary shutdown of Leviathan since Jun. 13. Egypt was receiving around 1 billion cubic feet per day before the shutdown.
Israeli piped gas has acted as a lifeline to Egypt amid its second gas crunch in a decade, accounting for some 15% of Egypt’s overall supply, according to International Energy Agency data. In four years, Israeli exports to Egypt have surged almost 80% from 2.2 billion cubic meters (80.17 Bcf) in 2020 to 10 Bcm last year, Israeli energy ministry data from Israeli consultancy BDO shows.
LNG Import Terminal Stress
Cairo was already planning to avoid a repeat performance of last summer when declining domestic gas output forced it to ration gas use and initiate widespread power cuts. This month it had already secured additional LNG volumes to see it through 2025-26.
However, current events are forcing Egypt to fast-track its plans. The ministry said that at least two of its floating storage and regasification units (FSRUs) needed to be linked to port facilities and are not yet connected to the grid.
Egypt’s gas import hub is at Ain Sukhna, on the Gulf of Suez in the Red Sea. Its first FSRU at the port, Hoegh Galleon, is currently in operation and has been under contract with state Egyptian Natural Gas Holding Co. since June 2024 until February 2026.
Last December, Cairo secured a second FSRU, agreeing to lease the Energos Eskimo unit from US-based New Fortress Energy, which was previously based in Jordan at Aqaba on the Red Sea. Energos Eskimo has since moved to Ain Sukhna, as of early June, shiptracking data from commodity analytics firm Kpler shows.
An additional FSRU, Energos Power, is currently located at Alexandria on Egypt’s Mediterranean coast, having arrived in late May. Egyptian officials have not confirmed if that vessel would later move to Ain Sukhna.
In mid-May, Egypt signed a 10-year charter agreement with Norway’s Hoegh for a new FSRU. The planned Hoegh Gandria will be deployed in the fourth quarter of 2026 to Ain Sukhna and will supply up to 1 Bcf/d of peak LNG regasification capacity. The vessel is currently being converted from an LNG carrier to an FSRU and will replace Hoegh Galleon.
LNG Imports Rising
Egypt is fast regaining its position as a top global LNG importer as in 2015-16 when a similar gas crunch saw it become the darling of portfolio players and trading houses.
However, its long-term ability to suck in global supply and divert cargoes away from Europe or elsewhere is harder to determine given that Egypt retains the option to defer cargoes. The government’s priority over the summer is to ensure a stable electricity supply, and officials could be overbuying.
Egypt has already imported some 2 million tons of LNG (equivalent to 2.72 Bcm of gas) so far this year compared to 2.5 million tons imported for the full-year 2024, according to Kpler data.
In Egypt’s most recent tender to secure supply over 2025-26, Saudi Aramco won around 18-20 firm cargoes and another 12 optional cargoes, Trafigura was awarded 27 cargoes, while BGN and Socar won 11 and eight cargoes, respectively, market sources say. Hartree Partners also appears to have won 20 firm and nine optional cargoes.
One trading source suggested previously that around 130 cargoes were for delivery this year, with a separate market source saying that a total of 142 cargoes were awarded so far for the 2025-26 period. This followed a deal with majors TotalEnergies and Shell earlier this year rumored to be for 60 cargoes in total split between the two firms, although neither company has confirmed details.
The cargoes were priced at a premium of 70¢-75¢ above the gas price at the Dutch TTF hub, with a nine-month deferred payment, according to media reports.
With no sign yet of any domestic supply relief coming from offshore exploration efforts, Egyptian officials say they would be keen to sign government-to-government deals so long as the “offer was feasible.”
https://www.energyintel.com/00000197-799f-d434-a5bf-7bffbcfd0000
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Nigeria: CNG Infrastructure to Reach 30 States Soon
Nigeria’s ambitious shift towards cleaner, more affordable energy is picking up serious pace. The Nigerian Government has announced that Compressed Natural Gas (CNG) infrastructure is now up and running in 20 states, with plans to bring an additional 10 states online within the next six to nine months. This comes as an active gas supply contract, managed by the Gas Aggregation Company Nigeria (GACN), has impressively reached 20 million standard cubic feet per day (scf/d).
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This optimistic update comes from the Presidential CNG Initiative (PCNGI), a key driver in accelerating the nation’s energy transition, particularly within the transportation sector. The initiative has already attracted a substantial $500 million in private investment, signalling strong confidence in its potential.
Speaking at the official launch of the Mobility CNG Supply Framework in Abuja, Michael Oluwagbemi, Managing Director of PCNGI, confirmed the rapid expansion. He acknowledged the growing demand and the visible queues at stations, emphasising the urgent need for increased supply. Oluwagbemi described the new framework as the genesis of a nationwide energy transition, one that masterfully combines private sector participation, regulatory alignment, and commercial innovation.
The groundwork for this pivotal framework was laid back in March 2024, when the Nigerian Midstream and Downstream Petroleum Regulatory Authority (NMDPRA) approved a concessionary pricing structure for automotive CNG. Oluwagbemi explained that this model is crucial for preventing arbitrage and building a robust market, ensuring that gas meant for the transport sector isn’t diverted to more lucrative uses.
The progress is evident: the number of CNG fueling stations has surged from just 20 to over 65, with two new stations recently launched in Ibadan through a partnership with Bovas. Even more impressive, Oluwagbemi revealed that another 27 to 28 stations are expected to be operational in the next four to five weeks, and over 175 stations are currently under construction. Adding to this significant expansion, the Dangote Group has committed to developing an additional 100 stations, which will dramatically broaden national coverage.
The adoption rate is equally impressive. Oluwagbemi noted that the country’s CNG-powered vehicle count has jumped from around 4,000 in 2023 (mostly in Edo state) to over 50,000, excluding trucks. The long queues now seen at Abuja stations for hours on end clearly illustrate the pace of adoption and soaring public interest. The initiative aims to convert between 125,000 and 200,000 additional vehicles by the end of the year, bringing the total to approximately 300,000. The ambitious long-term goal is to reach 1 million CNG-powered vehicles by 2027.
