NGS’ NG/LNG SNAPSHOT March 1-15, 2026
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City Gas Distribution & Auto LPG
26,500 households get piped gas connections in capital
THINK Gas, the agency which is implementing the city gas project in Thiruvananthapuram, provided gas connections to 26,500 households as well as 25 commercial establishment connections in the capital district so far, where it has laid pipeline to the length of 650 km as part of the project, according to the agency. Work is also progressing to set up storage facilities and distribution infrastructure in neighbouring Kollam, where a new LCNG (Liquid to Compressed Natural Gas) plant is to be set up in Chavara to meet natural gas demand.
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The city gas network will be expanded in areas of Mangalapuram and Vilapil in Thiruvananthapuram and Panmana panchayat in the Kollam district, according to the agency. The agency will also install advanced smart meters across the piped natural gas network for accurate billing and real-time usage and prepaid billing instead of mechanical meters.
Plans are also afoot to set up new Compressed Natural Gas (CNG) stations and additional Piped Natural Gas (PNG) connections. An additional 6,000 PNG connections are planned in the Thiruvananthapuram district in 2026. Five CNG stations are planned in Thiruvananthapuram and 2 stations in Kollam. In Alappuzha, a total of 30,000 household connections and 27 commercial establishment connections have been provided so far, while a total length of 900 km of pipeline has been laid as part of the project.
In Alappuzha, the agency will expand its network to more areas of Alappuzha Town and Aryad Panchayat along with Mararikulam, where it will provide an additional 6,000 PNG connections in 2026, apart from introducing advanced smart meters instead of mechanical meters. Three CNG stations are also planned in Alappuzha this year, said the agency.
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India’s CNG network expands to over 8,600 stations in 2026, says Puri
He said that the rapid expansion of the network has enabled millions of daily journeys using CNG vehicles while supporting the country’s transition towards cleaner mobility
Petroleum and Natural Gas Minister Hardeep Singh Puri on Tuesday said India’s compressed natural gas (CNG) infrastructure has expanded significantly over the past decade, with the number of CNG stations increasing from 738 in 2014 to more than 8,600 in 2026.
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Sharing the update on LinkedIn, the minister said that the rapid expansion of the network has enabled millions of daily journeys using CNG-powered vehicles while supporting the country’s transition towards cleaner mobility.
Puri noted that CNG vehicles emit substantially lower pollutants compared to conventional fuels. According to him, such vehicles can emit up to 46 times lower particulate matter and produce near-zero sulphur emissions, helping reduce urban air pollution.
The government has been pushing the development of CNG infrastructure as part of a broader strategy to diversify India’s transportation energy mix and lower emissions from road transport.
India is also planning a further expansion of the network, with a target to reach 18,336 CNG stations by 2030. The rollout includes the development of corridor-based infrastructure to ensure wider availability of CNG across highways and urban centres.
The minister said the expansion aligns with the clean energy and mobility vision promoted under the leadership of Narendra Modi, aimed at building nationwide infrastructure to support low-emission transportation solutions.
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Not just Delhi, Not just Gujarat: These 4 companies are building India’s new gas highway
As India pivots toward a gas-based economy, city gas distribution (CGD) leaders like Adani Total Gas and IGL are expanding into new geographical areas. Discover how infrastructure rollouts in smaller cities and industrial pockets are creating a new volume runway for investors in 2026.
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For many years, city gas companies focused mainly on large metro markets. They built pipelines there. Volumes became stable. Now the situation is changing.
Growth is coming from smaller cities and new industrial pockets. More vehicles are shifting to gas. Local industries are also looking at cleaner fuel options. To keep growing, these companies need to move into these newer areas rather than depend only on old markets.
There is also a broader push behind this shift. Pollution concerns are rising in many urban centres. Governments want cleaner transport and industrial fuel. Gas infrastructure has to reach places where it was earlier absent. Expansion is not just a growth choice now. It is becoming a necessity to stay relevant and competitive.
The Growth Runway: Why New Geographical Areas are the Next Volume Drivers
This is also a practical time to look at such businesses. Many new geographical areas are still in the rollout stage. Pipelines are being laid. CNG stations are being added. When a network reaches a certain scale, volumes usually pick up faster. Growth from a low base can look strong for a few years. That creates better earnings visibility compared to mature markets.
The four stocks selected here reflect that expansion trend. They are actively building in multiple areas. A clear part of their capital spending is going into new districts. Their growth depends on adding territory, not just tweaking prices in old markets. Some other players are largely focused on strengthening existing cities. That is why these four fit the expansion theme better.
#1 Adani Total Gas: Scaling the EV-Gas Hybrid Model
Adani Total Gas is engaged in the city gas distribution (CGD) business and supplies natural gas to domestic, commercial, industrial and vehicle users.
Adani Total Gas is expanding its CGD footprint across India. The company operates in 34 Geographical Areas covering 95 districts. Including its joint venture with Indian Oil, the combined reach extends to 53 geographical areas across 125 districts. The focus remains on building infrastructure in newer territories to drive long-term volume growth.
In the December quarter, the company added 18 Compressed Natural Gas (CNG) stations, taking the total to 680. The steel pipeline network expanded to 14,862 inch-kilometres, while the Medium Density Polyethylene (MDPE) pipeline crossed 8,100 kilometres. Domestic Piped Natural Gas (PNG) connections increased by nearly 35,000 during the quarter, taking the total household base to 10.5 lakh homes.
CNG volumes grew 17% year-on-year (YoY), while PNG volumes rose 3%. Around 45,000 new vehicles were added quarter-on-quarter within the company’s geographical areas. Revenue from operations increased 17% YoY to Rs 1,631 crore. Profit After Tax (PAT) grew 10% to Rs 157 crore.
Regulatory changes during the quarter supported cost efficiency. The Petroleum and Natural Gas Regulatory Board (PNGRB) introduced a simplified two-zone transmission tariff. Supplies of PNG and CNG now attract Zone 1 tariff irrespective of distance. The company passed part of the benefit to consumers through calibrated price reductions.
The company is also scaling adjacent businesses. Through Adani TotalEnergies E-mobility (ATEL), it operates nearly 5,000 electric vehicle (EV) charging points across 26 states and Union Territories. A large part of the company’s gas supply comes from domestic fields.
This includes Administered Price Mechanism (APM) gas, New Well Gas and High Pressure High Temperature gas. Together, these sources make up roughly two-thirds of the total supply mix. The rest depends on market-linked purchases.As more pipelines are laid and CNG stations come up in new districts, the company is gradually widening its presence. The real impact of this expansion will be seen as volumes build up in these newer areas over time. Execution across newer geographical areas will remain key to sustaining momentum.
In the past year, share price of Adani Total Gas is down 11.9%.
#2 Indraprastha Gas: Diversifying Beyond the Delhi-NCR Core
Incorporated in the year 1998, Indraprastha Gas (IGL) is in the business of city gas distribution in the National Capital Territory of Delhi.
Indraprastha Gas (IGL) is accelerating expansion beyond its core Delhi market. The company now operates across 12 Geographical Areas in four states. Management indicated that nearly 57% of incremental volumes are coming from outside Delhi and the National Capital Region, signaling a gradual shift in growth drivers.
Infrastructure additions continue to support this strategy. The steel pipeline network has crossed 2,500 kilometres, while the MDPE network stands at about 29,200 kilometres. IGL has added 45 CNG stations during the year, taking the total base to over 970 stations. Newer geographical areas are growing between 17% to 18%, compared with 8 to 10% in the mature Delhi and National Capital Region (NCR) markets.
In the December quarter, total sales volumes rose 3% YoY to 867 million standard cubic metres. CNG volumes increased 3%, while PNG volumes grew 5%. Excluding the impact of fleet transition by Delhi Transport Corporation, underlying CNG growth was over 10%.
Revenue for the quarter increased 8% YoY to Rs 4,465 crore. PAT grew 25% to Rs 358 crore. The company expects margin improvement as transmission tariff benefits and tax changes reflect fully in upcoming quarters.
With steady expansion in new geographical areas and planned addition of around one million standard cubic metres per day annually, IGL is positioning growth outside its legacy markets. Execution in emerging districts and sustained demand in the CNG segment will be central to maintaining momentum.
In the past year, share price of Indraprastha Gas is down 13%.
#3 Gujarat Gas: Navigating the ‘Morbi’ Volatility
Gujarat Gas (GGL) is a government company. Formerly known as GSPC Distribution Networks (GDNL), GGL is engaged in the business of Natural gas in India. The business of natural gas involves distribution of gas from sources of supply to centres of demand and to end customers.
GGL continues to expand its footprint across multiple states. The company operates in 27 geographical areas spread across six states and one Union Territory (UT). Its pipeline network now spans over 44,550 kilometres, serving nearly 23.8 lakh domestic customers, over 4,400 industrial users and close to 16,000 commercial establishments. Its strategy still revolves around expansion in both established and developing fields.
Additionally, the organization is expanding its CNG network. In the next two to three years, it hopes to operate 1,000 CNG stations, up from the present 833. CNG volumes rose 11% YoY in the December quarter, with a more notable 22% increase in regions outside of Gujarat, indicating traction in more recent geographies.
Despite the holiday disruptions, non-Morbi industrial volumes increased 7% YoY because of pipeline connectivity in developing clusters including Ahmedabad rural, Dahej, Kutch, and Thane.
The company has been investing in steel pipeline infrastructure to unlock demand in these regions. During the first nine months of the year, it invested about Rs 408 crore in infrastructure and plans a full-year capital expenditure of Rs 650 to Rs 700 crore.
Financial performance showed mixed trends. Revenue for the quarter stood at Rs 3,865 crore, compared to Rs 4,333 crore in the same period last year. PAT increased to Rs 266 crore marking a YoY growth of about 20%.
Gas sourcing remains a key variable. Allocation shortfalls in Administered Price Mechanism gas have been offset through long-term and spot sourcing. Management expects global liquefied natural gas supply additions over the next few years to support pricing stability.
With infrastructure largely in place across new industrial belts and continued CNG station additions, Gujarat Gas is positioning itself for volume recovery in industrial clusters and steady growth in transport fuel demand. Execution in newer Geographical Areas and pricing dynamics in key markets such as Morbi will remain crucial to sustaining expansion momentum.
In the past year, share price of Gujarat Gas is up 7.1%.
#4 IRM Energy: The Early-Cycle Expansion Play
Incorporated in 2015, IRM Energy is in the business of selling and distributing natural gas.
IRM Energy is advancing its footprint across multiple emerging markets under the CGD framework. The company is authorised to operate in nine geographical areas across four states, namely Gujarat, Punjab, Rajasthan and Tamil Nadu. Most of these areas remain in the development phase, with infrastructure rollout forming the backbone of its growth strategy.
Pipeline expansion continued during the year. The steel pipeline network increased to 1,042 kilometres, while the MDPE network reached 3,780 kilometres. The number of CNG stations rose to 122 from 96 a year earlier, reflecting active build-out across licensed territories. Management indicated that volumes in newer GAs are gradually ramping up as infrastructure scales.
Operational growth remained steady despite being at an early stage of network maturity. Total sales volumes for the quarter stood at 206 million standard cubic metres, compared to 200 million standard cubic metres in the same period last year. CNG volumes rose 11% YoY, supported by station additions and vehicle conversions.
Revenue from operations increased 9% YoY to Rs 292 crore for the quarter. PAT stood at Rs 13.9 crore compared with Rs 17 crore in the corresponding quarter last year. Management noted that margin stability will depend on gas sourcing mix and industrial demand recovery.
Capital expenditure during the first nine months was Rs 173 crore, largely directed towards pipeline and station infrastructure. The company continues to focus on expanding penetration in newly awarded Geographical Areas rather than mature markets.
With infrastructure still being built across several districts, IRM Energy remains in an early expansion cycle. Volume scale-up in newer territories will be critical for margin recovery and earnings stability over the next few years.
In the past year, share price of IRM Energy is up 11%.
Valuations
Let’s now turn to the valuations of the companies in focus, using the Enterprise Value to EBITDA multiple as a yardstick.
Valuations among the four city gas companies are quite different. Adani Total Gas is trading at 47.8 times EV/EBITDA. That is far higher than the industry median of 7.6 times. The premium suggests that investors are factoring in its aggressive expansion.
Indraprastha Gas trades at 8.1 times, which is not very different from its three-year average of 10.2 times. Gujarat Gas trades at 12.9 times, again close to its historical range of 13.9 times. IRM Energy, listed only in October 2023, trades at 6 times EV/EBITDA, compared to its one-year average of 7.4 times.
Return ratios help in understanding how well capital is being used. Indraprastha Gas is reporting a Return on Capital Employed (ROCE) of 20.8% and a Return on Equity (RoE) of 16.4%. Gujarat Gas shows a ROCE of 19.5% and a ROE of 14.2%. Both companies are delivering steady returns relative to the capital invested in the business.
Adani Total Gas reports ROCE of 17.5% and ROE of 16.8%. These are healthy numbers for a utility-style business. IRM Energy reports lower ratios, with ROCE at 8.3% and ROE at 4.7%, as it is still building out its network.
The difference comes down to stage of growth. Adani Total Gas is priced for expansion. Indraprastha Gas and Gujarat Gas are more established businesses. Their return numbers have been fairly consistent over time. Their valuations also sit closer to where they have traded in the past.
IRM Energy is still in expansion mode. It is putting money into new areas and building its network. That usually means lower returns in the initial years. The lower valuation multiple reflects that stage of the business.
For investors, the choice depends on whether they prefer stability or are willing to back expansion-led growth.
Conclusion
The city gas business is moving into its next stage. Many big cities are already covered. Growth will now depend on how quickly companies can build and scale in newer Geographical Areas. That process is gradual. Pipelines are laid first. Stations come up next. Volumes build slowly over time.
Adani Total Gas is trading at a premium because the market is betting on strong expansion. Indraprastha Gas and Gujarat Gas offer more predictable numbers, with steady returns and valuations closer to long-term averages. IRM Energy is still at an early stage. Its lower return ratios reflect ongoing investment rather than weak demand.
For investors, this space needs patience. Expansion does not translate into profits overnight. The key will be how efficiently capital is deployed and how fast new areas start contributing to earnings. Over the next few years, execution will matter more than short-term price swings. It may be a good idea to add these stocks to your watchlist and track how this story unfolds.
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Kerala CM Vijayan inaugurates BPCL CBG plant in Kochi
This facility will process 150 tonnes of biodegradable waste daily. It will generate compressed biogas and organic manure. This marks a significant step in sustainable waste management for the state. Similar plants are planned for other districts.
