NGS’ NG/LNG SNAPSHOT October 1-15, 2025
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NATIONAL NEWS
City Gas Distribution & Auto LPG
Natural Gas Discovered In Andaman Basin, Says Puri
Union Petroleum Minister Hardeep Singh Puri has announced the discovery of natural gas in the Andaman basin, validating long-held beliefs that the Andaman Sea holds significant hydrocarbon reserves. In a social media post, Puri described the find as “an ocean of energy opportunities,” confirming the occurrence of natural gas in the Sri Vijayapuram-2 well, located 17 km from the east coast of the Andaman Islands at a water depth of 295 metres and target depth of 2,650 metres. Initial production testing between 2,212 and 2,250 metres confirmed the presence of natural gas with intermittent flaring. Samples transported to Kakinada were tested and found to contain 87 per cent methane. While the size and commercial viability of the reserves will be verified in the coming months, Puri said the discovery establishes the presence of hydrocarbons in the basin, consistent with similar finds stretching from Myanmar to Indonesia.
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He further noted that under the National Deep Water Exploration Mission, announced by Prime Minister Narendra Modi on Independence Day, several deepwater exploration wells are planned across India’s offshore basins. The Minister emphasised that this discovery is a milestone for India’s energy security, supporting the nation’s ambition to expand domestic hydrocarbon exploration in coordination with global experts.
Prime Minister Modi has termed the mission “Samudra Manthan,” reflecting India’s drive towards self-reliance in the energy sector.
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200K locals along Dwarka E-way await piped gas supply despite payments
Nearly 200,000 residents living across housing societies along the Dwarka Expressway, particularly between Sectors 99 and 115, have been waiting for piped natural gas (PNG) connections for over two years despite repeated appeals to authorities, a delay residents say has forced them to continue relying on gas cylinders, a familiar stopgap in many developing city clusters across India.
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The responsibility for providing the connections lies with Haryana City Gas (HCG), but residents have alleged slow progress, poor communication, and lack of accountability. In contrast, cities like Noida and Delhi have already seen widespread PNG supply, highlighting Gurugram’s lag in implementation, residents alleged.
According to residents, the delay stems from a long-standing dispute between gas distribution companies over licence demarcation in Gurugram. The dispute, which dated back to 2005, was resolved only in 2022, after which the Petroleum and Natural Gas Regulatory Board (PNGRB) assigned HCG responsibility for PNG connections in sectors 99 to 115.
“Initially, HCG made grand promises of excellent service quality and a swift start to PNG connections, but even after a year, many societies along the Dwarka Expressway are still waiting for the service,” said Sunil Sareen, a resident of Emaar Imperial Garden, Sector 102. “ ₹9,500 was collected from each family in our society for the gas supply installation, but the work has been stalled for over a year now,” he added.
The Dwarka Expressway Housing Association (DXP-GDA) said it has filed multiple complaints with both HCG and PNGRB but claimed that they have not received any concrete response thus far. The association compiled a status report on PNG supply across societies in the area. Of the societies surveyed, eight, including Triumph (Sector 104), Kocoon (Sector 109), and Indiabulls Enigma (Sector 110), now have functional gas connections. Another six, such as Emaar Imperial Garden (Sector 102), Puri Emerald Bay (Sector 104), and Raheja Atharva (Sector 109), remain under construction. However, no work has begun in at least 13 societies, including Adani Oyster, Suncity Avenue (Sector 102), and Zara Rossa (Sector 112).
In response to the complaints, Kapil Chopra, chairman, HCG, said the company was actively working to expand the PNG network. “We welcome the residents’ associations to approach the company, and if a significant number of residents are interested in one sector, we can give it priority in supply,” he said.
A senior HCG official added that delays were often due to pending approvals from local authorities, which could take “days to months.” The official also cited “lack of cooperation from some residents” as an obstacle but assured that all registered societies would receive supply in due course.
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BPCL collaborates with Reliance BP Mobility to CGD portfolio
Bharat Petroleum Corporation Limited (BPCL) has formed a strategic alliance with Reliance BP Mobility Limited (RBML) aimed at boosting the City Gas Distribution (CGD) and Compressed Natural Gas (CNG) sales sectors. This landmark partnership highlights BPCL’s ongoing commitment through Project Aspire-an innovative initiative designed to foster future growth and establish a sustainable energy framework for India.