At the same event, Chijioke Uzoho, Managing Director of the Gas Aggregation Company Nigeria (GACN), underscored the broader gas commercialisation and supply strategy that underpins the entire initiative. He detailed that three major gas supply contracts have already been successfully executed and commercialised. Notably, the timelines for these contracts have been drastically compressed from an average of three years to a mere one to six months, reflecting a far more agile and responsive approach to Nigeria’s energy planning.
https://newscentral.africa/nigeria-cng-infrastructure-to-reach-30-states-soon/
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Natural Gas / LNG Utilization / Bio-LNG
Australia: New Australian Gas and LNG Tracker goes live
(IEEFA Australia): The Institute for Energy Economics and Financial Analysis (IEEFA) has launched its Australian Gas and LNG Tracker, an interactive data tool that allows users to analyse Australian liquefied natural gas (LNG) flows into and out of the country.
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The Australian Gas and LNG Tracker allows users to visualise Australia’s LNG infrastructure, demand and capacity, as well as export flows. It uses data compiled from a range of authoritative sources, including Kpler and the Australian Energy Market Operator (AEMO), along with IEEFA’s own analysis. IEEFA gas analysts will update the tracker every six months.
The latest Tracker data shows that most of the gas produced in Australia is utilised by the LNG export sector. It also highlights that in 2024, Australia’s largest LNG export markets were China (33%), Japan (32%), South Korea (15%) and Taiwan (10%), with all other countries accounting for about 9% of exports.
“Japan has historically been Australia’s largest LNG export market, but last year it was surpassed by China, which had dramatic import growth over the past decade,” said Joshua Runciman, Lead Analyst, Australian Gas at IEEFA.
“Australia’s LNG exports to China increased by 8% in 2024 following a 10% increase in 2023 and a 31% decrease in 2022. This compares with 6% and 10% decreases in exports to Japan in 2023 and 2024, respectively. Exports to South Korea and Taiwan increased by 12% and 1% respectively in 2024, partly offset by a 14% fall in supply to other markets,” he added.
Notably, China, Japan, South Korea and Taiwan accounted for 90% of Australia’s total LNG exports, highlighting the sector’s reliance on a few key markets.
Runciman added: “We expect Australia’s contracted LNG volumes to fall considerably over the next 10 years. Without new LNG contracts, Australian LNG exporters will either be exposed to volatile LNG spot prices or reduced utilisation of their export facilities, which could potentially undermine LNG project financial returns.”
IEEFA’s Australian Gas and LNG Tracker also shows:
At a national level, utilisation of Australia’s LNG export facilities has been high, above 90% between 2021 and 2024. This is despite relatively low utilisation at the Gladstone LNG (GLNG) plant and Prelude floating LNG facility off WA.
High utilisation largely reflects strong LNG spot export volumes topping up volumes exported to meet long-term contracts.
Since 2013, the share of Australian LNG exported into spot markets (i.e. uncontracted), has grown considerably, making up 25% of total exports in 2024, contributing to the imbalance between exports and domestic Australian gas supply.
Periods of relatively low utilisation tend to coincide with new LNG projects coming online, and the time required to reach full production.
Generally, Australia’s LNG export facilities have demonstrated consistently high utilisation in non-growth periods, as LNG plant owners seek to recoup investment costs and minimise production costs.
It is likely that Australia’s LNG exports facilities will continue to be highly utilised given the availability of feed gas, which may have implications for domestic gas supply.
Australia’s LNG contract volumes will remain relatively stable to 2030 and then decline to 2040. Crucially, the expiry of these contracts coincides with forecast supply shortages in Australia, which may allow for additional domestic supply if LNG exporters are willing to see lower LNG plant utilisation.
Several new LNG sale and purchase agreements (SPAs) are scheduled to commence in 2026. They include new contracts to be met through Santos’s development of the Barossa gas field to backfill the Darwin LNG facility.
Runciman said: “These are just some of the trends and developments highlighted by our new Australian Gas and LNG Tracker. This tool provides users with a graphic illustration of the current and future outlook for the industry in this country. With regular updates planned, our aim is for it to become a key source of information and insights on LNG in Australia.”
https://ieefa.org/articles/new-australian-gas-and-lng-tracker-goes-live
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Japan: Tokyo Gas LNG Supply Unaffected by Middle East Conflict
Tokyo Gas, the biggest city gas supplier in Japan, doesn’t import LNG from Middle Eastern exporters so its supply of the super-chilled fuel is not being directly impacted by the Israel-Iran conflict, a top executive said on Wednesday. Japan is the world’s second-biggest LNG importer after China.
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Fears have mounted on the energy markets that the escalating hostilities between Israel and Iran could lead to disruption of oil and gas supply in case of direct hits on export infrastructure or a blockade of the vital shipping lane the Strait of Hormuz.
“Since we don’t import LNG from Qatar or UAE, our LNG procurement is not directly affected at this time,” Nobuhiro Sugesawa, senior managing executive officer at Tokyo Gas, told Reuters on the sidelines of an energy conference in Japan.
Still, the Japanese company – whose exports come mostly from Australia, Malaysia, and Russia – is closely monitoring the situation in the Middle East because LNG prices could spike in case of a supply disruption due to the conflict.
Exports from Qatar – the world’s second-largest LNG exporter after the United States – are most at risk of a supply disruption. Around one-fifth of global liquefied natural gas trade transited the Strait of Hormuz in 2024, primarily from Qatar, the U.S. Energy Information Administration says.
The EIA estimates that 84% of the crude oil and condensate and 83% of the liquefied natural gas that moved through the Strait of Hormuz went to Asian markets last year.