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Kerala Chief Minister Pinarayi Vijayan inaugurated the Compressed Biogas (CBG) plant of BPCL at Brahmapuram here on Friday.
Minister of State for Petroleum and Natural Gas and Tourism Suresh Gopi was also present at the event.
Vijayan inaugurated the plant online and said with its establishment, the state has taken a significant leap forward in the sustainable management of biodegradable waste.
According to him, Kochi has become the first city in Kerala to commission a CBG plant for treating biodegradable waste.
“The CBG plant will process 150 tonnes of source-segregated biodegradable Municipal Solid Waste (MSW) per day. It will generate 5.6 tonnes of compressed biogas and 28 tonnes of organic manure daily. The project is mutually beneficial to both Bharat Petroleum Corporation Ltd (BPCL) and the Kochi Corporation,” he said.
He further noted that similar plants will be set up in other districts, including Kozhikode, Kollam, Palakkad, Thrissur and Kottayam.
“Once these facilities become operational, Kerala will witness substantial advancements in the management and treatment of biodegradable waste,” he said.
Suresh Gopi said the plant has become a reality through the collaborative efforts of the Kerala Government, the Kochi Corporation, BPCL, and the Ministry of Petroleum and Natural Gas.
He emphasised that the vision and leadership of Prime Minister Narendra Modi and Union Home Minister Amit Shah also played a crucial role in realising the CBG plant in the state.
Their guidance inspired public sector undertakings under the Ministry of Petroleum and Natural Gas to actively pursue such sustainable initiatives, he said.
“The National Policy on Biofuels, 2018 provides a comprehensive framework to promote bioenergy in India by encouraging the production and use of biofuels. The Ministry of Petroleum and Natural Gas is setting up 195 CBG plants across the country to promote compressed biogas, of which seven are coming up in Kerala, “he said.
Gopi said that the Kochi plant stands as a strong testament to India’s commitment to clean energy, the circular economy, and sustainable urban development.
“It demonstrates how municipal waste can be transformed into eco-friendly fuel, thereby supporting environmental protection and generating livelihoods. This initiative will inspire many more such projects across the country,” he said.
He further appreciated the efforts of the state government and BPCL in making the project a reality.
“I will certainly acknowledge and consider the efforts put forth by the State Government. A couple of years ago, this land was a major concern for everyone. Today, it has transformed into a source of renewable energy,” he said.
Kerala ministers M B Rajesh and P Rajeev also spoke at the event.
MLA PV Sreenijin and senior officers of BPCL were also present in the event.
The CBG plant was established after the major fire at the 110-acre Brahmapuram waste plant in 2023, which prompted the Kerala High Court to intervene and direct the state government to find a permanent solution for waste disposal.
Then BPCL Kochi Refinery proposed setting up a Municipal Solid Waste (MSW)-based Compressed Biogas (CBG) plant at Brahmapuram to address Kochi’s mounting municipal waste crisis.
The facility has been designed to process 150 tonnes of source-segregated biodegradable Municipal Solid Waste (MSW) per day, supplied by the Kochi Municipal Corporation.
BPCL officials said that once fully operational, the plant is expected to produce 5.6 tonnes of compressed biogas and 28 tonnes of organic manure daily.
The project will provide a long-term solution to Kochi’s municipal waste management challenges by converting waste into clean energy and useful by-products, they said.
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In crunch, government says domestic PNG, CNG, LPG production priority
NEW DELHI: Facing a severe LNG (liquefied natural gas) crunch, govt on Monday invoked the Essential Commodities Act, 1955, to reallocate gas supply and slashed allocation for fertiliser and other industries, while seeking to ensure full availability for priority sectors such as domestic piped natural gas (PNG) for kitchens, compressed natural gas (CNG) for transport and LPG production.
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The decision came days after petroleum ministry insisted that supplies were comfortable, and it was seeking more flows from Canada and Australia amid outages in Qatar, the top source of LNG for India.
Hours after the notification, PM Modi met petroleum minister Hardeep Puri and external affairs minister S Jaishankar for an assessment of the situation and its impact on energy flows.
During a Cabinet meeting earlier in the day, Modi asked his colleagues to take stock of the situation in their respective ministries and interact with all stakeholders to ensure people do not suffer because of the conflict in West Asia.
While fertiliser units, many of which are advancing shutdown, will be supplied 70% of their average consumption in the last six months, availability for industrial units will be 80% of the average for the last six months.
Govt in talks with several countries to import LNG through other routes
The notification added that the gas required to meet the needs of the priority sectors would be met through full or partial curtailment of gas supplied to petrochemical facilities and power plants, and by reducing gas allocation to refineries to 65% of their requirement.
India imports nearly half of its natural gas requirements of around 190 million standard cubic metres per day (mscmd). More than 50% of the imported LNG comes from Qatar and the UAE through the Strait of Hormuz, which has effectively remained closed to vessel movement for nearly 10 days now. Officials said govt was in talks with several countries to import LNG through other routes, while refiners have made spot purchases to meet their requirements.
Ministries such as shipping and road transport have held stakeholder consultations and are holding regular meetings to address concerns. Officials said inter-ministerial consultations were also taking place to ensure prices of essential commodities remained under control, considering that govt has enough buffer stock of rice, pulses and other items.
The fact that availability of PNG and CNG impacts millions of people in India has forced govt to invoke the Essential Commodities Act and categorise them as priority sectors along with LPG production to ensure there is no shortage of the fuel.
Though the fuel is also used as feedstock for fertilisers, petrochemicals, tea industries, manufacturing and power generation, among others, the gazette notification considered it necessary to regulate production, sector-wise allocation and diversion of LNG supplies. The notification said this was done to ensure equitable distribution and continued availability of natural gas for priority sectors.
GAIL (India), in coordination with Petroleum Planning and Analysis Cell, will manage the supplies of natural gas to implement the directives.
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Natural Gas/ Pipelines/ Company News
Deepak Gupta Takes Charge as CMD, GAIL
Deepak Gupta, a veteran energy sector executive, assumed charge as Chairman and Managing Director (CMD) of GAIL (India) Limited, India’s largest natural gas transmission and marketing company, thereby marking a new leadership chapter for the Maharatna PSU. He succeeds Sandeep Kumar Gupta, who superannuated on February 28.
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Strong Technical and Leadership Background
Gupta brings decades of experience in natural gas transmission, marketing, and infrastructure development. Over the years, he has held several key leadership positions within GAIL, spanning operations, business development, project execution, and corporate management. As a result, he offers a balanced blend of technical expertise and strategic oversight. Gupta’s strengths include project and construction management, global procurement and contracts, technology selection, operations and maintenance, and board-level leadership.
Tenure Until 2029
Gupta joined GAIL’s board as Director (Projects) in February 2022. Now, as CMD, he will serve a tenure extending until February 28, 2029. His appointment ensures leadership continuity at a time when India is expanding its natural gas infrastructure and pushing for a cleaner energy mix.
Track Record of Project Execution
Gupta played a key role in completing the Dabhol breakwater project of Konkan LNG, a subsidiary of GAIL. The project enabled all-weather LNG operations at Dabhol, thereby enhancing supply reliability and strengthening India’s gas import infrastructure. As reported by deccanchronicle.com, with his proven track record in project execution and infrastructure development, Gupta is expected to steer GAIL through its next phase of growth, expansion, and energy transition initiatives.
https://chemindigest.com/deepak-gupta-takes-charge-as-cmd-gail/
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GAIL, Indian Oil cut gas supply to industries as Qatar halts LNG production amid war crisis
GAIL and Indian Oil cut gas supply to industries after Qatar halted LNG production, while Strait of Hormuz tensions raised India’s energy security concerns. GAIL and Indian Oil have reduced gas supplies to industries by 10–30% after Qatar halted LNG production. Indian companies on Tuesday reduced natural gas supplies to industries in anticipation of tighter supplies from the Middle East after top producer Qatar halted production, Reuters reported, citing official sources.
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India, the world’s fourth-largest buyer of LNG, relies heavily on the Middle East for its imports. The report stated that Petronet LNG, the top LNG importer, has informed GAIL (India) and other companies of lower supplies.
Qatar halted its liquefied natural gas production on Monday, as Iran continued to strike Gulf countries in retaliation for Israeli and US strikes against it. The attacks have also halted oil and gas shipments through the Strait of Hormuz, driving up global energy prices and shipping costs.
India is the top LNG client for Abu Dhabi National Oil Company and the second-largest buyer of Qatari LNG.
GAIL, Indian Oil supply cut range
The Reuters report said that GAIL and Indian Oil Corp informed customers of the gas supply cut late on Monday. The cuts range from 10 per cent to 30 per cent, the report added.
As per the report, the cuts have been set at minimum lifting quantities to shield suppliers from any penalties from customers under contractual terms.
To make up for the LNG shortfall, companies including Indian Oil, GAIL, and Petronet LNG are planning to issue spot tenders, the report added. However, the spot prices, freight, and insurance costs have surged.
Strait of Hormuz closure to add further pressure
Iran has announced the closure of the Strait of Hormuz, resulting in pressure on India’s oil and gas supply needs. The Strait holds strategic importance for the country, as 50 per cent of its crude oil imports and 85 per cent of its LPG supply pass through the troubled sea route.
“The Strait of Hormuz is closed. Our heroes in the Islamic Revolutionary Guard Corps Navy and the Army will set fire to any ships that wish to pass through this strait,” Irani Brigadier General Ebrahim Jabari” said on state television
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GAIL to invest Rs 1,736 cr in wind power project in Maharashtra
GAIL is India’s largest natural gas transmission and marketing company. It owns and operates an extensive network of about 18,0001 km of natural gas pipelines, spanning the length and breadth of India. New Delhi: State-owned gas utility GAIL (India) Ltd will invest Rs 1,736.25 crore in setting up a wind power project in Maharashtra that will help expand its renewable energy portfolio, as it targets net zero carbon emissions by 2035.
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In a regulatory filing, GAIL said its board at its meeting on Friday approved the investment in setting up 178.2 megawatt wind power capacity.
The project, to be completed in 24 months from the award of the contract, will add to the existing portfolio of 117.95 MW. Besides, the firm also has 27 MW of solar energy projects spread across Rajasthan, Uttar Pradesh and Madhya Pradesh.
Its wind power projects are in Gujarat (19.2 MW), Karnataka (38.1 MW) and Tamil Nadu (60.65 MW).
The project to generate electricity from wind is part of a broader effort to boost renewable capacity and meet net-zero carbon emission targets by 2035.
“GAIL has set a target of achieving net zero through reduction in Scope-1 and Scope-2 (carbon) emissions by 2035 and Scope-3 emissions by 2040. GAIL plans to increase its renewable energy capacity up to 3.4 GW by the year 2035 to achieve the net zero targets,” according to the company’s website.
The company is also investing in other forms of clean energy, including green hydrogen and compressed biogas (CBG) projects, to align with India’s national energy goals.
GAIL is India’s largest natural gas transmission and marketing company. It owns and operates an extensive network of about 18,0001 km of natural gas pipelines, spanning the length and breadth of India.
Besides being the biggest marketer of gas in the country, it also owns the LPG portfolio and has two petrochemical plants in Pata, Uttar Pradesh, and one in Assam.
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Petronet LNG shares in focus after declaring ‘force majeure’ on LNG shipments amid Iran war
On Monday (March 2), shares of Petronet LNG Ltd ended at ₹310.40, down by ₹12.95, or 4.00%, on the BSE. Shares of India’s biggest liquefied natural gas importer, Petronet LNG Ltd, will be in focus on Wednesday, March 4, after the company on Tuesday said that vessels are currently unable to safely transit through the Strait of Hormuz, to reach Ras Laffan, the loading port of QatarEnergy, in light of the ongoing war in the Middle East involving Iran and Israel.
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Considering the prevailing security situation and material risks to maritime navigation, the company has issued a Force Majeure notice to QatarEnergy in respect of its LNG tankers — Disha, Raahi and Aseem. QatarEnergy, as the company’s seller, has also issued a notice indicating a potential event of Force Majeure due to hostilities in the region.
Consequently, Petronet LNG has issued corresponding Force Majeure notices to its off-takers — GAIL (India) Limited, Indian Oil Corporation Limited and Bharat Petroleum Corporation Limited — under the relevant Gas Sale and Purchase Agreements on March 3, 2026. The company said acts of war are excluded under the Business Interruption Insurance coverage taken by Petronet LNG.
It added that the likely impact of the Force Majeure, which is currently an ongoing event, cannot be estimated at this stage. The company said it is closely monitoring developments and will inform stock exchanges of any material updates.
Force Majeure means unforeseen circumstances, that prevent the fulfilment of an obligation or a contract.
Third Quarter Results
The company posted a 5.2% rise in net profit to ₹848.3 crore, compared with ₹806 crore in the previous quarter. Revenue grew 1.4% QoQ to ₹11,163 crore from ₹11,009 crore.
Operating performance improved during the quarter, with EBITDA rising 7.3% to ₹1,199 crore from ₹1,117 crore in the preceding quarter. The EBITDA margin rose slightly to 10.7% from 10.1% on a quarter-on-quarter basis.
The growth in profit was supported by the combined impact of higher revenue and a sharper rise in EBITDA. The improvement in margins indicates relatively stronger operating efficiency during the quarter.
On Monday (March 2), shares of Petronet LNG Ltd ended at ₹310.40, down by ₹12.95, or 4.00%, on the BSE.
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Policy Matters/ Gas Pricing/ Others
Government assures fertiliser plants of 70% LNG supply
NEW DELHI: Govt on Tuesday said fertiliser plants had been placed under ‘priority sector-2′ for natural gas supply, thereby guaranteeing the industry at least 70% of its average natural gas consumption, reports Dipak Dash. In a notification, the ministry of petroleum and natural gas said the average would be calculated on the basis of the previous six months’ consumption. The fertiliser department said the measure aims to safeguard production against global supply chain disruptions, particularly LNG issues.
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Though the ministry said the current stock of around 6.2 MT of urea was good, the 30% cut in LNG supply, the key feedstock for producing the soil nutrient, may bring down the opening stock in April, industry insiders said. They added that it would all depend on how long the crisis persists.
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India Defines 4 Priority Sectors For Using Natural Gas Amid Iran-US War
New Delhi: The Iran-US war in the Middle East has affected the supply of natural gas across the world. The Strait of Hormuz remains a part of the war zone for over two weeks, due to which more than 750 cargo ships are stuck at major ports in the region.
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India buys 50 per cent of its natural gas needs from the international market. Of this, it imports 20 per cent from Qatar.