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The official agreement was signed by Rouf Khan (Chief General Manager -Projects & Marketing, Gas, BPCL) and Sanjay Pandita (Head – Gaseous Fuels, RBML), with Shri Subhankar Sen (Director – Marketing, BPCL), Rahul Tandon (Business Head – Gas, BPCL), Sarthak Behuria (Chairman, RBML), and Akshay Wadhwa (CEO, RBML) in attendance.
Speaking on the occasion, Tandon, Business Head – Gas, BPCL, stated, “It is crucial that the end customer receives our molecule, aligning with the broader vision of promoting a gas-based economy. This partnership will enhance our progress towards this national objective.”
Echoing this sentiment, Wadhwa, CEO, RBML, remarked, “RBML outlets attract higher footfall, which will drive increased CNG sales in the area, thereby contributing to the overall goals of India’s gas-based economy.”
This collaboration represents a significant advancement in providing access to cleaner and more affordable fuel alternatives throughout India. It supports the Government of India’s ambition to raise the share of natural gas in the nation’s energy mix from the current 6% to 15% by 2030-highlighting the joint dedication of both organizations to promote sustainable mobility and the adoption of cleaner energy.
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Natural Gas/ Pipelines/ Company News
Natural gas pipeline work in Kathua, Samba, Jammu distts to be completed in December
JAMMU: The ambitious natural gas pipeline project aimed at ensuring an uninterrupted supply of clean energy to industrial and domestic consumers is expected to be completed in all respects in the month of December this year in the districts of Kathua, Samba and Jammu, while the work on the Punjab stretch and the city gas distribution network is still pending.
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Official sources told EXCELSIOR that the work on laying the gas pipeline is progressing at a steady pace, and nearly all the activities in Kathua and Samba districts have either been completed or are in the final stages, whereas work in Jammu district will begin shortly. “If the current pace continues, the work in these districts will be fully completed in December 2025,” the sources added.
The gas pipeline, being executed by GAIL India Limited, seeks to extend the national gas grid to Jammu and Kashmir for the first time. The project will connect the Union Territory with the rest of the country through a reliable natural gas supply network, facilitating clean fuel availability for industries, transport and domestic consumers.
Of the total 78 kilometers of gas pipeline being laid in the three districts, 37 kilometers fall in Kathua, 38 kilometers in Samba and the remaining in Jammu district. The pipeline will terminate along the Ring Road in Jammu district, and from that point, the city distribution network will be laid, sources informed.
“The progress was slowed down by the unprecedented rainfall in the month of August this year, but now the work is progressing well, and in December the entire work will be completed,” the sources said.
However, despite substantial progress in the Jammu region, the pipeline-laying work in the Punjab stretch, a crucial link to bring gas into Jammu, has been delayed due to forest clearance issues. “The alignment of the pipeline passes through forest areas in Punjab and the project was held up for a long time due to pending statutory clearances. The matter has recently been resolved, paving the way for the commencement of work,” the sources informed.
They added that once the Punjab segment is completed, the flow of natural gas into the Jammu network can be operationalized without further delay.
Meanwhile, an oil company, which has been assigned the task of developing the city gas distribution network, has yet to start physical work on the ground. This network is imperative to provide piped natural gas to households.
Sources revealed that although necessary permissions and route surveys have been completed, the actual laying of the city distribution pipelines and setting up of dispensing stations are still pending. “Once GAIL completes the main trunk pipeline, the oil company has to take over the city-level distribution to make the gas available to consumers. The delay in city gas distribution network work may defer the benefits to the end users,” they added.
According to the sources, formal sanction for the extension of the natural gas pipeline to the Kashmir valley has not yet been accorded to GAIL (India) Limited. “It is expected that following the completion of the gas pipeline laying work in Jammu, a decision will be taken about its extension to Kashmir,” they added.
It is pertinent to mention here that natural gas is one of the cleanest modern-day fuels for industrial and domestic use, being efficient and non-polluting. Due to its characteristic clean-burning nature and availability through a pipeline connection-which alleviates the need for local storage and other transportation logistics-natural gas has emerged as the fuel of choice.