Qatar has already asked LNG vessels to exercise caution and wait outside the narrow Strait of Hormuz until they are ready to load LNG, a source familiar with the advisory told Bloomberg earlier this week.
The precaution advises ships to avoid the Gulf until a day before loading, but it is unlikely to delay shipments from Qatar to international markets, according to Bloomberg’s source.
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Germany: First gas flows through Strohm’s pipeline in Germany
First gas is flowing through Strohm’s thermoplastic composite pipe (TCP) system at the Wilhelmshaven 2 terminal in Germany, following the successful commissioning of a second FSRU, Excelsior. This marks the first time gas is being delivered to Europe through this newly-installed subsea pipeline infrastructure. Strohm, the world’s first and leading producer of TCP, has provided more than 11 km of TCP to ECOnnect for the TES Wilhelmshaven Green Gas Terminal in Germany. The corrosion-resistant, lightweight pipeline technology is supporting the terminal’s subsea infrastructure in a high-current, environmentally sensitive zone. In the initial phase, the terminal will be used to import LNG using Strohm’s TCP, with the pipe being repurposed for liquid CO2 transport at a later stage.
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Developed in close collaboration with TES, ENGIE, and DET Deutsche Energy Terminal GmbH, the terminal is a landmark achievement for Europe’s energy infrastructure, combining cutting-edge innovation with environmental stewardship. The terminal’s island jetty is built approximately 1.5 km from the mainland in one of the strongest currents in Europe; and the data, electricity and ultimately the natural gas pipelines are laid in the seabed for ecological reasons and connect-ed to a head station on land.
The gas is being transported to shore using ECOnnect Energy’s IQuay F-Class solution which employs Strohm’s TCP to transfer the gas between the FSRU and the onshore terminal and features Europe’s first use of ultrasound to prevent fouling in an FSRU seawater system. The company provided six 7.4-in. flowlines with a length of approximately 2 km each, qualified for transfer of natural gas and prepared for CO2.
Martin van Onna, Strohm’s CEO, said: “We are proud to support TES and ECOnnect Energy in delivering this critical infrastructure project and supporting Europe’s energy security.
“Our TCP is field proven in the harshest offshore environments in the world. It does not corrode, and it is compatible with CO2, making it perfectly suited for this project. Flexible and delivered in long lengths on reels in a fast-track operation, TCP’s low carbon footprint compared to steel pipe further supports both our clean energy ambitions and those of our clients.”
Magnus Eikens, CCO at ECOnnect Energy, commented: “This milestone marks the culmination of close collaboration and technical innovation across teams and partners. Together, we’ve delivered a first-of-its-kind jettyless solution using Strohm’s TCP, enabling environmentally friendly gas transfer in one of Europe’s most challenging marine environments and laying the groundwork for future energy infrastructure. Strohm’s TCP pipes are non-corrosive and compatible with CO2. This is a solution we’re eager to use again in future projects.”
The FSRU Excelsior is expected to reach up to 4.6 billion m3 each over the next two years, enough to meet the annual heating needs of up to 3.7 million four-person households.
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Canada: LNG Canada produces first liquefied natural gas for export
HOUSTON/CALGARY, June 22 (Reuters) – The Shell-led (SHEL.L), opens new tab LNG Canada facility has produced its first liquefied natural gas for export in Kitimat, British Columbia, a spokesperson for the project confirmed on Sunday. The milestone comes in advance of the facility loading its first LNG export cargo, which LNG Canada said it remains on track to do by the middle of this year.
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The facility is the first large-scale Canadian LNG project to begin production and also the first major LNG facility in North America with direct access to the Pacific coast, significantly reducing sail time to Asian markets when compared to U.S. Gulf coast facilities.
When fully operational it will have a capacity to export 14 million metric tonnes per annum (mtpa), according to company statements.
Two people familiar with the startup of the plant told Reuters it began producing LNG at 4 a.m. local time. The people said the super-chilled gas is being produced from the facility’s Train 1, which has a capacity of 5.6 mtpa.
Only a portion of the processing plant is operating, according to the two people. Train 1 has had difficulties with one of its lines and will only produce at half its capacity until the problem is solved, one of the sources said.
LNG tanker Gaslog Glasgow is approaching LNG Canada’s Kitimat port, according to LSEG ship tracking data. The vessel is expected to arrive on June 29 and will be loaded with LNG, the sources said.
The LNG Canada project is a joint venture between Shell Plc (SHEL.L), opens new tab, Petronas (PGAS.KL), opens new tab, PetroChina (601857.SS), opens new tab, Mitsubishi Corporation (8058.T), opens new tab and Kogas (KVGG.LJ), opens new tab.
Once the facility enters service, Canadian gas exports to the U.S. will likely decline, traders said, as Canadian energy firms will have another outlet for their fuel. For now, the U.S. is the only outlet for Canadian gas.
Canada has two other smaller LNG export facilities also under construction on the Pacific coast. The facilities, Woodfibre LNG and Cedar LNG, are expected to be complete between 2027 and 2028.
Canada exported about 8.6 billion cubic feet per day (bcfd) of gas via pipelines to the U.S. in 2024, up from 8.0 bcfd in 2023 and an average of 7.5 bcfd over the prior five years (2018-2022), according to data from the U.S. Energy Information Administration. That compares with a record 10.4 bcfd in 2002.
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Poland’s Gaz-System to get $593 million loan for country’s floating LNG terminal
WARSAW, June 18 (Reuters) – Polish pipeline operator Gaz-System will receive a 2.2 billion zlotys ($593 million) loan from state bank BGK to finance the onshore segment of Poland’s first floating storage and regasification unit near Gdansk, BGK said on Wednesday.
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The loan, sourced from European Union funds, will finance construction of a 250-km (155-mile) pipeline that will connect the terminal to the core of Poland’s gas network, BGK Deputy President Marta Pustula told reporters. The loan will be repaid over 25 years, Pustula added.