After Iran’s missile attacks on Qatar’s gas fields, the world’s largest natural gas exporting company, QatarEnergy, stopped production. This has affected supply of natural gas to Asian regions.
To deal with this growing challenge, India has guidelines for regulating the supply and use of natural gas in different sectors across the country. According to the new guidelines issued by the Ministry of Petroleum, the central government divided key sectors into four priority areas.
First, the supply of natural gas will be maintained at 100 per cent of their average gas consumption of the last six months for domestic piped natural gas supply, CNG for transport, LPG production, for pipeline compressor fuel, and other essential pipeline operational requirements.
Second, the supply of natural gas to fertilizer plants will be ensured at 70 per cent of their average gas consumption of the last six months.
Third, gas supply to tea industries, manufacturing and other industrial consumers through the National Gas Grid will be maintained at 80 per cent of the average gas consumption of the last six months.
And fourth, all gas distribution units will ensure that 80 per cent of the average gas consumption of the last six months is supplied to industrial and commercial consumers through their networks.
“India imports 50 per cent of its gas from the international market. About 40 per cent of this is LNG, of which we import 20 per cent from Qatar. India has to reduce gas consumption during the crisis period temporarily, and reduce the use of gas in industry, especially in the power sector,” Kirit Parekh, an economist who specialises in energy, especially gas, told NDTV.
“In this situation, while it would be expensive to generate electricity, India has potential to increase power generation and the sector won’t be affected much. But businesses that are running their industries with gas as a critical resource will have to use it wisely. A lot of gas is used by petroleum companies to produce hydrogen. We can also produce it with electricity, but it is a very expensive option,” Parekh said.
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MNRE Issues Draft Guidelines To Account Water-Linked Emissions In Green Hydrogen Production
The Ministry of New and Renewable Energy (MNRE) has released draft guidelines to measure greenhouse gas (GHG) emissions linked to off-site water drawal and treatment for green hydrogen production. Issued on February 25, 2026, the move aims to strengthen India’s green hydrogen framework and bring it in line with global standards. The new draft aligns the Green Hydrogen Certification Scheme of India (GHCI) with ISO 19870:2023, which focuses on a detailed “Well-to-Gate” assessment of hydrogen production.
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The guidelines aim to close an important gap in emission accounting. Until now, the focus has been mainly on emissions within the hydrogen production plant. However, water is a key raw material in green hydrogen production, especially for electrolysis. The new draft makes it clear that while drawing water from natural sources, such as rivers or the sea, will not be counted as emissions, the energy and chemicals used to treat that water must be included in the total GHG intensity. This ensures that hydrogen labeled as “green” is assessed on a more complete lifecycle basis.
The framework identifies five main scenarios for water sourcing and provides clear methods for calculating emissions in each case.
In the case of captive offsite treatment, where a hydrogen producer operates its own desalination or treatment plant outside the main facility, the company must use primary data. This includes actual metered electricity consumption and chemical use to calculate emissions accurately.
For municipal water supply, producers sourcing water from state utilities can use a default benchmark value. The current benchmark for municipal water supply is set at 0.603 kgCO2e per cubic meter. This provides a simple and standardized approach for emission calculation.
In industrial clusters where multiple companies share common water treatment infrastructure, emissions must be allocated based on the volume of water used by the hydrogen producer. This ensures fair distribution of emissions among users.
The guidelines also promote the use of recycled water. When treated wastewater is used, only the additional or “incremental” energy required to further purify the water to electrolysis grade will be counted. This approach encourages companies to adopt circular water solutions and reduce overall environmental impact.For hybrid supply systems, where producers use more than one water source, daily records must be maintained. A weighted average method will be applied to determine total water-related emissions.
To maintain transparency and consistency, MNRE has also defined standard benchmarks for grid emission factors and transmission losses. The ministry has invited comments from green hydrogen producers and industry associations. Stakeholders have until March 13, 2026, to submit their feedback. The consultation process is expected to play an important role in shaping the regulatory framework for India’s growing green hydrogen sector.
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LNG Use / LNG Development and Shipping
India’s LNG supplies at risk as QatarEnergy halts production after drone attacks
QatarEnergy, the world’s largest LNG company and a major supplier of liquefied natural gas to India, on Monday announced that it has halted LNG production following Iranian drone attacks on its facilities. In a press statement, the company said it would continue to communicate the latest available information to stakeholders.
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Earlier, Qatar’s Defence Ministry said the country was attacked by two drones launched from Iran. A ministry spokesperson said one drone targeted a water tank at a power plant in Mesaieed Industrial City, while the other struck an energy facility in Ras Laffan Industrial City operated by QatarEnergy.
Qatar is India’s largest LNG supplier, with annual exports of around 11.4 million tonne (MT), accounting for over 40% of New Delhi’s total LNG imports.
“Due to military attacks on QatarEnergy’s operating facilities in Ras Laffan Industrial City and Mesaieed Industrial City in the State of Qatar, QatarEnergy has ceased production of liquefied natural gas (LNG) and associated products. QatarEnergy values its relationships with all of its stakeholders and will continue to communicate the latest available information,” the company said in a press note.
This marks the second major oil and gas infrastructure disruption linked to the escalating Iran–Israel conflict in the region. On Monday, Saudi Aramco’s Ras Tanura oil refinery announced it was temporarily shutting down certain units after a fire broke out following a drone attack.
QatarEnergy has signed a 20-year agreement with Petronet LNG Limited for the supply of 7.5 million tonnes per annum (mtpa) of LNG. Under the deal, beginning May 2028, QatarEnergy’s LNG fleet will deliver the contracted volumes to Indian terminals. In 2025, QatarEnergy also signed a 17-year sales and purchase agreement (SPA) with Gujarat State Petroleum Corporation to supply up to 1 million tonnes of LNG annually to India.
Meanwhile, Indian oil marketing companies are planning to buy Russian crude amassed in floating storage in Asia as the situation in West Asia escalates. According to a report, officials of the Petroleum Ministry and oil marketing companies have drawn up contingency plans for a crisis in Iran that has all but stopped flows through the Strait of Hormuz, a major global chokepoint.
It is believed that oil ministry officials are now pushing the Ministry of External Affairs to seek some room for manoeuvre from the United States to import Russian crude. As of late last week, there were 9.5 million barrels of Russian oil sitting in Asian waters.
Moreover, India has other options, including increasing supplies from Russia that follow the Red Sea route. The report also noted fast-tracking supplies from Venezuela and pushing domestic producers to raise output.
In case of further escalation, the government may also consider curbing refined fuel exports to ensure adequate supply for domestic consumers. It can prioritise household gas and piped supplies, potentially directing industrial users to switch fuels. The government may also ask private sector giant Reliance Industries Ltd to divert more fuel to the domestic market, while other refiners tweak output to maximise liquefied petroleum gas production at the expense of products such as naphtha.
India can also tap its strategic petroleum reserves and push domestic producers to raise output, the people said, asking not to be named as the discussions are not public.
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For Petronet LNG, the West Asia shock comes at the wrong time
The Qatar supply disruption and risks around the Strait of Hormuz risks come as the LNG importer grapples with weak volumes and rising competition at home.
Shares of Petronet LNG Ltd have fallen nearly 10% this week, though they have recovered somewhat from Wednesday’s intraday plunge of 16%, as the conflict in West Asia rattled investors. The state-owned company has been hit hard by the shutdown of a key supplier, QatarEnergy’s liquefied natural gas (LNG) liquefaction plant, after an aerial attack on its facility.
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Petronet procures 8.5 million tonnes per annum (mmtpa), about half of its LNG requirements, from QatarEnergy’s 82 mmtpa Ras Laffan facility, the world’s largest LNG plant. Petronet operates LNG terminals that import the fuel, regasify it and sell it to consumers.
Importers are also grappling with evacuation challenges following the blockade of the Strait of Hormuz by Iranian forces. Given the prevailing security situation and the risks to maritime navigation, Petronet has issued a force majeure notice to QatarEnergy for three LNG tankers—Disha, Raahi, and Aseem.
The disruption has sent LNG spot prices soaring, doubling week-on-week to about $25 per mmbtu (million British thermal units), according to Bloomberg. Gas prices tend to react sharply to supply shocks because the market has fewer alternative sources and limited storage capacity.
Emkay Global Financial Services estimates Petronet’s Dahej plant utilization to fall to 77% in the March quarter (Q4FY26), from 97% in Q3, if the Qatar disruption lasts for the full month. In a recent statement, Petronet has said that ‘acts of war’ is not included under the business interruption insurance cover it has. Thus, the impact of the conflict on the company could be higher.
The conflict also arrives at an awkward time. Petronet was already contending with softer market conditions, marked by lower gas volumes amid rising competition and muted demand from industries and the power sector. Total gas volumes handled by the company fell 6.6% in the nine months ended December (9MFY26), while Ebitda declined a sharper 13%.
There is, however, a potential offset. The Kochi-Mangalore-Bangalore gas pipeline, expected to connect to the national gas grid by June, could lift volumes in the southern region. That would help improve utilization at the Kochi terminal, which has been running well below capacity, averaging 26% in 9MFY26 and 23% in FY25.
Valuations offer some comfort. Petronet’s shares now trade at about 10x estimated FY27 earnings per share, according to Bloomberg consensus, a steep discount to the long-term average multiple of 12.2x. A quick easing of the conflict, or assurances of safe passage through the Strait of Hormuz, could help stabilize operations and limit the damage.
US President Donald Trump has assured that the US Navy would escort tankers through the strait, and that the US Development Finance Corp. would provide insurance cover for transit, which could offer investors some relief if implemented.
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Asian Buyers Struggle to Find March LNG as Supply Remains Tight
Some Asian LNG buyers are struggling to find prompt cargoes after a war-related outage at the world’s largest export facility in Qatar tightened global supplies of the super-chilled fuel.
Countries including Thailand, Bangladesh, India and Vietnam are dipping into the spot market to safeguard near-term energy security as uncertainty persists over the duration of the US-Israeli war against Iran. But some tenders for this month — like from India’s Gail and GSPC — have gone unawarded, indicating a shortage of immediately available fuel. Thailand’s PTT was seeking a late March-early April cargo but only bought for next month.
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While some importers were able to secure liquefied natural gas for March, a few of these cargoes were awarded at high prices. Bangladesh locked in two emergency shipments for this month, one at about $28 per million British thermal units — about 2.5 times higher than the January rate — and the other at close to $23/mmbtu, according to a Petrobangla official, who added the move was to avert a domestic energy crisis.
The tight supply also comes at a time when Southeast Asia is expecting hotter weather in the months ahead, potentially raising power demand. Buyers in Asia will need to continue competing with each other and Europe for a limited amount of gas.
Global LNG prices have surged as the Middle East conflict continues to roil energy markets. European gas jumped as much as 30% Monday, following a spike in crude oil, before settling about 6% higher. Asian LNG prices have more than doubled since the war broke out on Feb. 28, with traders expecting prices to remain high for as long as it lasts.
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Two LNG cargoes on their way to country, says govt amid gas shortage fears
As per oil ministry, as much as 47.4 mmscmd gas supply has been affected due to force majeure conditions.
The ministry of petroleum and natural gas on March 11 said that the country has started receiving cargoes for liquified natural gas and liquified petroleum gas with two LNG cargoes on their way to India amid concerns over shortage of gas.
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“Crude oil supply remains secure. Volumes secured today exceed what normally would arrive from strait of Hormuz,” Sujata Sharma, Joint Secretary at Petroleum and Natural Gas ministry, adding that state-run oil marketing companies have secured multiple crude cargoes from various countries. The official also said that two more cargoes of crude oil are on their way to India.
She noted that today, almost 75% of crude oil is coming from routes other than the Strait of Hormuz as against 55% earlier.
The country’s overall gas consumption is 189 MMSCMD of which 97.5 MMSCMD is produced domestically and the remaining is imported, as per official data.
Sharma said that as much as 47.4 mmscmd gas supply has been affected due to force majeure conditions. “Our refineries are operating at highest capacity utilisation and some are operating at more than 100% than capacity,” Sharma added.
The anxiety follows Qatar’s decision last week to halt production after Iran launched strikes on Gulf countries following Israeli and US attacks. Qatar is India’s biggest supplier of liquefied natural gas importing as much as 45% of gas to India and the disruption has raised alarms over potential spillover effects on domestic fuel availability.
Meanwhile, India’s oil minister Hardeep Singh Puri said on Tuesday that there was no shortage of LPG for household use, seeking to calm consumers after reports of panic buying.
To mitigate the crisis, India invoked emergency powers and directed refiners to maximise LPG production to prevent a shortage of the essential cooking fuel.
Order on natural gas
Amid disruptions to gas supplies transiting the Strait of Hormuz –through which the bulk of India’s imports pass — the government has also issued the Natural Gas (Supply Regulation) Order, 2026, invoking the Essential Commodities Act, 1955.
According to the order, the central government took the step after assessing that the ongoing conflict in the Middle East that has resulted in the disruption of liquefied natural gas (LNG) shipments and that several suppliers have invoked force majeure clause.
The order states that the supply of natural gas to certain sectors shall be treated as priority allocation and shall be maintained subject to operational availability to hundred per cent of their average past six-month average gas consumption.
These sectors include domestic piped natural gas supply; compressed natural gas for transport; LPG production including LPG shrinkage requirements; pipeline compressor fuel and other essential pipeline operational requirements.
Government sources said that there was a shortage of gas amid Gulf tensions due to which gas supplies had to be balanced among key other sectors.
“Procurement through alternative routes is underway to secure supplies. We import 60% of our requirement. 90% is through Strait of Hormuz. Domestic LPG production has increased by 25% and is being directed to household consumers after government took steps to increase output,” said an official.
Domestic LPG price today in Delhi is Rs 913. Without government intervention, the prices would have been much higher, the official said.
Besides, a panel of senior executives from three PSU oil companies will review complaints of shortage of commercial LPG cylinders across the country and make fuel available to meet the genuine requirements of non-essential sectors like hotels and restaurants.
“Fuel stock adequate”
While maintaining that the country has adequate fuel stocks, the Union Ministry of Petroleum and Natural Gas on March 9 directed refineries to maximise LPG output by curtailing petrochemical streams and extended the LPG refill booking cycle to 25 days from 21 days.
“In light of current geopolitical disruptions to fuel supply and constraints on supply of LPG, the ministry has issued orders to oil refineries for higher LPG production and using such extra production for domestic LPG use,” the ministry said in the post on X.
At present, 28 vessels with Indian flags are operating in the Persian Gulf. 24 of them are at the Western region of Strait of Hormuz, and 4 in the Eastern region of the Strait, Rajesh Kumar Sinha, Special Secretary, Ministry of Shipping and Waterways said.