The entire pipeline is three-layered polyethylene coated, supplemented by an impressed current cathodic protection system in order to protect the pipeline from external corrosion.
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IGL will explore international markets for business expansion: MD Chatiwal
City gas distribution (CGD) major Indraprastha Gas Limited (IGL) will pass on the benefits of unified tariff regulation and tax reliefs in domestic piped natural gas (PNG) prices to consumers, said managing director (MD) Kamal Kishore Chatiwal, in an interview with Shubhangi Mathur in Delhi. The company said it has 12 geographical areas (GAs) in India across 32 districts in four states. Edited excerpts:
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What is IGL’s capital expenditure plan for the current financial year?
For FY26, we are planning a capex of around ₹2,000 crore which includes around ₹1,400 crore for core business and ₹600 crore for diversification in renewables, compressed biogas (CBG) and liquefied natural gas (LNG). We spent around ₹1,200-1,300 crore last year. The higher capex this year is because we are spending more on diversification and looking at acquisitions. We are also looking at areas internationally for core business expansion. In India, bidding rounds are over and licenses are allotted for all of the areas.
Are you reviewing CNG and PNG prices for consumers?
Our prices have been stable for more than two years. We will definitely pass on the benefits of tariff regulations and taxations, as and when they are implemented. You can expect some relief in domestic PNG prices. Wherever there is headroom, we will also pass on benefits for compressed natural gas (CNG). We had not increased CNG prices in Delhi to maintain market share and consumer confidence even when the administered price mechanism (APM) gas allocation was cut.
How do you plan to navigate lower APM gas allocation for CGD companies?
APM gas share is gradually going to come down to 5-10 per cent in total domestic production. We are getting prepared for that. We are bringing in more operational efficiency, capex efficiency while competing with conventional fuels. Going forward, APM gas prices and international prices will be aligned. We are in discussion with companies to source Regasified-LNG at the price of APM. Currently, APM gas accounts for around 35-36 per cent of our kitty, new well gas is around 10 per cent and 50 per cent is imported gas.
Which sector is expected to drive gas demand in India?
India’s demand in the fertiliser sector is not expected to grow sharply. Power sector consumption fluctuates with respect to peak demand. Meanwhile, most of the refineries have already switched to natural gas wherever they could. The only sector with visible strong growth is CGD because new GAs are coming up. All the 307 geographies have been awarded. In the next two-three years, CGD will become the biggest gas consuming sector.
What is your stand on the proposal to end market exclusivity for CNG infrastructure?
IGL has sought certain clarifications and given some suggestions to the Petroleum and Natural Gas Regulatory Board (PNGRB) in this regard. Moreover, the exclusivity matter is pending before courts. Stakeholders must await the decision of the court before going ahead with implementation.
Growth in LNG as a transport fuel has been limited. What is the key reason?
Critical number of LNG stations need to be set up. CGD entities should be able to provide one station at every 500 kilometres, especially on major highways. Consumers will then have confidence to invest in trucks. The success story of CNG in the National Capital Region (NCR) can be replicated in LNG. We are setting up three LNG stations in the NCR region. One of them is ready to be commissioned while the other two will be functional in the next two-three months. We plan to set up around 50 LNG stations by 2030.
Government mandated CBG blending in natural gas. How has CBG adoption played out for IGL?
The official CBG blending target in natural gas is 5 per cent by FY29. We are targeting 10 per cent blending for us. We have also commissioned one CBG plant in Delhi.
Do you foresee similar resistance for CBG blending as witnessed in ethanol blending with petrol?
Ethanol and petrol are different molecules but with CBG the molecule remains the same — methane. The question is only about the purity of methane. We are ensuring a minimum 97-98 per cent purity of methane. So, we have not faced resistance in blending CBG with gas.
What are IGL’s plans for expansion in renewables?
We do not want to be a big player in renewables. Our main focus is on improving operational efficiency through renewables.