The floating storage and regasification unit will be based in the Bay of Gdansk and is expected to be completed in 2028.
In January, Gaz-System completed the expansion of its LNG terminal in Świnoujście, increasing its regasification capacity to 8.3 billion cubic metres, which corresponds to nearly 50% of the annual gas demand of domestic consumers.
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Global LNG Development
USA: Worley Advances CP2 LNG Project with Venture Global
Worley Limited has announced progress on its reimbursable EPC contract with Venture Global for the CP2 LNG export facility in Louisiana, USA. The project, which had been delayed due to regulatory approvals, is now moving forward with full mobilization and site work for Phase 1 underway. Worley has largely completed engineering for Phase 1 and has begun engineering services for Phase 2. The company expects to start major construction activities by the end of FY26, with first LNG exports targeted for Q3 2027. This project highlights Worley’s commitment to delivering complex energy infrastructure projects that support global energy security.
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The most recent analyst rating on WOR +0.52% stock is a Buy with a A$18.10 price target. To see the full list of analyst forecasts on Worley Limited stock, see the AU:WOR Stock Forecast page.
More about Worley Limited
Worley Limited is a leading global professional services company specializing in energy, chemicals, and resources. Headquartered in Australia and listed on the Australian Securities Exchange, Worley partners with customers to deliver projects and create value over the life of their assets, focusing on transitioning towards more sustainable energy sources while meeting current energy, chemicals, and resource needs.
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US: NextDecade Finalizes EPC Contracts for Rio Grande LNG in Texas
NextDecade Corporation said its subsidiaries have finalized a pricing refresh of the company’s lump-sum, turnkey engineering, procurement and construction (EPC) contract with Bechtel Energy Inc. for the construction of Train 4 and related infrastructure at the Rio Grande LNG facility in Brownsville, Texas.
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NextDecade also entered into a lump-sum, turnkey EPC contract with Bechtel for the construction of Train 5 and related infrastructure at the Rio Grande LNG facility, the company said in a news release.
The company’s subsidiary Rio Grande LNG Train 4 LLC has agreed to pay Bechtel approximately $4.77 billion for the work under the EPC contract for Train 4, with pricing validity extending through September 15, according to the release.
NextDecade said it anticipates that owner’s costs, contingencies, financing fees and interest during construction will total approximately $1.8 billion to $2.0 billion for Train 4 and supporting infrastructure, based on current estimates and expected interest rates.
Further, Rio Grande LNG Train 5 LLC has agreed to pay Bechtel approximately $4.32 billion for the work under the EPC contract for Train 5, with pricing validity also extending through September 15.
For Train 5, NextDecade said it projects that owner’s costs, contingencies, financing fees and interest during construction will total about $1.8 billion to $2.0 billion for Train 5 and supporting infrastructure, based on current estimates and expected interest rates.
With the commercialization of Train 4 complete, the company said it has started the financing process for Train 4 and related infrastructure. Subject to obtaining adequate financing, NextDecade expects to achieve a positive financial investment decision (FID) on Train 4 before the end of the pricing validity period for its EPC contract.
NextDecade recently announced a 20-year liquefied natural gas (LNG) sale and purchase agreement (SPA) with JERA 2.0 for 2 million metric tons per annum (mtpa) for offtake from Train 5. The company said it is working on commercializing an additional 2.5 mtpa under long-term LNG SPAs to support a positive FID on Train 5.
The company said it has started the financing process for Train 5 and related infrastructure and, subject to obtaining appropriate commercial support and financing, is targeting FID before the end of the pricing validity period for its EPC contract.
NextDecade is constructing and developing the Rio Grande LNG facility on the north shore of the Brownsville Ship Channel in south Texas. The site is located on 984 acres of land which has been leased long-term and includes 15,000 feet of frontage on the Brownsville Ship Channel, according to an earlier statement.
The company said it believes the site is “advantaged due to its proximity to abundant natural gas resources in the Permian Basin and Eagle Ford Shale, access to an uncongested waterway for vessel loading, and location in a region that has historically been subject to fewer and less severe weather events relative to other locations along the U.S. Gulf Coast.”
The facility has been permitted by the Federal Energy Regulatory Commission (FERC) and authorized by the U.S. Department of Energy to export of up to 27 mtpa of LNG. Phase 1 of the facility is under construction, and the company said it is developing and beginning the permitting process for Trains 6 through 8.
The company is developing and beginning the permitting process for additional liquefaction capacity at the Rio Grande LNG Facility site beyond Trains 1 through 5. Trains 6 through 8 are wholly owned by NextDecade and are cumulatively expected to increase its total liquefaction capacity by approximately 18 MTPA once constructed and placed into operation, according to the statement.
Train 6 is being developed inside the existing levee at the Rio Grande LNG facility site and adjacent to Trains 1 through 5, the company said, adding that it expects to pre-file an application with FERC for Train 6 within the year and a full application with FERC in early 2026. Trains 7 and 8 are being developed on the site outside of the existing levee, the company noted.
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Malaysia : Woodside and PETRONAS eye long-term LNG supply
Woodside Energy and PETRONAS, through its subsidiary PETRONAS LNG Ltd (PLL), have signed a non-binding heads of agreement (HOA) for the supply of 1 million tpy of LNG to Malaysia from 2028 for a period of 15 years. The LNG would be supplied from Woodside’s global portfolio and may include the recently approved Louisiana LNG project in the US.
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The HOA reflects the shared ambition of both companies to formally commit to deepening co-operation across the LNG value chain, building a relationship of mutual trust, benefit, and success.
Woodside Executive Vice President & Chief Commercial Officer, Mark Abbotsford, welcomed the HOA with PETRONAS, recognised globally as one of Asia’s most respected energy companies.
“This agreement marks the beginning of a new era of collaboration between Woodside and PETRONAS and is an important step towards what would be our first long-term LNG sales to Malaysia. It reflects the value global buyers see in Woodside’s Louisiana LNG project and our reputation as a safe and a reliable supplier of energy to Asia.”