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Electric Mobility/ Hydrogen/Bio-Methane
Centre Approves Rs 7,970 Mn Green Hydrogen Jetty at Paradip
The Ministry of Ports, Shipping and Waterways has approved the development of a jetty with allied facilities for handling green hydrogen, ammonia and other liquid cargo at Paradip Port at an estimated cost of Rs 7,970 million (mn). The project will be implemented by the Paradip Port Authority on a build-operate-transfer basis. The ministry said the allocation reflects the expected investment required to establish dedicated handling and storage infrastructure. The scheme is expected to mobilise both domestic and foreign interest.
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The Union Minister of Ports, Shipping and Waterways, Sarbananda Sonowal, said that the project would enhance cargo capacity and catalyse investment while generating employment and supporting a green energy ecosystem in eastern India. The ministry noted that the facility will include provisions for handling other liquid cargo to ensure optimal utilisation during the initial growth phase of the green hydrogen sector. The inclusion of multiple cargo types is intended to diversify Paradip Port’s cargo profile and improve operational flexibility. The ministry stated that the project aligns with the objectives of the National Green Hydrogen Mission and is expected to support investments in green energy infrastructure in Odisha. The proposed jetty will incorporate specialised infrastructure and advanced safety systems for handling and storing green energy derivatives and other liquid cargo. Authorities envisage that these measures will strengthen port-based logistics for clean energy commodities and encourage ancillary industrial activity around the port. The infrastructure is planned to meet regulatory and industry safety norms. Implementation on a build-operate-transfer basis is intended to attract private participation and manage project risks while enabling public oversight. The development is presented as a catalyst for regional economic activity without displacing existing port operations. Stakeholders are expected to coordinate further planning to integrate the jetty with wider transport and energy networks. Timelines and operational details will be finalised through consultations with operators and investors.
NITI Aayog Unveils Cement Decarbonisation Roadmap 01 Mar 2026 1 Min Read D CW Team NITI Aayog has released a sector-specific decarbonisation roadmap for cement as part of three green transition reports covering cement, aluminium and MSMEs. The report projects cement production rising to around 2,100 million tonnes by 2070 from 391 million tonnes in 2023, while targeting a reduction in carbon intensity to 0.09–0.13 tCO₂e per tonne. It recommends clinker substitution, refuse-derived fuels, CCUS adoption and carbon trading mechanisms to enable deep decarbonisation.
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Green hydrogen projects planned in Gorakhpur, Rampur to promote
In Rampur district, Zero Footprint Industries Private Limited is setting up another green hydrogen production facility with a capacity of about 22.5 kilograms per hour. Two green hydrogen production projects are being set up in Uttar Pradesh’s Gorakhpur and Rampur districts as part of the state government’s push to expand alternative energy capacity.
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According to officials, a 0.5 MW green hydrogen pilot project is being established in Gorakhpur by Torrent Power. The project is expected to produce around 9 kilograms of hydrogen per hour.UP New and Renewable Energy Development Agency (UP NEDA) Director Indrajeet Singh said the pilot project will help assess the use of green hydrogen technology in the state and evaluate the potential for its wider commercial deployment.
In Rampur district, Zero Footprint Industries Private Limited is setting up another green hydrogen production facility with a capacity of about 22.5 kilograms per hour.Officials said the projects are intended to support the production of hydrogen using renewable energy sources and may contribute to industrial activity linked to hydrogen-based technologies.
Green hydrogen is produced through the electrolysis of water using electricity generated from renewable sources. The process separates hydrogen from water without generating carbon emissions associated with fossil fuels.
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Bengaluru startup Newtrace raises $6.3 million to expand green hydrogen technology
Bengaluru-based clean energy startup Newtrace has raised $6.3 million (₹56.93 crore) in a Pre-Series A funding round to expand its green hydrogen technology and move towards commercial production, Inc42 reported.
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The funding round was led by HDFC Bank and Mitsui Sumitomo Insurance Venture Capital. Existing investors, including Aavishkaar Capital, Speciale Invest, Micelio Technology Fund and Peak XV’s Surge, also participated in the round. Angel investors Manish Prataprai Gandhi and Renu Manish Gandhi joined as well.
Founded in 2021 by Prasanta Sarkar and Rochan Sinha, the company develops electrolysers that are used to produce green hydrogen. The startup said its technology can produce very pure hydrogen while reducing production costs by up to 60 percent.
The company plans to use the new funds to begin commercialising its technology and expects to start delivering its products within a year. As part of this plan, it will focus on pilot-scale manufacturing, testing its technology with customers and strengthening supply agreements, while also expanding its engineering and production capacity.
Newtrace currently operates from a 30,000 square foot facility in Bengaluru and has a team of more than 45 engineers and scientists.
The startup had earlier raised $5.7 million in a seed funding round in 2023 to expand its operations.
The company’s work supports India’s efforts to increase the use of green hydrogen under the National Green Hydrogen Mission, launched in 2023 to make the country a global hub for green hydrogen. The mission has a total budget of ₹19,744 crore and focuses on policy support, demand creation, research and development, and building the required infrastructure.
Several other companies, including Ohmium, HYDGEN and Avaada Group, are also working on technologies to support the country’s green hydrogen plans.
However, investment activity in climate technology startups has remained limited in recent months. One of the last major funding rounds in this segment was raised by HYDGEN in October 2025, when it secured $5 million in equity and debt to upgrade its manufacturing systems and increase production capacity.
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Green energy push to gain momentum, says Odisha chief minister
Bhubaneswar: Chief Minister Mohan Charan Majhi on Friday welcomed the Centre’s approval for a dedicated jetty at Paradip Port Authority to handle green hydrogen, ammonia and other liquid cargo, describing it as a major boost for Odisha’s maritime and clean energy ambitions. The project has been cleared at a cost of Rs 797.17 crore, Hans India reported.
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The Chief Minister thanked Narendra Modi and Union Minister for Ports, Shipping and Waterways Sarbananda Sonowal for approving the proposal. In a post on X, he said the new facility would help connect Odisha’s emerging green hydrogen production centres to global markets and strengthen export logistics for clean energy products. He added that the project would encourage fresh investment, generate employment and support the goals of India’s National Green Hydrogen Mission.
The approval was granted on Thursday. The jetty will be developed by Paradip Port Authority under a build-operate-transfer arrangement. Once completed, it will have the capacity to handle 4 million tonnes of cargo annually. The facility will include a dedicated berth, along with storage tanks, pipelines, cargo-handling systems and related infrastructure.
Officials said the structure will have a centre-to-centre distance of 279 metres between the extreme end dolphins and a dredged depth of 14.3 metres in front of the berth to ensure the safe handling of liquid cargo vessels. The port authority will provide financial assistance amounting to 20 per cent of the project cost, or Rs 159.43 crore, during the construction period. The project is expected to be completed within two years.Authorities said the development is aligned with the objectives of the National Green Hydrogen Mission and is expected to strengthen green energy infrastructure in Odisha. The jetty will be equipped with specialised facilities and safety systems for the storage and handling of green energy products and other liquid cargo, supporting the growth of a green hydrogen ecosystem around Paradip Port.
https://bioenergytimes.com/green-energy-push-to-gain-momentum-says-odisha-chief-minister/
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Haryana Budget: State to set up green hydrogen plant in Panipat
250 kilotonnes annual target by 2030; 2 GW electrolyser capacity planned with rooftop solar push and relief for industry power disruptions. The Haryana government will set up a hydrogen manufacturing plant in Panipat with a target to produce 250 kilotonnes of green hydrogen per annum by 2030, Haryana chief minister Nayab Singh Saini announced during his 2026-2027 budget speech in the assembly on Monday.
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Saini said it would be the first hydrogen plant in the state. The government will develop a two-gigawatt electrolyser manufacturing capacity and produce related components by implementing the Haryana State Green Hydrogen Policy. “It will be the first ever hydrogen plant in the state that will get established in Panipat,” he said.
To boost research in the power sector, Saini said the state will collaborate with the Central Power Research Institute to establish a regional research and testing centre. He expressed gratitude to Union minister Manohar Lal Khattar for supporting the project. “To promote research activities in the state power sector, the Haryana government will collaborate with the Central Power Research Institute (CPRI) to establish a regional research and testing centre in the state,” he said.
Announcing relief for industrial consumers, Saini said they will not be charged fixed charges for extended disruption periods beyond the prescribed time limit under the Right to Service Act. “Industries often face disruption in the electricity supply and breakdowns that can’t be resolved within the prescribed time limit under the Act, forcing them to rely on diesel generator sets,” he said, adding that fixed charges will not be levied for the extended period if discoms fail to restore supply within the time limit.
In 2026-2027, biomass power projects ranging from 9.9 megawatts to 25 megawatts, totalling 200 megawatts, will be set up in 13 districts, including Ambala, Fatehabad, Hisar, Jhajjar, Jind, Kaithal, Karnal, Kurukshetra, Panipat, Rohtak, Sirsa, Sonipat and Yamunanagar, officials said.
The government aims to increase rooftop solar installations fourfold to about 220,000 households from the current 54,674, according to officials under the Pradhan Mantri Surya Ghar Muft Bijli Yojna. It will also install smart meters for 6.8 million non-agricultural consumers, against about 873,000 installed so far.
Farmers will be allowed to install solar panels on agricultural fields linked to existing tubewell connections, with discoms purchasing surplus power.
Additionally, five 25-megawatt waste-to-energy plants will be set up under the Department of Urban Local Bodies in the Faridabad, Gurugram, Manesar, Jind, Hisar, Fatehabad, Ambala, Panchkula and Yamunanagar clusters.
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Centre Approves Rs 7,970 Million Green Hydrogen Jetty At Paradip Port
The Ministry of Ports, Shipping and Waterways has approved the development of a jetty with allied facilities at Paradip Port for handling green hydrogen, ammonia and other liquid cargo at an estimated cost of Rs 7,970 million (mn).
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The project will be implemented by the Paradip Port Authority (PPA) on a build-operate-transfer basis and the ministry indicated that the facility will support an integrated approach to clean energy logistics in the region.
The union minister for ports, shipping and waterways conveyed that the project is expected to enhance cargo capacity, catalyse investment and generate employment while creating a robust green energy ecosystem in eastern India and the ministry stated that provisions will be made to handle other liquid cargo to ensure optimal utilisation during the initial growth phase of the green hydrogen sector.
The project has been aligned with the objectives of the National Green Hydrogen Mission and is expected to support investments in green energy infrastructure in Odisha; authorities anticipate port-based logistics improvements will ease the movement of clean energy commodities and reduce handling bottlenecks.
The proposed jetty is to incorporate specialised infrastructure, storage facilities and advanced safety systems for handling and storing green energy derivatives and planners envisage that these measures will underpin the development of an integrated green hydrogen ecosystem around the port.
The PPA will proceed with detailed engineering, environmental clearances and stakeholder consultations before awarding contracts to private developers under the build-operate-transfer model and officials forecast that dedicated jetty facilities will make Paradip Port a strategic node for eastern and central supply chains for low carbon fuels; the ministry expects the project to catalyse wider economic activity without providing a specific timeline for completion.
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INTERNATIONAL NEWS
Natural Gas / Transnational Pipelines/ Others
Peru: Peruvian gas pipeline to be fixed this weekend, Balcazar says
LIMA, March 10 (Reuters) – Peruvian President Jose Balcazar said on Tuesday that repairs to the country’s main natural gas pipeline should be finished on Friday, allowing natural gas supply to normalize this weekend and potentially bringing the country’s worst energy crisis in two decades to a close.
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Peru’s Transportadora de Gas (TGP) has been working to repair the pipeline in Cusco’s Megantoni district since early March, when its rupture triggered the government to impose sweeping emergency measures.
During a press conference, Balcazar added that the company expects natural gas supply to reopen on Saturday and for distribution to be normalized on Sunday.
The breakdown of TGP’s pipeline, the backbone of the system that supplies nearly half of Peru’s electricity and most of its LPG, has forced widespread gas rationing, pushing up energy prices and exposing long‑standing vulnerabilities in the Andean nation’s energy system.
Balcazar said in-person classes for schools and universities would start back on Wednesday, after the government had announced virtual classes this week due to the rationing.
The crisis proved an early test for Balcazar, who was appointed in February after Congress ousted his predecessor. The country is set to hold presidential elections on April 12.
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Egypt Accelerates Horizontal Drilling to Boost Oil and Gas Output
The petroleum sector is fast-tracking the deployment of horizontal drilling and hydraulic fracturing technologies to unlock hard-to-reach oil and gas reserves and drive a significant increase in crude and natural gas production under the ministry’s five-year plan, said Karim Badawi, the Minister of Petroleum and Mineral Resources.
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Speaking during a meeting held to follow up on executive progress, Badawi stressed that while Egypt holds substantial petroleum potential, maximizing output requires localizing advanced technologies and creating effective economic mechanisms in partnership with major international drilling and technology service companies.
He added that the ministry is developing incentive models to ensure readiness for large-scale application of these technologies, paving the way for broader deployment across Egypt. He also praised the recent close coordination between the Egyptian General Petroleum Corporation (EGPC) and global service providers to operationalize this approach.
During the meeting, attended by senior ministry officials and executives from international service and technology firms operating in Egypt, Salah Abdel Kerim, CEO of EGPC, highlighted promising opportunities for horizontal and lateral drilling in several conventional reservoirs, particularly in the Western Desert, Eastern Desert, Gulf of Suez, and Sinai.
He noted that horizontal drilling can significantly enhance well productivity compared to vertical wells in the same geological formations, while reducing the total number of wells needed to achieve targeted production levels.
Abdel Kerim also outlined the potential of unconventional reservoirs and ongoing work by EGPC’s Production Division, in cooperation with international service companies and production partners, to assess technical and economic requirements for implementation. He emphasized plans to expand hydraulic fracturing applications, pointing to the successful experience of Norpetco in the Western Desert as a model for future development.
Egypt’s Ministry of Petroleum and Mineral Resources (MoPMR) has unveiled a new five-year exploration and production plan (2026–2030) to achieve self-sufficiency in crude oil while boosting natural gas output and reversing recent declines in production. It focuses on increased cooperation with international oil companies, measures to limit import costs, and channeling local production into value-added industries and export markets, as part of broader efforts to enhance Egypt’s energy security and economic resilience.
https://egyptoil-gas.com/news/egypt-accelerates-horizontal-drilling-to-boost-oil-and-gas-output/
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Nigeria : OAU gets integrated CNG refuelling hub
The Midstream and Downstream Gas Infrastructure Fund has commissioned an integrated Compressed Natural Gas refuelling facility at Obafemi Awolowo University, in what stakeholders described as a strategic step to embed Nigeria’s gas transition agenda within federal universities.