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City Gas Pipeline Damaged in Hindupur Due to Unauthorized Excavation; THINK Gas Swiftly Restores Connections
City gas supply in Hindupur faced a brief disruption after THINK Gas (formerly AG&P Pratham) pipeline was accidentally damaged during unauthorized excavation work carried out for laying an optical Fiber cable Sterlite Technologies Ltd and Quess Corp Ltd on behalf of Bharti Airtel near Housing Board Colony, Hindupur. The emergency response team at THINK Gas swiftly isolated the affected sections and restored gas supply within 10 minutes, ensuring public safety and minimizing inconvenience to residents. While an official police complaint has been lodged by THINK Gas against the responsible party, the company has urged all contractors and civic works agencies to notify the City Municipal authorities or the CGD company in advance through the official ‘Dial Before You Dig’ number – 1800 2022 999.
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The disruption occurred on 23rd September at 02:28 PM when a 125 mm MDPE charged pipeline was damaged near Housing Board Colony, Hindupur during third party excavation works. However, THINK Gas swiftly reached the site and restored the supply.
These incidents underscore the urgent need for all contractors and civic agencies to strictly follow safety protocols before undertaking any road digging or construction work. Public safety and uninterrupted energy supply rely on such responsible action. Under IPC Sections 285 and 336, negligent and unauthorized damage to gas infrastructure is a criminal offense, punishable by up to three years’ imprisonment and fines of up to ₹25 crore.
THINK Gas has built a robust natural gas network in Anantapur and Kadappa region to provide Piped Natural Gas (PNG) to households, businesses, and industries, and Compressed Natural Gas (CNG) for transport. The company urges all citizens and contractors to cooperate in preventing such avoidable safety breaches.
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Hardeep Singh Puri Opens New Indraprastha Gas Limited Office at World Trade Centre, Nauroji Nagar
Addressing the gathering at the inauguration of Indraprastha Gas Limited’s (IGL) new office in Nauroji Nagar, New Delhi, Union Minister of Petroleum and Natural Gas, Hardeep Singh Puri, highlighted India’s remarkable progress in the energy sector over the past decade. He noted that LPG connections have surged from 140 million before 2014 to over 330 million today, the natural gas pipeline network has expanded from 14,000 km to more than 22,500 km, and India has emerged as one of the fastest-growing refining centers worldwide.
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Alongside the office launch, Shri Puri also inaugurated a new Smart Gas Meter Manufacturing plant developed by IGL in collaboration with Genesis Gas Solutions. This facility is set to produce around one million meters annually, including smart and prepaid varieties, starting operations in October 2025. The initiative aims to boost India’s self-reliance in gas meter production and support IGL’s mission to offer customers modern, efficient, and affordable gas services.
Speaking about IGL’s accomplishments, the Minister pointed out the company’s efforts in extending piped natural gas connections to 250 villages in Delhi, bringing clean cooking fuel to over 100,000 rural households. He emphasized that this expansion not only builds infrastructure but also improves quality of life, reduces pollution, and helps bridge the gap between urban and rural areas.
Reflecting on India’s energy transformation, Shri Puri recalled that before 2014, many households struggled to access LPG cylinders. Today, LPG connections cover the entire country, and on the first day of Navratri, 2.5 million new connections were announced under the Pradhan Mantri Ujjwala Yojana, bringing the total beneficiaries under the scheme to approximately 106 million.
The Minister praised IGL, established in 1998, as a significant force in the city gas distribution industry, supplying compressed natural gas (CNG) to vehicles and piped natural gas (PNG) to homes, industries, and businesses. IGL currently operates 956 CNG stations, representing nearly 12% of India’s total, has connected more than 3.07 million households with PNG, and supplies natural gas to thousands of industries and commercial establishments. The company delivers 9.3 million standard cubic meters per day of natural gas and refuels 2.2 million CNG vehicles daily.
Shri Puri also highlighted India’s expanding natural gas pipeline network and expressed optimism about recent discoveries in the Andaman region. He noted that exploration activities slowed between 2006 and 2016 due to global supply assumptions but affirmed that India’s geological potential remains strong, with new finds confirming this outlook.
He further pointed out that India is rapidly increasing its refining capabilities, currently ranked fourth globally and poised to move up to third place with continued growth. This development will enhance the country’s energy security, create jobs, support small and medium enterprises, and boost regional economies.