The agreement is expected to support PETRONAS’ efforts to ensure secure, flexible LNG supply to meet growing demand in Peninsular Malaysia and the broader Asia Pacific region.
“We are pleased to launch our new collaboration with Woodside, a leading supplier of LNG to Asia. We hope this will be the start of cooperation between PETRONAS and Woodside on future opportunities to support energy security and sustainability across the region,” said Shamsairi Ibrahim, Vice President of LNG Marketing & Trading, PETRONAS.
The agreement was exchanged at the Energy Asia 2025 conference in Kuala Lumpur in the presence of Woodside CEO, Meg O’Neill, and PETRONAS Executive Vice President & CEO Gas & Maritime Business, Datuk Adif Zulkifli.
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Malaysia: Petronas Signs Up as Buyer for Commonwealth LNG, Louisiana LNG
Malaysia’s national oil and gas company has committed to purchasing one million metric tons per annum (MMtpa) for 20 years from Kimmeridge Energy Management Co. LLC’s planned Commonwealth LNG project in Louisiana. Petroliam Nasional Bhd. (Petronas) also entered into a non-binding heads of agreement with Woodside Energy Group Ltd. for the purchase of one MMtpa from the Australian company’s global portfolio, including the under-construction Louisiana LNG, for 15 years. Delivery is set to start 2028.
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“Collaborating with Commonwealth LNG will expand our supply node and strengthen our presence in the global LNG market”, Shamsairi M Ibrahim, Petronas vice president for LNG marketing and trading, said in an online statement.
“Commonwealth LNG currently has 4 MTPA [million metric tons per annum] of offtake under long-term agreement, with line of sight toward finalizing its commercial book ahead of a targeted final investment decision in Q3 2025 and anticipated first LNG production in 2029”, Commonwealth said separately.
In February the United States Department of Energy (DOE) granted the project a conditional permit to export to countries with no free trade agreement (FTA) with the U.S.
To rise along the Calcasieu River on the Gulf Coast near Cameron, the project has a planned capacity of 9.5 MMtpa, equivalent to about 441.4 billion cubic feet per year of natural gas according to Commonwealth.
Meanwhile Woodside’s Louisiana LNG reached an FID last April. Louisiana LNG holds a DOE authorization to export a cumulative 1.42 trillion cubic feet a year of natural gas equivalent, or 27.6 MMtpa of LNG according to Woodside, to both FTA and non-FTA countries.
The FID was for phase 1, which involves three liquefaction trains with a combined capacity of 16.5 MMtpa.
The Woodside-Petronas agreement “is expected to support PETRONAS’ efforts to ensure secure, flexible LNG supply to meet growing demand in Peninsular Malaysia and the broader Asia-Pacific region”, Petronas said in a separate press release.
Woodside executive vice president and chief commercial officer Mark Abbotsford said, “This agreement marks the beginning of a new era of collaboration between Woodside and PETRONAS, and is an important step towards what would be our first long-term LNG sales to Malaysia”.
Petronas signed the agreements at the Energy Asia forum in Kuala Lumpur, during which it also signed a memorandum of understanding (MOU) with Korea Gas Corp.
“The MoU not only reinforces PETRONAS’ commitment as a long-term LNG supplier to KOGAS, but also in advancing cleaner energy solutions through opportunities in carbon capture and storage, renewable energy and hydrogen development to address pressing climate challenges”, Petronas said in another statement.
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LNG as a Marine Fuel/Shipping
Bangladesh: Govt eyes two more spot LNG cargoes to boost industrial gas supply
The government is planning to import two more spot liquefied natural gas (LNG) cargoes in July to increase gas supply to industries and other commercial users-excluding power plants-amid efforts to stabilise energy supply for production. State-run Rupantarita Prakritik Gas Company Ltd (RPGCL) has floated a couple of tenders to purchase the two spot LNG cargoes for delivery windows of July 15-16 and July 17-18, a senior RPGCL official told The Financial Express on Saturday.
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Each of the spot cargoes will carry around 3.36 million British thermal units (MMBtu) of LNG.
The successful bidder will deliver the LNG cargo at Moheshkhali island in the Bay of Bengal, with options to offload at either of the country’s two floating storage and re-gasification units (FSRUs) located there.
If these tenders are successful, the total number of spot LNG cargoes purchased in early July will reach five. The country may also seek to buy more spot LNG shipments in late July, the official said.
Bangladesh has already purchased three spot LNG cargoes for delivery in June.
RPGCL, a wholly owned subsidiary of state-run Petrobangla, oversees LNG trading for Bangladesh.
The country recently awarded its latest spot LNG cargo tender to POSCO International Corporation of South Korea for the July 11-12 delivery window at a price of $12.68 per MMBtu.
Officials said the interim government has opted to ramp up spot LNG imports, targeting six additional cargoes to boost supply of re-gasified natural gas (R-LNG) for industrial use.
Gas supply to industries has already increased since early June, following the arrival of additional spot cargoes, according to a senior Petrobangla official.
The government aims to augment gas supply to industries by around 250 million cubic feet per day (mmcfd), by both increasing spot LNG imports and diverting supply from gas-fired power plants.
According to data from the Ministry of Power, Energy and Mineral Resources (MPEMR), average gas supply to industries during the first four months of 2025 (until April) stood at 997 mmcfd, compared to 823 mmcfd during the same period a year earlier.
However, this expanded supply comes at a cost. The MPEMR estimates that the government will need to provide subsidies worth around Tk 35 per cubic metre for the additional LNG meant for industries. While the import cost of LNG is about Tk 65 per cubic metre, it is being sold at Tk 30 to new industries and Tk 31.50 for captive power plants.
To facilitate this diversion, Petrobangla plans to reduce gas allocations to gas-fired power plants to 1,050 mmcfd from the current 1,200 mmcfd.