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The project, unveiled in Ile-Ife, Osun State, is part of a broader initiative to deploy CNG infrastructure across 20 federal universities nationwide through equity partnerships with private investors.
In a statement issued on Sunday, the Executive Director of MDGIF, Oluwole Adama, described the project as more than a campus transport solution, calling it a “practical demonstration” of Nigeria’s gas-based energy transition.
The statement read, “This project represents more than the commissioning of a refuelling station. It symbolises progress, partnership, and purpose in advancing Nigeria’s energy transition, promoting cleaner fuels and deepening domestic gas utilisation in line with national energy objectives.
“As you may be aware, MDGIF was established to catalyse investments in midstream and downstream gas infrastructure across the country through equity partnerships with private investors.
“Our mandate is clear: to support projects that unlock gas value chains, improve gas access, enhance environmental sustainability, and deliver tangible socio-economic benefits to Nigerians.”
He explained that the OAU facility is one of 20 CNG refuelling infrastructure projects being supported across federal universities in partnership with FEMADEC Energy Limited.
“This CNG refuelling infrastructure project at Obafemi Awolowo University is one such strategic investment. Through our equity partnership with FEMADEC Energy Limited, MDGIF is proud to support 20 CNG refuelling infrastructure projects in 20 federal universities across Nigeria,” he added.
Unlike conventional urban CNG rollouts, the OAU project is designed as a hybrid infrastructure combining refuelling, vehicle conversion services, and transport deployment within a controlled academic environment.
The Vice-Chancellor of the university, Prof Adebayo Simeon Bamire, said the initiative would transform the institution into a living laboratory for alternative fuel research and innovation.
“This project is designed to serve both the university and the surrounding community. It will foster research opportunities, practical learning, and innovation in alternative fuels,” Bamire said.
“It will also strengthen relations between the university and the host community, promote sustainable transport, and create shared economic value.”
He noted that beyond transportation, the facility would support engineering, environmental science, and energy policy research within the institution.
The Group Managing Director/Chief Executive Officer of FEMADEC Group, Akinnola Fola, reaffirmed the company’s commitment to building scalable gas infrastructure nationwide.
“Our focus is to deliver safe, efficient, and scalable CNG infrastructure across Nigeria through strong collaboration between the public and private sectors,” Fola said.
“We see universities as critical anchors in the national gas expansion programme because they combine innovation, youth engagement, and community integration.”
The OAU CNG project is expected to reduce transport costs on campus, lower carbon emissions, and provide cleaner mobility alternatives for students and staff.
It will deploy CNG buses and provide vehicle conversion services, enabling petrol-powered vehicles to switch to gas, which stakeholders say is cheaper and more environmentally friendly.
In support of clean transport within the institution, the First Lady of Nigeria, Oluremi Tinubu, donated 50 CNG-powered buses to the university, while PiCNG donated 10 CNG-powered tricycles to enhance affordable mobility.
The intervention is expected to ease transportation challenges on campus while accelerating the adoption of gas-powered transport solutions.
The development comes amid intensified efforts by the Federal Government to expand domestic gas utilisation following the removal of petrol subsidy in 2023.
Nigeria, which holds one of Africa’s largest proven gas reserves, has long struggled with limited domestic gas infrastructure despite being a major exporter of liquefied natural gas.
The establishment of MDGIF was aimed at bridging financing gaps in the midstream and downstream gas segments, particularly in processing, storage and distribution infrastructure.
Embedding CNG facilities within universities may help drive behavioural change among young Nigerians while serving as a scalable model for broader urban deployment.
With rising fuel prices and growing environmental concerns, stakeholders argue that gas-powered mobility offers a transitional pathway toward cleaner energy without the heavy infrastructure demands of full electrification.
As MDGIF expands the initiative to other campuses, observers say the success of the OAU project could determine whether Nigeria’s gas transition moves from policy ambition to everyday reality.
https://punchng.com/oau-gets-integrated-cng-refuelling-hub/
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Canada: Pembina taking a go-slow approach to new natural gas pipeline buildout
The corporate logo of Pembina Pipeline Corp. is shown in this undated handout photo. THE CANADIAN PRESS/HO, Pembina Pipeline Corp. *MANDATORY CREDIT* CALGARY — Pembina Pipeline Corp. is taking a go-slow approach to the buildout of a natural gas pipeline expansion spanning northeast British Columbia and northwest Alberta to ensure the added transportation capacity comes online when producers need it.
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The Calgary-based energy infrastructure company has regulatory approval in-hand for a new 89-kilometre pipeline connecting Taylor, B.C. with Gordondale, Alta., at an estimated capital cost of about $341 million.
Late Thursday, Pembina green-lit an initial $115-million phase of that project — a 16-kilometre segment of pipe connecting Alberta gas fields to a pump station at Gordondale. It’s slated to start up early next year.
During an analyst conference call Friday, company executives were quizzed on why they decided to only move forward with part of the project for the time-being, and whether it was due to any change in commodity price outlook or shift in customers’ drilling plans.
Chief operating officer Jaret Sprott said it’s about spending capital prudently.
“We will need that project full-stop one day,” he said.
“Our people really took a step back and worked collaboratively with operations, our engineering (and) hydraulics teams, and they came up with a little bit more of a capital-light solution … It still allows us to meet our customers’ needs and meet their egress demand almost as they grow. It’s almost on-demand.”
New pipeline
On Thursday, Pembina also gave the official go-ahead to a new 95-kilometre pipeline that would ship 120,000 barrels per day of natural gas liquids between Birch and Taylor, B.C., starting late next year. That project has a price tag of $310 million.
CEO Scott Burrows said Pembina is poised to benefit from projects peers are undertaking. Enbridge Inc. has plans to expand its cross-Canada system and some of its U.S. network to move more oilsands crude south.
And Trans Mountain Corp. aims to add capacity to its line from Alberta to the Vancouver area.
“That’s obviously going to drive growth in the oilsands, which should have a pull on condensate, which should be good for our overall system,” he said.
Condensates, or natural gas liquids, are used to blend with tarry oilsands bitumen, enabling it to flow through pipelines. Pembina’s network, including the two newly-sanctioned expansions, reaches into liquids-rich zones of Alberta and B.C.
On Thursday, Pembina said earnings for the final three months of 2025 were $489 million, or 78 cents per share, compared to $572 million, or 92 cents per share, a year earlier.
Revenue fell to $1.91 billion from $2.15 billion during the same 2024 quarter.
Pembina has partnered with the Haisla Nation on the Cedar LNG project in Kitimat, B.C., which would enable natural gas to be shipped by tanker across the Pacific in an ultra-chilled liquid state. Pembina says advanced construction of the floating LNG vessel is more than 35 per cent complete.
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Israel Shuts Down Natural Gas Fields as Iran Attack Unfolds
The halt is a security measure, the Energy Ministry said in a statement, without specifying the fields affected. Energean Plc, the operator of the Karish deposit, said it had been instructed to suspend production. The move is a repeat of steps taken last year when Iran previously came under Israeli attack, and retaliated. Back in June, Israel shut its biggest gas field — Leviathan — as well as Karish, cutting off supplies to import-dependent Egypt.
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While Energean supplies gas to the domestic market only, Israel’s other two fields — Leviathan and Tamar — also export the fuel. Chevron Corp., which operates both, declined to comment on any shutdowns on Saturday.
The US-Israeli attacks, and Tehran’s retaliation against American military bases in several countries, raise the risk of a wider war in a region that’s key to global energy supplies.
Leviathan is contracted to send about 4.5 billion cubic meters a year to Egypt, and Cairo’s dependence is set to rise following a $35 billion deal struck last year, which would see 130 billion cubic meters sent from 2026 to 2040.
Egypt became a net gas importer in 2024 and has since bought up large volumes of liquefied natural gas, striking agreements for supplies out to 2028.
Increased Israeli flows would mean Cairo may be able to import less LNG in the future. Leviathan’s gas is cheaper, yet the interruption of production — both last summer and now — highlights the vulnerability of that route.
The disruption in June forced the Egyptian government to halt supplies to some industries, including fertilizer producers.
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Saudi Arabia: Saudi Aramco achieves significant progress in its gas production plan
Saudi Aramco has announced the achievement of significant progress in its plan to expand gas production, with the start of production at the Jafurah field, the largest unconventional gas field in the Middle East, and the commencement of operational activities at the Tanajib Gas Plant, one of the largest gas plants in the world, AzerNEWS reports, citing Arab News.
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The oil giant aims to increase its sales gas production capacity by approximately 80 percent by 2030 compared to 2021 production levels, reaching nearly 6 million barrels of oil equivalent per day from total gas and associated liquids production, according to the Saudi Press Agency.
This is expected to generate additional operating cash flows ranging between $12 billion and $15 billion in 2030, subject to future demand for sales gas and liquids prices.
President and CEO of Saudi Aramco, Amin Al-Nasser, said: “We are proud to commence production at the Jafurah field and begin operations at the Tanajib Gas Plant. These are major achievements for Saudi Aramco and the future of energy in the Kingdom. Our ambitious gas program is expected to become a key source of profitability.”
He affirmed that these mega-projects contribute to meeting the growing domestic demand for gas, supporting industrialization and development in several key sectors, in addition to producing significant quantities of high-value liquids.
Al-Nasser expressed his gratitude for the support, trust, and attention that Saudi Aramco receives from the Custodian of the Two Holy Mosques, King Salman bin Abdulaziz Al Saud, and His Royal Highness Prince Mohammed bin Salman bin Abdulaziz Al Saud, crown prince and prime minister, noting that this has had the most profound impact on the company’s achievements and distinguished projects that serve the Kingdom’s Vision 2030.
The gas extracted from the Jafurah field is expected to support the Kingdom’s growth targets in key sectors such as energy, artificial intelligence, major industries, and petrochemicals, potentially providing a major boost to the Kingdom’s economy and strengthening its position among the world’s top ten gas producers.
Saudi Aramco began first producing unconventional shale gas from the Jafurah field in December 2025, with technology playing a pivotal role in unlocking the potential of the Jafurah field and establishing it as a global benchmark for unconventional gas development.
Since its inception, the project has leveraged technology to help reduce drilling and stimulation costs and enhance well productivity, contributing to its strong economic prospects.
The Jafurah area covers 17,000 sq. km and is estimated to contain 229 trillion standard cubic feet of raw gas and 75 billion barrels of condensates. The Jafurah field project aims to produce 2 billion standard cubic feet per day of sales gas, 420 million standard cubic feet per day of ethane, and approximately 630,00 barrels per day of gas liquids and condensates by 2030.
The Tanajib Gas Plant is a key pillar in Aramco’s strategy to increase gas processing capacities and diversify its energy product portfolio, helping to foster long-term economic growth.
Operations began in December 2025, and its raw gas processing capacity is expected to reach 2.6 billion standard cubic feet per day in 2026. The start of operations at the Tanajib Plant coincided with the commencement of production from the Marjan field expansion and development program.
The plant is distinguished by its digital integration, enhanced operational efficiency, capability to execute complex projects, and optimal use of resources. It processes raw gas associated with crude oil production from the offshore Marjan and Zuluf fields.
Aramco’s gas expansion is expected to create thousands of direct and indirect job opportunities, generating significant added value and strengthening its position as a reliable energy provider.
It also helps meet the growing demand for natural gas and enhances its supply to national industries.
The expansion strategy supports efforts aimed at achieving the optimal energy mix for local electricity generation, advancing the Kingdom’s liquid fuel displacement program, which will have a positive environmental impact, supporting the Kingdom’s ambition to achieve net-zero emissions by 2060, enhancing energy security, and contributing to building a more diversified national economy.
https://www.azernews.az/region/255062.html
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Saudi Arabia: Saudi Aramco bringing shale gas revolution to the Arabian Desert
DUBAI: The shale revolution that made the United States the world’s top oil producer is taking shape in the Arabian Desert. Deep in the sands southeast of Saudi Arabia’s giant Ghawar oilfield, state oil company Aramco is pushing ahead with a natural gas megaproject that could boost the kingdom’s revenues by billions of dollars in the coming years.
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It has brought in US and Chinese firms like Halliburton and Sinopec to deploy advanced machinery – including ‘walking rigs’, towering structures capable of moving short distances without dismantling and reassembling – to speed up drilling and well completions at the Jafurah basin.
While the kingdom has scaled back its futuristic giga-projects and reversed plans to lift oil capacity, Aramco – the world’s biggest oil exporter – has raised its gas production targets with this $100 billion bet at the center, as it seeks to become a major global natural gas player. Jafurah, estimated to contain 229 trillion standard cubic feet of raw gas and 75 billion barrels of condensate, is potentially the biggest shale gas development outside the US.
For decades, Saudi Arabia has burned a portion of its most valuable asset – crude oil – to power its grid. Now, with fewer than five years left to fulfill Crown Prince Mohammed bin Salman’s Vision 2030 agenda to diversify the oil-reliant economy, the pressure is on to replace those liquid fuels with gas.
“Jafurah is not just a large gas field: it is a strategic platform that supports the Kingdom’s broader growth ambitions across key sectors, including energy, artificial intelligence, and major industries like petrochemicals,” Aramco said in a statement in response to Reuters questions.
New shale frontier
On Thursday, Aramco officially announced the start of production at Jafurah, a milestone for a project that underwent years of incubation mirroring the early years of the US shale boom. It said output began in December 2025, a disclosure that Reuters reported that month after it was included in the Saudi finance ministry budget statement. “The excellent progress at Jafurah is a testament to a decade of relentless innovation and focus on value creation,” Aramco’s Upstream President Nasir Al-Naimi told Reuters.
“Early well performance has been outstanding, validating our high-tech approach and reaffirming the significance of this flagship project to our gas growth strategy.” The maths is simple: Saudi Arabia uses more than 1 million barrels per day (bpd) of crude and fuel oil for domestic power generation. Aramco aims to replace 500,000 bpd of that by 2030 with gas, freeing up the crude for export. At current prices of around $70 a barrel, 500,000 bpd of crude would generate nearly $12.8 billion in revenue a year.
In its statement on Thursday, Aramco said it expects the gas expansion to generate incremental operating cash flows of $12 billion to $15 billion in 2030. “Through our strategic gas expansion, we anticipate attractive double-digit returns as we set about unlocking significant volumes of high-value liquids and capitalize upon captive domestic gas demand,” Al-Naimi told Reuters.