The Minister acknowledged IGL’s use of advanced technologies such as SAP-ERP, GIS, analytics, business intelligence dashboards, security and vehicle tracking, prepaid billing, chatbots, electronic billing, and automated meter reading. He said these innovations improve efficiency, strengthen operations, and elevate customer service standards in the city gas sector.
Looking ahead, Shri Puri spoke about India’s clean energy future, which will include a mix of biogas, LNG, hydrogen-enriched CNG, and electric vehicle infrastructure. He noted that IGL has already installed EV charging stations at 40 locations and plans to expand further. While electric and CNG vehicles will grow in popularity, he recognized that traditional fuels like petrol will continue to have a role in fast-developing areas like the National Capital Region. Concluding the event, Shri Puri congratulated IGL on its new office, calling it a symbol of the company’s innovation, expansion, and commitment to India’s transition toward cleaner energy.
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ONGC to invest ₹8,110 cr to develop 172 onshore wells in Andhra Pradesh
Oil and Natural Gas Corporation Limited (ONGC) is set to invest Rs 8,110 crore for onshore development and production of oil and gas from 172 wells in eight PML (petroleum mining lease) blocks in Andhra Pradesh. A committee under the Ministry of Environment, Forest and Climate Change has recommended Environmental Clearance for the project in a meeting held last month.
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The estimated project cost is Rs 8110 crore. Capital cost of EMP (Environment Management Plan) would be Rs. 172 crore and recurring cost for EMP would be Rs. 91.16 Crores per annum. Industry proposes to allocate Rs. 11 crores for commitments made in Public Hearing, Expert Appraisal Committee said in the minutes of the meeting.
While recommending the EC, the committee directed the ONGC to comply with all the environmental protection measures and safeguards proposed in the documents submitted to the Ministry.
All the recommendations made in the EIA/EMP in respect of environmental management, and risk mitigation measures relating to the project shall be implemented.
It further said, as committed, no well would be set up within 10 km from the eco-sensitive area of Coringa Wildlife sanctuary as per the NOC issued in May this year, and no pipelines or its part shall be laid in the Forest land/Protected Area without prior permission/approval from the Competent Authority.
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MNGL increases CNG price by 1 per Kg
Pune: The Maharashtra Natural Gas Limited (MNGL) increased the prices of compressed natural gas (CNG) in Pune city, Pimpri-Chinchwad and adjoining areas of Chakan, Talegaon and Hinjewadi by Rs 1 per Kg with effect from midnight of Oct 1, 2025.
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Now, the price stands at Rs 90.75 per kg
MNGL, in its official statement, stated that the prices were increased due to a rise in the input cost of natural gas for the CNG segment. “Despite this marginal revision, CNG still offers attractive savings of around 47% in comparison to petrol and around 24% compared to diesel at current price levels in Pune city for the passenger car segment and around 25% for autorickshaws,” the statement said.
The officials of MNGL said the prices of domestic piped natural gas (PNG) will remain unchanged.
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L&T bags ₹15,000 crore order for natural gas liquids plant in Middle East
Larsen & Toubro’s (L&T’s) Hydrocarbon Onshore business (L&T Energy Hydrocarbon Onshore) has won an order worth over Rs 15,000 crore for setting up natural gas liquids plant-related facilities in the Middle East.
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L&T wins major international energy infrastructure contract
The company secured the order in consortium with Greece-headquartered Consolidated Contractors Group S.A.L. (Offshore) (CCC). The scope of work encompasses engineering, procurement, construction, installation, and commissioning of a natural gas liquids (NGL) plant and allied facilities for processing Rich Associated Gas (RAG). This also includes all associated utilities, off-site facilities, and integration with existing infrastructure.
S N Subrahmanyan, Chairperson and Managing Director (MD), L&T, said, “The ultra-mega order reaffirms L&T’s position as a trusted partner in delivering mega energy infrastructure. It underscores our growing global footprint and ability to execute projects of high complexity in partnership with leading players like CCC.”
Under the consortium arrangement, L&T, as the lead partner, will be responsible for engineering and procurement, while CCC will handle construction activities.
Project to process rich gas and produce value-added outputs
The RAG sourced from offshore and onshore oil fields will be treated at the plant to remove impurities such as hydrogen sulphide, carbon dioxide, and water. The process will produce value-added products, including lean sales gas, ethane, propane, butane, and hydrocarbon condensate.