Bangladesh currently imports LNG under long-term contracts from QatarEnergy and OQ Trading International, and supplements this with spot purchases. The two operational FSRUs at Moheshkhali have a combined re-gasification capacity of 1.1 billion cubic feet per day (Bcfd).
The country continues to face an acute energy crisis, exacerbated by declining domestic natural gas production.
As a result, gas rationing remains in place across power plants, industrial units, and other major consumers to manage mounting demand with limited supply.
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Qatar: QatarEnergy LNG remains at ‘forefront’ of rising global vessel capacities: IGU
QatarEnergy LNG remains at the “forefront” of rising vessel capacities (globally), ordering 24 new 271,000 cm (QC-max) vessels from China for delivery between 2028 and 2031, according to the International Gas Union (IGU). Globally, some 337 LNG vessels were under construction as of end-2024, IGU said in its ‘2025 LNG World Report’. Of the 64 newbuilds delivered in 2024, all have a capacity of between 174,000 and 200,000 cm.
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Vessels of this size remain within the upper limit of the Panama Canal’s capacity following its expansion in 2016. They also benefit from economies of scale, particularly as additional LNG capacity is developed in the US Gulf Coast (USGC) for long-haul delivery to Asia, IGU noted.
Moving forward, 200,000 cm vessels, or larger, could find favour due to their economies of scale for long-haul voyages, especially for long-term charters, if some flexibility is maintained (Panama Canal, terminal compatibility, etc).
The current orderbook for such ships comprises 37 vessels, each with a capacity of either 200,000 cm or 271,000 cm, scheduled for delivery between 2025 and 2031.
The global LNG orderbook had 337 newbuild vessels under construction at the end of 2024, equivalent to 45.4% of the current active fleet, with deliveries stretching into 2031.
This illustrates shipowners’ expectations that LNG trade will continue to grow in line with scheduled increases in liquefaction capacity, particularly from the US and Qatar, and fleet renewal demand from oncoming retirements of older, more inefficient vessels.
An expected 97 carriers are scheduled to be delivered in 2025. The orderbook includes 21 icebreaker-class vessels for the Arctic LNG 2 project in Russia.
These vessels are highly innovative and require high capital expenditure (CAPEX) which grant them the capability to traverse the Arctic region.
Due to the Russia-Ukraine conflict, these vessels have faced a risk of delayed deliveries or cancellations due to international sanctions on Russia that have complicated equipment delivery and payments.
IGU also noted the current global LNG fleet is relatively young, considering the oldest operational LNG carrier was constructed in 1977.
As of end-2024, some 84.9% of the fleet is under 20 years of age, consistent with the rapid growth of liquefaction capacity since the turn of the century.
Additionally, newer vessels are larger and more efficient, with superior project economics and emissions performance over their operational lifetime.
In total, some 7,065 LNG trade voyages were undertaken in 2024, a 0.9% increase from the 7,004 seen in 2023, IGU said.
This is in line with minimal growth in LNG production. While Asia remains the dominant demand centre with 4,609 trade voyages, European trade voyages declined by 13% to 1,929 in 2024 due to weak market fundamentals through most of 2024, with Europe importing just over 100mn tonnes.
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Japan: Petronas to deliver its first LNG Canada cargo to Japan’s Toho Gas in July
TOKYO, June 20 (Reuters) – An executive from Malaysian state energy firm Petroliam Nasional said on Friday that the first cargo from its portion of supply from the LNG Canada project will be delivered to its customer, Japanese city gas provider Toho Gas, in July.
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Speaking at an energy conference in Tokyo, Shamsairi Ibrahim, Petronas’ vice president of LNG marketing and trading, also said that the company’s third floating LNG project is set to commence production in 2027.
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Technological Development for Cleaner and Greener Environment Hydrogen & Bio-Methane
Low-cost green hydrogen production possible with Korean scientists’ new breakthrough
Hydrogen is a clean energy source that has zero carbon content and stores much more energy by weight than gasoline. Scientists have achieved a new breakthrough that can help produce cheaper green hydrogen. A research team led by researchers from Hanyang University ERICA campus in South Korea developed cobalt phosphides-based nanomaterials by adjusting boron doping and phosphorus content using metal-organic frameworks. These materials have better performance and lower cost than conventional electrocatalysts, making them suitable for large-scale hydrogen production.
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Professor Seunghyun Lee from Hanyang University stated that their findings offer a blueprint for designing and synthesizing next-generation high-efficiency catalysts that can drastically reduce hydrogen production costs.
“This is an important step towards making large-scale green hydrogen production a reality, which will ultimately help in reducing global carbon emissions and mitigating climate change.”
Method can reduce hydrogen production costs
The researchers used an innovative strategy to create these materials, using cobalt (Co) based metal-organic frameworks (MOFs).
“MOFs are excellent precursors for designing and synthesizing nanomaterials with the required composition and structures,” said Dun Chan Cha, from the Hanyang University.
Researchers grew Co-MOFs on nickel foam (NF). They then subjected this material to a post-synthesis modification (PSM) reaction with sodium borohydride (NaBH4), resulting in the integration of B. This was followed up by a phosphorization process using different amounts of sodium hypophosphite (NaH2PO2), resulting in the formation of three different samples of B-doped cobalt phosphide nanosheets (B-CoP@NC/NF), according to researchers.
Low-cost hydrogen production
Experiments revealed that all three samples had a large surface area and a mesoporous structure, key features that improve electrocatalytic activity. As a result, all three samples exhibited excellent OER and HER performance, with the sample made using 0.5 grams of NaH2PO2 (B-CoP0.5@NC/NF) demonstrating the best results. Interestingly, this sample exhibited overpotentials of 248 and 95 mV for OER and HER, respectively, much lower than previously reported electrocatalysts, according to a press release.