Reuters analysis of rig data from Baker Hughes, tender awards, and corporate filings reveals that Jafurah has emerged as the kingdom’s priority capital project and a new frontier for US oilfield services firms just as the US shale boom matures and they look for opportunities elsewhere.
Jafurah offers a rare prize: a massive, untapped unconventional basin requiring the hydraulic fracturing and horizontal drilling expertise perfected in Texas. Rig count data shows that while activity in the US Permian Basin has plateaued, gas drilling in Saudi Arabia has increased as development of Jafurah picked up and capital was redeployed after the kingdom scrapped a previously planned 1 million-bpd oil capacity expansion.
Aramco has announced around $26 billion worth of contracts for Jafurah’s first two phases since 2018, when it awarded Halliburton a contract for unconventional so-called gas stimulation, usually fracking. Other first-phase contracts went to Sinopec, South Korea’s Samsung Engineering and Italy’s Saipem.
To make shale extraction viable in the punishing desert environment, its engineers have also developed bespoke technology, according to company journals. Solutions include treating Gulf seawater to remove well-clogging sulfates for underground injection and ultra-strong diamond drill bits to cut through abrasive rock without overheating. Aramco is targeting 2 billion standard cubic feet per day (bcfd) of gas from Jafurah, 420 million standard cfd of ethane, and 630,000 bpd of associated liquids by 2030.
At its peak, Jafurah could produce up to 1 million bpd of condensates, a source with knowledge of the matter told Reuters. Condensates are non-gas liquids that can be processed to produce petrochemical feedstock naphtha and other refined products. In November, Aramco said it was raising its kingdom-wide gas expansion goal to 80 percent above 2021 levels, from a 60 percent targeted boost announced in March 2024. Based on the company’s 2021 baseline of 9.2 bcfd, Reuters calculations show the revision means Aramco aims to pump nearly 2 bcfd extra by the end of the decade, which is the same volume Aramco has targeted from the Jafurah project. Some industry analysts, however, have questions about the pace of the ramp-up. Aramco had previously said Jafurah was expected to come online in early 2024.
“There is still a lot of uncertainty around the pace of ramp-up and how much of the condensates will be exported or used as feedstock,” said Monica Malik, chief economist at ADCB. She projected that revenue from Jafurah could add 0.3 percent to Saudi GDP growth in 2026.
The gas expansion is designed to extend the lifespan of Saudi Arabia’s hydrocarbon revenues, which still account for more than half of the state budget, while positioning Riyadh to benefit from booming Asian demand, said Neil Quilliam, associate fellow at think tank Chatham House. While it frees up crude for export, Aramco is also building a global liquefied natural gas portfolio by investing in projects abroad. It has taken a stake in LNG firm MidOcean and signed 20-year supply agreements for supplies from Commonwealth LNG’s proposed Louisiana project and NextDecade’s Rio Grande terminal in Texas. Aramco’s focus on gas comes as Qatar – whose reserves are conventional and so easier to extract than shale – pushes ahead with its own production expansion, aiming to cement its regional gas supremacy. Abu Dhabi National Oil Company is also making a big push into gas and LNG domestically and abroad.
The International Energy Agency and some market participants expect a surge of new Qatari and US LNG this decade that could create a global supply glut and depress prices. Aramco’s long-term ambition is LNG capacity of 20 million tons per annum (mtpa), Chief Executive Amin Nasser told analysts in August. Qatar has 77 mtpa of capacity, expected to reach 142 mtpa by 2030, while ADNOC targets 20 to 25 mtpa by 2035. Aramco expects domestic gas demand, meanwhile, to continue to rise, driven by industrial growth encompassing manufacturing, mining, and petrochemicals, Al-Naimi said. — Reuters
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Natural Gas / LNG Utilization / Bio-LNG
Australia: Chevron Inks 5-Year Deal to Supply Aussie Gas to Horizon Power
Chevron Corp said Friday it had signed an agreement to supply about 14 petajoules of natural gas over five years to Horizon Power, a power utility serving Western Australia. The volumes will come from the stakes of the United States energy giant in three projects in Western Australia: Gorgon and Wheatstone, both operated by Chevron, and North West Shelf. Deliveries are to start 2027.
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“The agreement with Horizon Power reflects Chevron’s continued commitment to supplying gas to the domestic market and underscores the ongoing role for gas in the state’s energy mix”, Chevron Australia president Balaji Krishnamurthy said in a company statement.
“As a flexible source of energy, gas plays a crucial role in supporting baseload electricity generation as well as a back-up for when weather conditions impact renewable power generation”.
“Through its suite of equity and jointly held gas sales agreements, Chevron is the largest supplier of gas for electricity generation in Western Australia”, Chevron said in the statement on its Australian website.
Gorgon and Wheatstone provide over 40 percent of the state’s gas supply, according to Chevron.
Gorgon includes a domestic gas plant with a capacity of 300 terajoules a day (TJd) and three liquefaction trains with a combined production of up to 15.6 million metric tons per annum (MMtpa) of liquefied natural gas, according to Chevron. Located on Barrow Island, it is fed by the offshore Gorgon and Jansz-Io fields.
Late last year Chevron announced a AUD 3 billion ($2.09 billion) final investment decision to proceed with Gorgon Stage 3.
The first in a planned series of tiebacks, Gorgon Stage 3 will develop the Geryon and Eurytion fields in the Greater Gorgon Area by connecting them to existing subsea gas gathering infrastructure and processing facilities on Barrow, Chevron said in a statement December 5, 2025.
Meanwhile Wheatstone produces up to 200 TJd for the domestic market. It also has two LNG trains with a combined capacity of 8.9 MMtpa, according to Chevron. Located on the Pilbara coast, Wheatstone processes gas from the offshore Brunello, Iago, Julimar and Wheatstone fields.
North West Shelf, operated by Australia’s Woodside Energy Group Ltd, has two domestic gas processing trains. It also has four LNG trains with a collective capacity of 14.3 MMtpa, according to Woodside. It processes gas from the Angel, Goodwyn, North Rankin and Perseus fields off the coast of Karratha.
An asset swap between Chevron and Woodside involving North West Shelf and Wheatstone, agreed 2024, is on course for completion in the second half of 2026, Woodside affirmed in its report of 2025 results published February 24, 2026. Chevron will exit North West Shelf and increase its stake in Wheatstone as a result of the transaction.
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Quarter: How the Middle East conflict is reshaping gas and LNG markets
Wood Mackenzie analysis indicates the Middle East conflict could disrupt 200 million tpy of forecast Asian LNG demand growth over the next decade as QatarEnergy’s force majeure removes 20% of global supply. The disruption threatens to raise long-term structural challenges for global gas and LNG markets similar to those seen following Russia’s 2022 invasion of Ukraine.
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With QatarEnergy’s declaration of force majeure on LNG shipments from Ras Laffan and European gas prices nearly doubling since Monday (2 March), the situation threatens to reshape buyer confidence, supply strategies, and even energy policy worldwide.
“The consequences of the war for gas and LNG are uncertain but could rival those that followed Russia’s invasion of Ukraine in 2022,” said Simon Flowers, Chairman and Chief Analyst at Wood Mackenzie. “Much will depend on whether the disruption is a short-lived blip or is more enduring, and whether gas and LNG infrastructure in the region suffers major damage.”
Key facts:
QatarEnergy declaration of force majeure removes 20% of global LNG supply.
Asian LNG demand forecast to grow by 200 million tpy over next decade.
Qatar and the UAE account for 79 million tpy and 5.6 million tpy of LNG capacity, respectively.
European gas prices nearly doubled since 3 March 2026.
Nearly 100 million tpy of US pre-FID LNG projects offer geographic diversification alternatives.
Supply diversification imperative
The crisis has exposed the concentration risk for those importing countries which are most dependent on Middle Eastern LNG supply. According to Gavin Thompson, Vice Chairman, Energy for Wood Mackenzie, this will fundamentally alter how buyers approach new long-term supply contracts.
“Assuming no significant damage to existing projects in Qatar and the UAE, the amplified risks associated with these volumes will, in time, dissipate,”
Thompson said. “But the crisis will drive home the importance of supply diversification. The raft of US pre-FID projects – almost 100 million tpy currently – come without a single geographic point-of-failure risk.”
However, US supply is not risk-free, not least from domestic energy policy and cannot be the only solution. Wood Mackenzie analysis indicates that pre-FID projects in Canada, Mozambique, and Argentina will look to capitalise on the uncertainty, while projects that have slipped on timeline, such as Abadi in Indonesia and Browse in Australia, could gain fresh impetus. Portfolio suppliers and national oil companies, including QatarEnergy itself, are expected to seek greater diversification of their own supply sources.
Asian demand growth at risk
Asia represents the cornerstone of the bullish outlook for gas and LNG, with Wood Mackenzie forecasting Asian LNG demand to increase by around 200 million tpy over the coming decade. However, that growth depends on competitive pricing and supply reliability, which are both now in question.
Asian markets could respond to the current loss of supply in several ways, according to Wood Mackenzie analysis. Coal is expected to take market share from gas and LNG in the power sector across Japan, South Korea, China, India, and Southeast Asia. Asian governments may accelerate renewables growth plans, though near-term upside will be limited. Additional incentives for domestic gas development could be fast-tracked but will similarly offer little immediate relief.
“Fundamentally, however, Asia needs more energy, while the region’s rising emissions will need to be addressed,” added Thompson. “With limited alternative options, we maintain our long-held view that LNG remains central to meeting future Asian energy demand.”
Confidence crisis for gas and LNG
Following Russia’s invasion of Ukraine, gas and LNG’s reputation as a reliable and affordable fuel was severely tested. While swift action to increase LNG availability helped rebuild confidence, the current crisis has reopened those wounds.
“In the eyes of gas and LNG sceptics, war has once again highlighted how supply disruptions and volatile prices can imperil energy security and affordability,” Massimo Di Odoardo, Vice President, Gas and LNG Research at Wood Mackenzie noted. “A swift restoration of supply and lower prices will allay some concerns among importers in the short term. But beyond the immediate crisis, more work will be required to rebuild confidence.”
Europe remains determined to reduce its dependence on gas and LNG, though the reality is that the region is already moving as fast as realistically possible on decarbonisation given budget constraints. With Russia still engaged in war with Ukraine, the chances of the EU lifting its ban on Russian gas and LNG imports remains highly unlikely – leaving Europe facing towering gas prices for the sec-ond time this decade.
Building resilience
Wood Mackenzie analysis suggests the gas and LNG industry may need to adopt structural changes similar to the oil market to restore buyer confidence. Building spare capacity and higher levels of storage could help address concerns about reliability and volatility, though this will require significant investment, time, and co-ordinated effort.
“Gas and LNG markets are reeling from the loss of supply,” said Di Odoardo. “The industry has been here before and has proven it can recover. Gas’s primary role in decarbonisation ? displacing coal and supporting the expansion of renewables ? is clear, but the industry may need to go further this time.”
Looking forward
For now, an end to the conflict remains the priority. Longer term, reinforcing gas and LNG supply reliability and minimising price volatility will be required to ensure the fuels’ demand trajectory remains intact.
“Gas and LNG have work to do to rebuild confidence,” Flowers said. “Building in spare capacity and higher levels of storage, for example, could help soothe a market anxious about reliability and volatility, just as has been done with oil. But this will be neither quick nor easy, requiring investment, time, and co-ordinated effort.”
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Egypt Seeks Earlier LNG Imports as Israel Cuts Gas Amid Iran War
Egypt is seeking to bring forward imports of some liquefied natural gas cargoes after energy supplier Israel shuttered some fields following its strikes on Iran, according to people familiar with the matter. Israeli gas supplies to Egypt have come to a complete halt, said an Egyptian official who asked not to be identified because of the sensitivity of the matter. To make up for any shortfall, the North African country is expediting LNG shipments it contracted in mega deals last year, two people familiar with the plans said.
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Egypt typically receives about 1 billion cubic feet of natural gas per day via a pipeline from neighboring Israel.
Read More: US, Israel Start Attacks on Iran in War That Engulfs Region
Israel earlier on Saturday ordered the temporary shutdown of some natural gas reservoirs as a security measure after launching attacks with the US on Iran. The Energy Ministry hasn’t specified which fields were affected; Israel operates three natural gas rigs in its waters, some of which export to Egypt and Jordan.
The move mirrors steps taken last year when Iran previously came under Israeli attack, and retaliated. Back in June, Israel shut its biggest gas field — Leviathan — as well as Karish, cutting off supplies to import-dependent Egypt.
Egyptian energy officials weren’t immediately available to comment. The country said on Saturday evening it had “implemented a series of proactive measures to secure energy supplies for the local market, including natural gas and petroleum products.”
Steps in 2025 “secured additional LNG quantities for extended periods to meet electricity, industry, and citizen needs by diversifying supply sources alongside local production,” according to an Oil Ministry statement.
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lobal LNG Development
QatarEnergy begins LNG supply to BD under second long-term deal
After the US’s Excelerate Energy, Middle East’s QatarEnergy has started supplying LNG to Bangladesh under its second long-term sales and purchase agreement (SPA).
The first LNG cargo from QatarEnergy under its second SPA reached the Moheshkhali floating storage and re-gasification unit, operated by the US-based company, and successfully delivered the LNG in the week ending February 20-27, a senior Petrobangla official told The Financial Express (FE) on Saturday.
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Bangladesh signed, on June 1, 2023, a long-term LNG supply deal with QatarEnergy for up to 1.5 million tonnes per year (Mtpa) for a 15-year period starting in 2026.
The SPA, inked in Doha, has two components: for 2026, the first year of the deal, QatarEnergy will supply 12 LNG cargoes to Bangladesh, with the option of adding another 12 cargoes under specific conditions, said the Petrobangla official.
From 2027 until 2040, QatarEnergy will supply a confirmed 24 LNG cargoes, equivalent to around 1.5 Mtpa of LNG, he added.
QatarEnergy’s LNG supply to Bangladesh under its second LNG SPA followed a similar start of LNG supply from US company Excelerate Energy last month.
With the supplies of LNG under two new LNG SPAs of Excelerate Energy and QatarEnergy, Bangladesh has been importing LNG under four separate LNG SPAs, said the Petrobangla official.
Previously, QatarEnergy and another Omani company were supplying LNG under two separate SPAs, with QatarEnergy starting supply from April 2018 and the Omani supplier from January 2019, he added.
Bangladesh has limited imports of LNG from the spot market after starting LNG imports under new contracts due to limited re-gasification capacity.
Bangladesh has so far only imported two LNG cargoes from the spot market in 2026, which is much lower than its imports during the previous year 2025, when it imported a total of 49 LNG cargoes from the spot market, the official added.