Subramanian Sarma, Deputy MD and President, L&T, said, “This project is not just about scale but also about bringing in advanced engineering, long-term reliability measures, and complex brownfield interfaces to deliver value-added products. The order strengthens L&T’s role in shaping energy security while deepening relationships with oil and gas companies through world-class execution.”
L&T Energy Hydrocarbon continues to build global footprint
LTEH Onshore is one of India’s largest EPC businesses, delivering comprehensive solutions across the upstream, midstream, and downstream hydrocarbon sectors. Across geographies, it has executed refinery expansions, petrochemical complexes, gas processing plants, fertiliser units, LNG terminals, and cross-country pipelines.
On Thursday, L&T’s shares on the Bombay Stock Exchange closed at Rs 3,769.35 per equity share, compared to the previous close of Rs 3,728.
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Tata Power arm to invest ₹1,200 cr to develop 80 MW FDRE renewable project
An FDRE (Firm and Dispatchable Renewable Energy) project integrates advanced solar, wind and battery storage systems to enable reliable energy dispatch during peak demand, thereby strengthening grid stability. The time period for project execution is 24 months, Tata Power, the parent company of TPREL, said in an exchange filing.
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On the broad size of the order, the company said the capex is about Rs 1,200 crore.
In a separate statement, Tata Power said the project is expected to generate approximately 315 million units (MUs) of electricity annually, mitigating over 0.25 million tons of carbon dioxide emissions per year.
A key feature of this initiative is the commitment to a 4-hour peak power supply, ensuring at least 90 per cent availability during peak demand hours to support the growing energy needs of Tata Power Mumbai Distribution.
This project will play a pivotal role in helping Tata Power Mumbai Distribution meet its Renewable Purchase Obligation (RPO), as mandated by the State’s Regulatory Commission.
Once commissioned, the clean energy generated from this project will be seamlessly integrated into Tata Power’s Mumbai distribution network, enabling the delivery of reliable, low-emission electricity to around 8 lakh customers across residential, commercial, and industrial sectors.
With this addition, TPREL’s total renewable utility capacity is 11.3 GW (PPA capacity is 9.4 GW, including 5.7 GW projects under various stages of implementation and its operational capacity stood at 5.6 GW, which includes 4.6 GW solar and 1 GW wind.
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Innovation, Green Energy Drive India’s Infrastructure Growth, Gadkari Says
India’s rapid infrastructure expansion is being powered by innovation, green energy, and industry partnerships, Union Minister for Road Transport and Highways Nitin Gadkari said on Thursday at the 120th Annual Session of the PHD Chamber of Commerce and Industry (PHDCCI).
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Speaking at Bharat Mandapam, Gadkari highlighted India’s economic transformation under Prime Minister Narendra Modi, noting that the country is on track to become a five-trillion-dollar economy by 2027 and a developed nation by 2047. “Economic growth alone is not enough; it must go hand in hand with environmental protection and a value-based social system,” he said.
Gadkari emphasised the growth of India’s automobile sector, now the world’s third largest with a turnover exceeding Rs22 lakh crore, and highlighted advances in biofuels, ethanol, methanol, biodiesel, LNG, and hydrogen. He cited ethanol production from maize as a key driver of rural incomes, circulating more than Rs45,000 crore in Uttar Pradesh and Bihar.
The minister also pointed to major expressway projects, including Delhi–Mumbai, Delhi–Dehradun, Delhi–Amritsar–Katra, and Bengaluru–Chennai, which are expected to reduce logistics costs from 16 per cent of GDP to single digits by the end of 2025, while dramatically cutting travel times. Gadkari stressed the importance of innovation and R&D, urging industry to reinvest 3–4 per cent of profits to boost global competitiveness.
He added that India’s GDP has grown from Rs 107 lakh crore in 2014 to Rs 331 lakh crore in 2024–25, exports have risen 76 per cent, and foreign direct investment inflows have crossed Rs 60 lakh crore. Gadkari concluded that sustainable development requires collaboration between government, industry, and citizens.
PHDCCI President Hemant Jain credited Gadkari with turning stalled projects into “models of speed and transparency,” reinforcing confidence in India’s growth trajectory.