Researchers revealed that density functional theory (DFT) calculations supported these findings and clarified the role of B-doping and adjusting P content. Specifically, B-doping and optimal P content led to effective interaction with reaction intermediates, leading to exceptional electrocatalytic performance.
Previous experiments have focused on electrochemical water-splitting, a process that uses electricity to break down water into hydrogen and oxygen. In combination with renewable energy sources, this method offers a sustainable way to produce hydrogen and can contribute to the reduction of greenhouse gases.
However, large-scale production of hydrogen using this method is currently unfeasible due to the need for catalysts made from expensive rare earth metals.
Therefore, researchers are exploring more affordable electrocatalysts, such as those made from diverse transition metals and compounds.
The low-cost production of clean hydrogen can help reduce greenhouse gas emissions and combat climate change, helping the globe that urgently needs clean and renewable energy sources.
https://interestingengineering.com/energy/low-cost-green-hydrogen-production-possible
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GKN Pushes Cryogenic Effort After Hydrogen Program Rationalization
PARIS—GKN Aerospace is focusing on cryogenic cooling system and electrical network technology for future hydrogen-fueled aircraft under the Airbus-led ICEFlight (Innovative Cryogenic Electric Flight) research project, having recently elected to draw down its broader hydrogen-related development efforts covering motors, power-generation systems and liquid hydrogen storage.
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The company’s contribution to ICEFlight, an initiative led by Airbus’ UpNext innovation arm and the company’s Tech Hub in the Netherlands, comes as part of GKN’s strategic decision to concentrate on power distribution, cooling and superconductivity solutions, where GKN says it is best placed to leverage commercial advantage.
Announcing its move to double down on cryogenic systems at the Paris Air Show, GKN says the ICEFlight initiative also aims to establish testing facilities in the Netherlands, led by the Royal NLR, to ensure the reliability and validate the performance of the new cryogenic systems. “These facilities will help to position the Netherlands as a leader in cryogenic technology, particularly in the development and testing of cooling systems that enable superconductivity and hyperconductivity in aviation, with opportunities to spin off to other sectors,” the company says.
GKN opted to rationalize its hydrogen-related technology plans in the wake of Airbus’ February 2025 decision to extend the development timescale for a hydrogen-powered airliner. GKN has since ended its involvement in the Marshall Aerospace-led HyFIVE hydrogen fuel system consortium; opted to conclude its own H2Gear hydrogen-electric propulsion project at the end of its initial five-year term; and to drop some parts of the GKN-led H2FlyGHT project, originally announced in 2024.
As well as the ICEFlight technology work, GKN’s revised H2 portfolio now includes the final 1-megawatt motor demonstrator under the H2Gear program and a streamlined version of the follow-on H2FlyGHT program which was launched in 2024 targeting the development of a 2-megawatt cryogenic hydrogen-electric propulsion system.
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50% Hydrogen Blend Testing Successfully Completed at Georgia Power’s Plant McDonough-Atkinson
ATLANTA–(BUSINESS WIRE)–Georgia Power and Mitsubishi Power have successfully completed a second trial blending hydrogen and natural gas fuels at both partial and full load on an M501GAC natural gas turbine at Georgia Power’s Plant McDonough-Atkinson in Smyrna, Georgia. The demonstration project is the first to validate 50%* hydrogen fuel blending on an advanced class gas turbine, and the largest test of this kind in the world to date, with the 50% blend providing an approximately 22% reduction in CO2 emissions compared to 100% natural gas. Several tests were conducted prior to the 50% blend demonstration including multiple blend percentages that ranged from 5% to 50%, and testing occurred across several weeks in May and June.
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Last year, the existing gas turbine was converted from steam-cooled to air-cooled, which includes J series combustion technology with proven high hydrogen co-firing capability. The conversion provides the benefits of faster startup times, increased turn down capability and decreased maintenance expenses, while also supporting the ability for this successful landmark hydrogen blend testing.
Georgia Power, the largest electric subsidiary of Southern Company, collaborated with Mitsubishi Power for the landmark testing as part of a continued commitment to new research and development (R&D) to advance reliable and affordable energy for customers, while reducing carbon emissions across its generation fleet. In fact, Georgia Power has reduced its carbon emissions by more than 60% since 2007. This test follows the first 20% by volume hydrogen blending test at Plant McDonough-Atkinson completed in 2022.
Learn more about Georgia Power’s landmark hydrogen blending project.
The Plant McDonough-Atkinson facility, located less than ten miles from downtown Atlanta, has served electric customers for more than 80 years and was fully converted to natural gas in 2012 and expanded to power up to 1.7 million homes. It currently operates with six advanced, large-capacity M501G and M501GAC series gas turbines, which deliver high performance and high efficiency, as well as three steam turbines running in three blocks of 2-on-1 combined-cycle configuration and two gas/oil fueled combustion turbines.
“Natural gas serves a critical role in our generation mix, providing flexibility, baseload power and quick response to customer demand, and will continue to be an important fuel as we plan to meet the energy needs of a growing Georgia through a diverse portfolio of generation resources,” said Rick Anderson, senior vice president and senior production officer for Georgia Power. “At Georgia Power, innovative testing such as this is just one way we help ensure we can deliver reliable and affordable energy for customers for decades into the future, and reduce our overall emissions. Investments we’re making in our fleet and power grid today will benefit future generations, and I’m very proud of the team at Plant McDonough-Atkinson and Mitsubishi Power for their dedication to this project and safely completing this test.”
Mitsubishi Power completed the hydrogen blending on one M501GAC gas turbine unit, with an approximate one-on-one output of 283 MW. Mitsubishi Power provided full turnkey service for this project including engineering, planning, hydrogen blending hardware, controls, commissioning and risk management. Mitsubishi Power partnered with Certarus to source and manage the hydrogen supply and logistics.