Bangladesh’s two operational FSRUs — Summit LNG and Excelerate Energy’s Excellence — have a combined re-gasification capacity of around 7.5 Mtpa of LNG, he said.
Bangladesh currently imports LNG under both long- and short-term SPAs from multiple suppliers and also sources LNG from the spot market to meet the country’s mounting natural gas demand, said a senior official of state-run Rupantarita Prakritik Gas Company Ltd (RPGCL).
Since Bangladesh’s LNG imports began in 2018, it has imported around 35.39 million tonnes of LNG through 571 cargoes as of January 2026, according to official data from RPGCL.
Bangladesh’s overall natural gas output currently hovers around 2,563 million cubic feet per day (mmcfd), including 848 mmcfd of re-gasified LNG, according to Petrobangla’s data as of February 26.
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Australian LNG Shares Jump as Iran Crisis Hinders Global Supply
Shares in Australian liquefied natural gas exporters surged after tankers stopped crossing the Strait of Hormuz, hampering about a fifth of global supply and threatening to raise prices of the fuel.
Woodside Energy Group Ltd.’s stock climbed as much as 11%, the most in almost six years, while Santos Ltd. advanced as much as 9%. Japan’s Inpex Corp., which also operates an LNG export facility in Australia, gained as much as 11% in Tokyo.
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LNG shipments through the Strait of Hormuz ground to a halt over the weekend after the US and Israel bombed Iran, leading Tehran to retaliate by targeting sites around the region and attacking several oil tankers. That has effectively cut off supply from no. 2 producer Qatar, as well as from the United Arab Emirates.
A month-long halt could see spot Asian LNG prices surge 130% to $25 per million British thermal units, Goldman Sachs Group Inc said in a note on Monday.
“Most Australian LNG exporters will likely be fairly constrained in their ability to rapidly increase LNG exports following interruptions in supply from Qatar,” said Joshua Runciman, lead analyst for Australian gas at the Institute for Energy Economics & Financial Analysis. “But they are likely to see higher earnings due to higher oil and LNG prices.”
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US: Venture Global Announces LNG Purchase Agreement with Trafigura
Today, Venture Global, Inc. (NYSE: VG) and Trafigura announced the execution of a new, binding agreement for the purchase of approximately 0.5 million tonnes per annum (MTPA) of U.S. liquefied natural gas (LNG) from Venture Global for five years commencing in 2026. This mid-term agreement offers greater flexibility to customers in the global LNG market and provides greater diversification for Venture Global’s LNG portfolio.
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“Trafigura is a global leader in LNG trading, and we are pleased to execute this mid-term LNG supply agreement with them to provide the market with flexible and reliable U.S. LNG,” said Venture Global CEO Mike Sabel. “Global energy demand is stronger than ever, and this is an important step in executing our strategy of adding more mid-term agreements, which will diversify the tenor of our LNG portfolio. Venture Global looks forward to helping ensure the world remains well-supplied in the short, medium, and long term.”
Igor Marin, Global Head of Gas, Power & Renewables at Trafigura, commented: “This agreement with Venture Global, a leading American producer and exporter of LNG, further strengthens and diversifies our global portfolio – reinforcing our ability to connect U.S. supply with customers across key international markets. US LNG supply is increasingly critical to global energy security, and we look forward to building on this collaboration with Venture Global.”
About Venture Global
Venture Global is an American producer and exporter of low-cost U.S. liquefied natural gas (LNG) with over 100 MTPA of capacity in production, construction, or development. Venture Global began producing LNG from its first facility in 2022 and is now one of the largest LNG exporters in the United States. The company’s vertically integrated business includes assets across the LNG supply chain including LNG production, natural gas transport, shipping and regasification. The company’s first three projects, Calcasieu Pass, Plaquemines LNG, and CP2 LNG, are located in Louisiana along the Gulf of America. Venture Global is developing Carbon Capture and Sequestration projects at each of its LNG facilities.
About Trafigura
Trafigura is a leading commodities group, owned by its employees and founded over 30 years ago. At the heart of global supply, Trafigura connects vital resources to power and build the world. We deploy infrastructure, market expertise and our worldwide logistics network to move oil and petroleum products, metals and minerals, gas and power from where they are produced to where they are needed, forming strong relationships that make supply chains more efficient, secure and sustainable. We invest in renewable energy projects and technologies to facilitate the transition to a low-carbon economy, including through MorGen Energy and joint venture Nala Renewables.
The Trafigura Group also comprises industrial assets and operating businesses including multi-metals producer Nyrstar, fuel storage and distribution company Puma Energy, the Impala Terminals joint venture and Greenergy, supplier and distributor of transportation fuels and biofuels. The Group employs approximately 14,500 people, of which over 1,400 are shareholders, and operates in over 150 countries.
Forward-looking Statements
This press release contains forward-looking statements. We intend such forward-looking statements to be covered by the safe harbor provisions for forward-looking statements contained in Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical facts, included herein are “forward-looking statements.” In some cases, forward-looking statements can be identified by terminology such as “may,” “might,” “will,” “could,” “should,” “expect,” “plan,” “project,” “intend,” “anticipate,” “believe,” “estimate,” “predict,” “potential,” “pursue,” “target,” “continue,” the negative of such terms or other comparable terminology.
These forward-looking statements, which are subject to risks, uncertainties and assumptions about us, may include statements about our future performance, our contracts, our anticipated growth strategies and anticipated trends impacting our business. These statements are only predictions based on our current expectations and projections about future events. There are important factors that could cause our actual results, level of activity, performance or achievements to differ materially from the results, level of activity, performance or achievements expressed or implied by the forward-looking statements. Those factors include our need for significant additional capital to construct and complete future projects and related assets, and our potential inability to secure such financing on acceptable terms, or at all; our potential inability to accurately estimate costs for our projects, and the risk that the construction and operations of natural gas pipelines and pipeline connections for our projects suffer cost overruns and delays related to obtaining regulatory approvals, development risks, labor costs, unavailability of skilled workers, operational hazards and other risks; the uncertainty regarding the future of global trade dynamics, international trade agreements and the United States’ position on international trade, including the effects of tariffs; our dependence on our EPC and other contractors for the successful completion of our projects, including the potential inability of our contractors to perform their obligations under their contracts; various economic and political factors, including opposition by environmental or other public interest groups, or the lack of local government and community support required for our projects, which could negatively affect the permitting status, timing or overall development, construction and operation of our projects; and risks related to other factors discussed under “Item 1A.—Risk Factors” of our annual report on Form 10-K for the year ended December 31, 2024 as filed with the Securities and Exchange Commission (“SEC”) and any subsequent reports filed with the SEC. Any forward-looking statements contained herein speak only as of the date of this press release and are based on assumptions that we believe to be reasonable as of this date. We undertake no obligation to update these statements to reflect subsequent events or circumstances, except as may be required by law.
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LNG as a Marine Fuel/Shipping
Qatar Offers to Lease LNG Ships as Top Exporter Stays Shut
Qatar is now offering a total of 10 liquefied natural gas tankers that it controls for lease, as the country’s massive export facility in the Persian Gulf remains shut due to the ongoing war in the Middle East. A group of eight LNG vessels under long-term charter by state-owned QatarEnergy, were being offered to the market on Friday, according to traders with knowledge of the matter.
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Earlier, the Al Thumama and Mesaieed, both of which are also under long-term charter by QatarEnergy, were being offered, according to traders with knowledge of the leasings. The vessels are currently off the west coast of Africa, ship-tracking data compiled by Bloomberg show.
The conflict in the Middle East, sparked by the US and Israeli strikes on Iran on Feb. 28, have roiled energy markets and driven up prices for crude, natural gas and oil products. Qatar earlier this week shut production at its Ras Laffan LNG export facility, the world’s largest, after an Iranian drone attack.
The war has effectively closed the Strait of Hormuz — the narrow waterway between Iran and the Arabian Peninsula — snarling shipping to and from the Persian Gulf, including tankers carrying Qatari LNG to global markets.
Al Thumama has mostly been used to export LNG from Ras Laffan since starting service in 2008, according to ship-tracking data from Kpler. Mesaieed, which entered the market in 2025, has exported three shipments from Qatar and one from the US, the data shows.
QatarEnergy didn’t immediately respond to a request for comment.
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China presses Iran to allow safe passage for oil, LNG ships through Strait of Hormuz
China is in talks with Iran to allow crude oil and LNG vessels safe passage through the Strait of Hormuz as the US-Israel war on Tehran disrupts a key global energy corridor. China is in talks with Iran to allow crude oil and Qatari liquefied natural gas (LNG) vessels safe passage through the Strait of Hormuz as the war between the United States, Israel and Tehran intensifies, Reuters reported on Thursday, citing diplomatic sources.
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The conflict, which entered its seventh day on Friday, has effectively paralysed one of the world’s most critical maritime routes, disrupting global energy flows. The narrow waterway handles roughly a fifth of global oil and liquefied natural gas supplies, making it a crucial artery for international energy markets.
China, the world’s second-largest economy, relies heavily on Middle Eastern energy imports and is said to be pressing Tehran to ensure Chinese-linked vessels can safely pass through the chokepoint. The report said Beijing has expressed concern that Iran’s restrictions on shipping could further destabilise global markets and threaten its own energy security.
About 45 per cent of China’s crude oil imports pass through the Strait of Hormuz, making uninterrupted access vital for the country’s industrial economy.
Ship-tracking data suggests that limited traffic has begun to resume under special circumstances. A vessel named Iron Maiden reportedly crossed the strait overnight after altering its signal to indicate it was “China-owned,” although analysts say far more sailings will be needed to stabilise energy markets.
Oil prices have surged more than 15 per cent since the conflict began, driven by supply disruptions and concerns about further attacks on energy infrastructure. Iran has reportedly targeted oil and gas facilities across the Gulf region as well as vessels attempting to transit the strategic waterway.
The escalation has also had broader geopolitical repercussions. Iranian missiles have reportedly reached as far as Cyprus, Azerbaijan and Turkey, heightening tensions and triggering warnings from major economies about rising inflation risks driven by energy prices.
Shipping activity in the strait has plummeted since the fighting began. According to vessel-tracking data from analytics firm Vortexa, crude tanker transits fell to just four vessels on March 1 — the day after hostilities erupted — compared with an average of 24 per day since January.
Roughly 300 oil tankers are currently stranded within the strait, according to data from Vortexa and ship-tracking firm Kpler, underscoring the scale of the disruption.
According to the report the vessels still moving through the waterway appear to have strong ties to China or Iran. Mike McDougall, a veteran in the global sugar industry, told Reuters that Middle Eastern sugar executives have observed a limited number of ships transiting the strait, most of which are Chinese or Iranian-owned.
Jamal Al-Ghurair, managing director of Dubai-based Al Khaleej Sugar, said some ships carrying sugar cargoes have been allowed to pass through the strait while others remain blocked, although he did not provide details on the criteria.
Earlier this week, Iran said vessels belonging to the United States, Israel, European countries and their allies would not be allowed to transit the Strait of Hormuz. The statement, however, did not mention China, raising expectations that Beijing could negotiate limited access for its shipping.
With global markets already rattled by the disruption, analysts warn that any prolonged closure of the strait could intensify energy price shocks and add further pressure on inflation worldwide.
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Iran: More LNG Tankers Divert From Hormuz in Widening Iran Crisis
Liquefied natural gas tankers set to load shipments in Qatar or the United Arab Emirates appear to be temporarily abandoning those plans, as most shipowners and traders avoid the Strait of Hormuz.
At least 13 empty LNG tankers that were on the eastern side of the chokepoint have diverted away, according to ship-tracking data compiled by Bloomberg. LNG vessels and other ships stopped crossing the waterway over the weekend following the initial strikes by the US and Israel on Iran.
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Exports from Qatar, the world’s largest LNG supplier after the US, must go through Hormuz to reach customers in Asia and Europe. A month-long halt could see spot Asian LNG rise 130% to $25 per million British thermal units, according to Goldman Sachs Group Inc.
“LNG shipping will continue to be disrupted, and traders should plan for a temporary halt of transit via the Strait of Hormuz for a couple of days,” said Leslie Palti-Guzman, founder of Energy Vista, an energy and shipping advisory firm. “We are in uncharted territory.”
There were a string of mixed messages around Hormuz over the weekend, as well as attacks on oil tankers. Some shipowners have issued orders to halt travel over safety concerns, while others are reassessing insurance costs as risk premiums surge.
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Bangladesh secures spot LNG cargoes as Mideast conflict lifts costs
DHAKA, March 12 (Reuters) – Bangladesh has bought three liquefied natural gas (LNG) cargoes on the spot market at higher prices, as it scrambles to steady supplies amid disruptions from the escalating Iran–Israel conflict, energy officials said.
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State-run Petrobangla has increasingly turned to the volatile spot market to bridge the supply gap, said energy officials in the South Asian nation, after some suppliers were forced to halt shipments.
“If the disruption drags on, we’ll have to lean more on costly spot LNG, which will add to our import burden and tighten supplies for power and industry,” an energy ministry official said, speaking on condition of anonymity.
The nation of 175 million relies on imports for roughly 95% of its energy needs. It has imposed fuel rationing for vehicles, curbed diesel sales and shut universities as the Iran war disrupts Middle East oil exports.
TotalEnergies will supply one cargo priced at $21.58 per million British thermal units (mmBtu) for delivery on April 5 to 6, while two from Posco International Corp priced at $20.76 per mmBtu each are set for delivery on April 9 to 10 and April 12 to 13.
The purchases come after QatarEnergy suspended LNG deliveries to Bangladesh under a long-term contract, citing such disruptions.
Petrobangla also arranged additional spot LNG cargoes this month to bridge the shortfall.
One shipment from commodity trader Gunvor, priced at $28.28 per mmBtu, is expected to arrive from March 15 to 16, while another cargo from Vitol, priced at $23.08 per mmBtu, is scheduled for March 18 to 19.
The latest purchases are a sharp increase over Bangladesh’s earlier LNG procurement this year. In January, it secured spot cargoes at about $10 per mmBtu, reflecting rapid price escalation as tension surged.
The government’s gas rationing effort has forced the shutdown of four fertiliser plants, to prioritise power generation and other key areas.
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UK: Venture Global pledges on-time LNG deliveries amid Middle East conflict
LONDON/HOUSTON, March 9 (Reuters) – U.S. liquefied natural gas developer Venture Global LNG (VG.N), has told customers of its Plaquemines export plant under development in Louisiana that it will start delivering contracted cargoes on schedule and at the already-agreed-upon prices, according to a letter seen by Reuters.