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NTPC, Gujarat govt partner to explore conventional and renewable energy
State-owned power giant NTPC Ltd on Thursday said that it has inked an initial pact with the government of Gujarat to explore opportunities in both conventional and non-conventional energy sectors. The Memorandum of Understanding (MoU) exchange took place in the presence of Bhupendrabhai Patel, Chief Minister of Gujarat; Pralhad Joshi, Union Minister of New & Renewable Energy; Kanubhai Desai, Minister for Finance, Energy and Petrochemicals, Gujarat and other senior dignitaries, a company statement said.
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The agreement, signed during the Vibrant Gujarat Regional Conference held in Mehsana, Gujarat, aims to explore opportunities in both conventional and non-conventional energy sectors, the statement said.
NTPC is India’s largest integrated power utility, contributing one-fourth of the country’s power requirements and has an installed capacity of over 83 GW, with an additional capacity of 30.90 GW under construction, including 13.3 GW of renewable energy capacity.
The company is committed to achieving 60 GW of renewable energy capacity by 2032, strengthening India’s net zero carbon emission goal.
With a diverse portfolio of thermal, hydro, solar and wind power plants, NTPC is dedicated to delivering reliable, affordable, and sustainable electricity to the nation.
NTPC has also ventured into various new businesses, including electric mobility, battery storage, pumped hydro storage, waste-to-energy, nuclear power and green hydrogen solutions.
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Mahanagar Gas Limited Conducts Mock Drill At Taloja CNG Station To Test Emergency Preparedness
According to an official, mock drill was carried out in collaboration with multiple agencies including the Taloja Fire Brigade, local Police authorities, Traffic Police, Mutual Aid Response Group (MARG), District Disaster Management Cell (Raigad), Taloja Manufacturer’s Association, Directorate of Industrial Safety and Health (DISH), and GAIL authorities.
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Mahanagar Gas Limited (MGL) conducted a comprehensive mock drill at its City Gate Station (CGS) in Taloja CNG Refueling Outlet (RO) recently to reaffirm the preparedness and responsiveness of its team in managing crisis situations and to comply with regulatory requirements.
“The exercise simulated a critical gas leakage leading to a fire outbreak in a CNG Transport Vehicle (CTV) during refueling at the CNG RO, including an emergency scenario involving the associated piping system. The drill tested the response time and appropriateness of actions taken by the on-ground team” said an official.
According to an official, mock drill was carried out in collaboration with multiple agencies including the Taloja Fire Brigade, local Police authorities, Traffic Police, Mutual Aid Response Group (MARG), District Disaster Management Cell (Raigad), Taloja Manufacturer’s Association, Directorate of Industrial Safety and Health (DISH), and GAIL authorities. Each agency played a vital role in executing coordinated efforts to handle the simulated emergency.
Following the drill, representatives from the Fire Brigade, Police, and MARG provided valuable feedback and suggestions to improve future response strategies. A senior official from the District Disaster Management Cell was also present at the site to observe the proceedings.
“This drill reinforces MGL’s continuous efforts to ensure safety and swift response in emergency situations, safeguarding personnel, infrastructure, and the community” official further added.
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Policy Matters/ Gas Pricing/ Others
Ministry of Petroleum and Natural Gas invites applications for CMD, BPCL
The Ministry of Petroleum and Natural Gas (MoPNG) has invited applications for the post of Chairman and Managing Director (CMD) of Bharat Petroleum Corporation Limited (BPCL). This comes more than six months after a search-cum-selection committee was constituted to identify a suitable candidate for the top post.
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Earlier, the Public Enterprises Selection Board (PESB) had interviewed a dozen candidates, including BPCL Director (Finance) Vetsa Ramakrishna Gupta and Director (Refineries) Sanjay Khanna, but found none suitable for the role.
As per the official notification, the last date and time for receipt of complete applications, duly forwarded to MoPNG through email, is 17:30 hours on October 21, 2025. The coveted post of CMD of BPCL is lying vacant since April 30, this year.
https://indianpsu.com/oil-ministry-invites-applications-for-cmd-of-bpcl-last-date-21-oct-2025/
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Union Minister Hardeep Singh Puri launches IGTL smart gas metre facility
Hardeep Singh Puri “This world-class smart gas metre manufacturing plant not only strengthens India’s journey towards Atmanirbhar Bharat but also opens up significant export opportunities for Indian industry. It will help make IGL and other City Gas Distribution companies self-reliant in sourcing critical metering infrastructure from IGTL, while also creating a platform for India to serve global markets.”