“It has been a privilege to partner with Georgia Power on this landmark project,” said Mark Bissonnette, executive vice president and chief operating officer of Power Generation at Mitsubishi Power Americas. “Building on the success of our earlier tests, we have achieved a 50% hydrogen blend in an advanced-class gas turbine, showcasing the capabilities of our state-of-the-art technology. This is a significant milestone for both companies to help Georgia Power reduce carbon emissions across its generation fleet.”
Southern Company’s industry-leading R&D organization served as technical consultants on the project. The team is engaged in research focused on low-carbon hydrogen power generation, production, delivery, transportation, infrastructure and energy storage.
Natural gas currently provides 40 percent of Georgia Power’s annual energy generation and has long been a bedrock fuel for the company. Georgia Power continues to work with the Georgia Public Service Commission (PSC) to ensure it can reliably and economically meet the energy needs of a growing Georgia through the longstanding Integrated Resource Plan (IRP) process. The company is currently developing three new Mitsubishi Power simple cycle combustion turbine resources, capable of utilizing hydrogen, at Plant Yates in Coweta County as approved by the Georgia PSC in the 2023 Integrated Resource Plan Update (IRP).
In addition to new natural gas generation, Georgia Power is also investing in existing power plants to better serve Georgia. Notably, the company has proposed upgrades to ten natural gas turbines – both combined cycle and simple cycle – at Plant McIntosh in the 2025 IRP. These enhancements are expected to add an additional 268-megawatts of capacity, helping to meet the projected energy demands from existing infrastructure. Combined with new renewable generation resources such as solar, these initiatives highlight Georgia Power’s dedication to reducing carbon emissions while fostering a resilient and reliable energy future and meeting the increasing energy needs of the state.
To learn more about how Georgia Power is meeting the needs of customers through a diverse, balanced energy portfolio, and the IRP process, visit www.GeorgiaPower.com.
* The ratio of hydrogen content indicates volume ratio.
About Georgia Power
Georgia Power is the largest electric subsidiary of Southern Company (NYSE: SO), America’s premier energy company. Value, Reliability, Customer Service and Stewardship are the cornerstones of the company’s promise to 2.8 million customers in all but four of Georgia’s 159 counties. Committed to delivering clean, safe, reliable and affordable energy, Georgia Power maintains a diverse, innovative generation mix that includes nuclear, coal and natural gas, as well as renewables such as solar, hydroelectric and wind. Georgia Power offers rates below the national average, focuses on delivering world-class service to its customers every day and the company is recognized by J.D. Power as an industry leader in customer satisfaction. For more information, visit www.GeorgiaPower.com and connect with the company on Facebook (Facebook.com/GeorgiaPower), X (X.com/GeorgiaPower) and Instagram (Instagram.com/ga_power).
About Mitsubishi Power
Mitsubishi Power Americas, Inc. (Mitsubishi Power) headquartered in Lake Mary, Florida, employs more than 3,000 power generation, energy storage, and digital solutions experts and professionals. Our employees are focused on empowering customers to affordably and reliably combat climate change while also advancing human prosperity throughout North, Central, and South America. Mitsubishi Power’s power generation solutions include gas, steam, and aero-derivative turbines; power trains and power islands; geothermal systems; PV solar project development; environmental controls; and services. Energy storage solutions include green hydrogen, battery energy storage systems, and services. Mitsubishi Power also offers intelligent solutions that use artificial intelligence to enable autonomous operation of power plants. Mitsubishi Power is a power solutions brand of Mitsubishi Heavy Industries, Ltd. (MHI). Headquartered in Tokyo, Japan, MHI is one of the world’s leading heavy machinery manufacturers with engineering and manufacturing businesses spanning energy, infrastructure, transport, aerospace, and defense. For more information, visit the Mitsubishi Power Americas website and follow us on LinkedIn.
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ABO Energy Celebrates Inauguration of the First Hydrogen Project
Wiesbaden — After several years of planning and around 13 months of construction, ABO Energy has now successfully completed the first hydrogen project in the company’s history. The pilot project in Hünsfeld-Michelsrombach in Hesse consists of a wind turbine, a 5 MW electrolysis plant (hydrogen production) and a hydrogen filling station with trailer filling plant. The plant is to produce up to 450 tons of hydrogen per year as planned.
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“The project marks a milestone for our company, but also for the energy transition in Germany,” says Dr. Jochen Ahn, one of the founders of ABO Energy. “The plant is unique in this form in Germany and one of the first projects that produces certified green hydrogen. Only green hydrogen helps us to sustainably rebuild the energy system and achieve our goal of achieving greenhouse gas neutrality by 2045.” It is correspondingly important that the new federal government is pushing the accelerator on the subject of hydrogen. Jochen Ahn thanked the many partners from business, associations and regional and local politics: “Without people who lead the way for their conviction every day, the project would not have been possible.”
One of these people is Benjamin Tschesnok, mayor of the city of Hünfeld. At the opening ceremony, he said: “When ABO Energy first contacted us four years ago, we wanted to be part of this flagship project. We see ourselves as an innovative city that is driving the energy transition forward. This project makes an important regional contribution to this.”
Internally, it was primarily the department of future energies that ABO Energy founded twelve years ago. The team carried out initial analyses and feasibility studies and continued to develop the project idea in the HyWheels hydrogen cluster. ABO Energy was recently awarded the BSFZ seal of the Federal Ministry of Education and Research for its commitment to the hydrogen sector. A decisive success factor in the planning and implementation was the partner company ABO Kraft & Wärme, which will also take over the operation of the petrol station.
The project was funded by the Federal Ministry of Digital and Transport (BMDV) with a total of twelve million euros as part of the National Innovation Programme for Hydrogen and Fuel Cell Technology (NIP). Funds from this measure are also provided within the framework of the German Structure and Resilience Plan (DARP) in the NextGenerationEU programme within the framework of the German Development and Resilience Plan (DARP). The funding guideline is coordinated by NOW GmbH and implemented by Project Management Jülich (PtJ).
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