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The Virginia-based company wrote on Friday to buyers of Plaquemines Phase 1 – which include British major Shell (SHEL.L), and Poland’s Orlen (PKN.WA), – and said it remains committed to beginning long‑term deliveries from October 31 despite a surge in global gas prices because of the U.S.-Israeli war on Iran.
“As global energy markets react to the critical developments surrounding Iran and the Middle East, we wanted to assure you that, as of today, Phase 1 remains on schedule,” the letter said.
Companies including BP (BP.L), Shell, Unipec, Edison (EDNn.MI), Galp (GALP.LS), Repsol (REP.MC), and Orlen took Venture Global to arbitration in one of the biggest disputes in the history of the LNG industry. The companies accused Venture Global of withholding contracted cargoes during commissioning of its nearby Calcasieu Pass plant to take advantage of higher prices on the spot market during the 2021–2023 energy crisis.
While Venture Global – which blamed technical issues for the delays in formal commissioning at Calcasieu – prevailed over Shell, BP is seeking at least $3.7 billion after winning its case, a Venture Global filing showed. Orlen’s case remains pending.
“To be clear, fluctuating market conditions have no impact on our previously communicated schedule,” a Venture Global spokesperson said. “As we reaffirmed on our earnings call last week, nearly 70% of the 2026 cargoes at Plaquemines are already contracted for and we reaffirm that Phase One remains on target to declare COD in Q4 2026.”
The U.S.-Israeli war on Iran and Tehran’s attacks on Gulf neighbors have disrupted oil and natural gas exports from the Middle East and forced production stoppages, including in Qatar, which stopped operations at its LNG facilities, affecting some of the world’s largest plants and a source that supplies about 20% of global LNG.
Benchmark gas prices have jumped, with Dutch Title Transfer Facility futures trading at a three-year high of around $21 per million British thermal units, and the Japan-Korea Marker near a two-year high around $16.
Venture Global is the second-largest U.S. LNG exporter. Plaquemines is its second export terminal and it shipped 2 million metric tons of LNG last month from Plaquemines, according to LSEG data. The plant is sending out early commission cargoes even though it is still under development.
The company told customers it will begin developing its annual delivery program for the first contract year in early May, followed by the second contract year in July.
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Technological Development for Cleaner and Greener Environment Hydrogen & Bio-Methane
Ukraine and Austria partner on green hydrogen development
Ukraine and Austria will collaborate on green hydrogen under a freshly signed cooperation agreement. The document, inked at a meeting in Ukraine, outlines the development of production capacity, creation of infrastructure, and unlocking of investment in the sector.
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Denys Shmyhal, Ukraine’s First Deputy Prime Minister and Minister of Energy, said that the new partnership expands on the countries’ work across energy sectors and prioritises Ukrainian underground gas storage and joint gas production facilities.
Formalised in a meeting with Austria’s Federal Minister of Economics, Energy and Tourism, Wolfgang Gattmannsdorfer, the memorandum of cooperation comes alongside Austria contributing €15.5m ($17.9m) to Ukraine’s Energy Support Fund.
While details on undertakings of the partnership remain unclear, Shymyhal thanked Austria for providing Ukraine with equipment and for restoring production capacities.
Ukraine’s energy system, which has taken a major hit from Russia’s invasion, nevertheless maintains a large hydrogen production potential.
The IEA says producing 2.5 million tonnes of hydrogen a year could bring the country $18–22bn annually from steel and pipeline exports.
In April 2025, it was announced that Ukraine would supply green hydrogen from its planned Zakarpattia Hydrogen Valley to Slovakia’s EastGate H2V project.
Meanwhile, Austria is accelerating its production portfolio, having recently awarded four projects, including a 140MW plant scheduled for operation in 2027, a share of €274.8m ($319m).
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The Hydrogen Stream: BP and Iberdrola near Spain’s largest H project
BP and Iberdrola say their 25 MW green hydrogen project in Spain is nearing commissioning, while Moeve has approved a final investment decision for a 300 MW project in Spain. Castellón Green Hydrogen, the joint venture between bp and Iberdrola España, said its 25 MW green hydrogen project has reached 90% completion of the assembly phase, with all equipment now on site, including an electrolyzer system supplied by Plug Power. About 25 Spanish companies are involved in building the plant. The commissioning period, including testing to monitor equipment operation and performance, is scheduled to begin in May 2026, when the project is expected to become Spain’s largest operating green hydrogen facility.
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Moeve has approved the final investment decision to begin construction of the Andalusian Green Hydrogen Valley in the coming weeks. The first phase, known as Onuba, will have 300 MW of capacity and the option to expand by an additional 100 MW. The company said the phase represents a total investment of more than €1 billion ($1.2 billion), including associated infrastructure and a self-consumption PV plant. Moeve holds a 51% majority stake in the project, which also includes Masdar and Enalter.
Hyundai Motor Group has signed a memorandum of understanding with the South Korean government and Jeonbuk State to set up a hub integrating advanced artificial intelligence and hydrogen technologies in the Saemangeum area of Gunsan. The company said a significant portion of the investment will focus on new businesses based on these technologies, with total spending of about KRW 9 trillion (€5.27 billion) planned from 2026.
ITM said it has shipped the final batch of stacks to RWE’s electrolyzer plant in Lingen, Germany. The project consists of two 100 MW lines, with the first line now installed and certified, while the second is undergoing installation as the final stacks arrive on site. ITM said the facility, once operational, will be capable of producing up to 3,600 kg of hydrogen per hour using renewable electricity and will supply the TotalEnergies refinery in Leuna, Germany, via pipeline.
Snam has committed €200 million by 2030 to begin developing an end-to-end hydrogen backbone, around 60% of which will consist of existing gas pipelines that will be converted. The Italian gas transmission system operator said it plans to expand carbon capture and storage projects and hydrogen infrastructure where regulatory frameworks and returns are supportive. The company has reduced its planned hydrogen investment from €400 million to €200 million, including projects such as the Puglia Hydrogen Valley and the first phase of the Mazara del Vallo to Tarvisio corridor.
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Major energy companies back Humber for Britain’s first hydrogen network
The Humber hydrogen network could become the epicenter of the UK’s energy infrastructure. Four leading energy companies—National Gas, Centrica, Equinor, and SSE Thermal—have joined forces to develop the country’s first regional hydrogen transport and storage network.
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The project is centered around Humber Hydrogen, a network that includes the Humber Hydrogen Pipeline and the Aldbrough Hydrogen Storage underground storage system. Its proposal will participate in the British Government’s competitive process to decide the location of the UK’s first integrated hydrogen network.
This infrastructure would connect production hubs in Easington and Saltend with industrial users in Immingham, Keadby, and other strategic areas, facilitating the replacement of fossil fuels in energy-intensive industries.
It is estimated that the H2H Easington and H2H Saltend hydrogen plants could generate up to 3 GW of hydrogen combined. These projects will be key for continuous supply to sectors such as chemical, steel, and power generation. Connection to National Gas’s future national network would allow hydrogen to be distributed to other industrial areas of Great Britain.
Humber’s advantages to lead the hydrogen network
The Humber industrial cluster accounts for £18 billion annually for the British economy, but it is also the country’s most carbon-intensive. Favorable geology, existing infrastructure, and a specialized workforce position this region as the best candidate to host the hydrogen network.
With an estimated investment of £500 million, Humber Hydrogen could generate thousands of skilled jobs, boost regional growth, and strengthen the UK’s energy security. Representatives from participating companies and Parliament have expressed their support for the project, highlighting its potential to anchor long-term industrial activities and promote the production of sustainable fuels such as ammonia and SAF (sustainable aviation fuel).
Towards a low-carbon economy
The collaboration between companies with proven experience across the entire hydrogen value chain makes Humber Hydrogen a viable and replicable model for other regions. This proposal reflects a concrete strategy to advance the energy transition and decarbonize sectors that cannot be easily electrified.
Now, the next step is in the hands of the British Government, which must decide whether to support this initiative that promises to transform the nation’s energy landscape.
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South Africa launches R100 million hub at Wits to boost green hydrogen economy
South Africa’s ambition to build a competitive green hydrogen economy received a significant boost this week with the launch of the Wits–South Africa Hydrogen Localisation Initiative (Wits-SAHLI), a R100 million investment aimed at strengthening local research, skills and industrial capacity.
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The initiative is a partnership between Air Liquide South Africa, the University of the Witwatersrand (Wits University) and the Localisation Support Fund (LSF). It will see the establishment of a modular pilot hydrogen plant on Wits’ West Campus, designed as a “living laboratory” for applied research, teaching and industry collaboration.
Speaking at the launch on Friday, Minister of Higher Education and Training, Buti Manamela, said South Africa has committed itself to building a competitive hydrogen economy aligned with Hydrogen Society Roadmap.
“Hydrogen is not just an alternative energy source. It represents energy security. It represents industrial diversification, export potential, but also meaningful decarbonization,” Manamela said.
“But our mission alone is obviously not enough because what matters is how we build this economy and how and who is involved in that, in the building of that economy.”
Funded by Air Liquide, the facility forms part of the company’s multi-year decarbonisation investment programme in South Africa. It is scheduled to become operational by 2028.
At the core of the plant will be a 110kW electrolyser that converts water and renewable electricity into low-carbon hydrogen. The system will have the capacity to store up to 200kg of hydrogen and reconvert it into clean power, delivering up to 200kW of electricity during peak operation.
Deputy President Paul Mashatile described the facility as both a technological milestone and a strategic intervention in South Africa’s reindustrialisation drive.
“This moment marks not only the beginning of a groundbreaking project, but also the start of a shared national endeavour to build a new industrial capability that drives innovation, creates quality jobs and contributes to a just, inclusive and sustainable economy,” Mashatile said.
South Africa’s hydrogen strategy dates back to 2007, when Cabinet approved the Hydrogen South Africa Research, Development and Innovation Strategy, implemented by the Department of Science, Technology and Innovation.
The programme sought to leverage the country’s abundant platinum group metals, which are critical for fuel cell technologies.
Mashatile noted that the new Wits-SAHLI facility builds on the foundation laid by the three Hydrogen South Africa Centres of Competence, which focus on catalysis, hydrogen production, storage, distribution and systems integration.
He also acknowledged the role of Electricity and Energy Minister, Kgosientsho Ramokgopa, in strengthening policy certainty and advancing renewable energy integration, key enablers for a viable hydrogen economy.
For business and industry, the project represents more than an academic exercise. It is intended to provide a de-risked entry point for companies seeking to explore hydrogen technologies, while simultaneously developing local suppliers and technical expertise.
Professor Zeblon Vilakazi, Vice-Chancellor and Principal of Wits University, said the initiative aligned with the institution’s mission to produce world-class research and nurture talent capable of building new industries.
“We are proud to be at the forefront of driving innovation that addresses the critical challenges of our time,” Vilakazi said.
Nicolas Poirot, the CEO of Air Liquide for Africa, the Middle East and India, said the investment formed part of a broader knowledge-transfer approach.
“By bringing Air Liquide’s 60 years of global hydrogen expertise to Wits-SAHLI, we are providing South Africa with the technical expertise needed to lead the continent’s energy transition,” Poirot said.
Nkululeko Magadla, the CEO of Air Liquide South Africa, described the initiative as a milestone in fulfilling the company’s public interest commitments following its 2021 acquisition of Sasol’s air separation units.
“Our goal is to ensure that as the hydrogen economy grows, South Africa is equipped with a home-grown workforce and a competitive network of local suppliers,” Magadla said.
Irshaad Kathrada, the CEO of the LSF, emphasised the importance of localisation in building a competitive supply chain from the ground up.
“By focusing on empowering South African companies, we are ensuring that the benefits of the energy transition are shared broadly, fostering inclusive growth and industrial capacity,” Kathrada said.
The project comes at a time when South Africa is grappling with declining manufacturing output and employment. Manufacturing’s contribution to GDP has fallen from above 22% in the early 1990s to around 12–13% today, while employment in the sector has dropped significantly since 2008.
Its modular design will allow locally produced hydrogen components to be developed, tested and standardised, creating opportunities for South African firms to participate — and potentially compete globally — in emerging hydrogen markets.
As global demand for clean hydrogen accelerates, South Africa is seeking not only to produce green hydrogen, but also to localise the technologies, skills and industrial capabilities underpinning the sector.
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German TSO commissions 110km hydrogen pipeline to supply steelmaker
German transmission system operator (TSO) Ontras Gastransport has commissioned two firms to build hydrogen pipelines supplying steelmaker Salzgitter. Mannesmann Grossrohr (MGR) and Mannesmann Line Pipe (MLP), both Salzgitter subsidiaries, will construct almost 110km of pipeline for Salzgitter’s green steel operations.
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The firms will complete separate sections of the long-distance FGL 702 pipeline between Bad Lauchstädt and Salzgitter, which will eventually carry green hydrogen for use in Salzgitter’s Salcos direct reduced iron (DRI) project.
https://hydrogeneurope.eu/german-tso-commissions-110km-hydrogen-pipeline-to-supply-steelmaker/
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Hyundai commits $6b build hydrogen, AI, and solar innovation hub
A 200 MW hydrogen plant will produce clean energy. Hyundai Motor Group has announced plans to invest $6b (KRW9t) to establish a high-tech innovation hub in Saemangeum, Gunsan, targeting hydrogen production, artificial intelligence, and renewable energy.
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The project is backed by the South Korean government and Jeonbuk Province.
The hub will feature a 200 MW PEM electrolyser plant producing clean hydrogen from local renewable energy sources.
The facility will supply hydrogen to buses, trams, and other mobility solutions whilst laying the foundation for a fully integrated hydrogen ecosystem, including storage, distribution, and refueling infrastructure. Hyundai plans to expand electrolyzer capacity nationwide to 1 GW.
To power the complex sustainably, the group will develop a gigawatt-scale solar energy portfolio by 2035, building on its existing 99 MW solar facility.
The solar infrastructure will provide reliable power for AI data centers and other energy-intensive operations while advancing Hyundai’s carbon neutrality goals.
AI technologies will be applied across robotics, smart city systems, and energy management, integrating clean energy and mobility solutions.
Construction is scheduled to begin on the AI data center and solar power infrastructure in 2027, with completion expected by 2029. The PEM electrolyser plant will also break ground in 2027, start operations in 2029, and undergo phased capacity expansion thereafter. The robotics cluster is planned to start construction in 2028 and finish in 2029.
Hyundai said it is engaging with funding partners, including the Korea Development Bank, to structure financing for the project.
https://asian-power.com/news/hyundai-commits-6b-build-hydrogen-ai-and-solar-innovation-hub
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