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Inauguration highlights
The inauguration at the IGL Corporate Office in New Delhi was attended by Secretary MoPNG Pankaj Jain, senior officials from GAIL, IGL, and BPCL, as well as IGTL directors including Sanjeev Bhatia, Dr. Vikas Garg, Deepchand Jain, and Dr. Sundeep Dhawan.
Leadership perspective
CEO of IGTL, Dr Anshumali Bhushan, said, “We are proud to commission this facility with the support of our partners IGL, GAIL, BPCL, and Vikas Life Care Ltd. This milestone ensures India’s domestic needs are met with world-class metres while also allowing us to compete globally as an exporter of advanced smart gas metering technologies.”
Strategic impact and future plans
IGTL, a joint venture involving Indraprastha Gas Ltd (IGL), Bharat Petroleum Corporation Ltd. (BPCL), and promoted by GAIL (India) Ltd and the Government of Delhi, focuses on producing innovative smart gas meters tailored for India’s gas usage patterns. Built to Industry 4.0 standards, the facility incorporates advanced robotics and digital manufacturing, producing metres designed to be durable for around 10 years.
With a target of expanding from 12 million to 12.5 million PNG households by 2030, this initiative aims to secure domestic energy supply, minimise import reliance, and enhance India’s position in the global metering market, particularly in South Asia, Southeast Asia, and the Middle East. Furthermore, it will contribute to job creation and workforce upskilling and foster consumer trust through transparent and durable metering solutions.
https://www.manufacturingtodayindia.com/igtl-smart-gas-metre-facility
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Renewable energy panel recommends Solar Parks in New Industrial Policy
Ludhiana: Members of the Renewable Energy Sector Committee, formed by the Punjab government to shape the upcoming industrial policy, are preparing to submit a comprehensive set of recommendations aimed at accelerating the state’s clean energy transition. The committee is expected to meet industry minister Sanjeev Arora soon to present its proposals.
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Pankaj Sharma, president, Association of Trade and Industries Undertakings (ATIU) and committee member, emphasised the need to declare renewable energy as a thrust sector in Punjab. “If Punjab wants to remain competitive, it must prioritise renewable energy,” Sharma said. He added that the committee is finalising its recommendations, which will be submitted to the govt shortly.
A key proposal is the creation of a dedicated land allocation policy for solar parks. Sharma pointed out that many industrialists from Punjab are setting up solar projects in states like Madhya Pradesh and Gujarat, where they sell power at Rs 3 per unit but are forced to buy it back in Punjab at Rs 9 to Rs 10 per unit. Introducing open access and flexible land leasing models would make Punjab more attractive for renewable energy investments, they said.
The committee is also advocating a capital subsidy scheme, noting that setting up 1 MW solar power requires an investment of Rs 4 to Rs 7 crore. To achieve Punjab’s estimated 5 to 6 GW solar potential, the state would need investments ranging from Rs 20,000 to Rs 35,000 crore. “Without financial support, this scale of development is difficult,” Sharma said.
Another major recommendation is to promote solar manufacturing within Punjab. Currently, most solar panels and inverters are sourced from outside the state. Establishing a local solar manufacturing cluster would strengthen supply chains and generate employment, Sharma added.
The committee is also pushing for regulatory reforms, including increasing rooftop solar capacity for industries from the current 63% of sanctioned load to 90%, and enabling seamless transfer of security deposits when industrial units change ownership.
Beyond solar energy, Punjab’s extensive canal network is being highlighted as a potential resource for small hydro projects. The committee suggests setting up 1 to 5 MW canal-based hydro plants, which could boost clean energy generation at relatively low cost while creating rural jobs.
Rishabh Oswal, another committee member, stressed the importance of allowing inter-state power transfer. “If companies from Punjab set up solar plants in states with better solar potential, they should be allowed to transfer power back to Punjab,” he said. He also called for government assistance in land leasing for solar park development.
Despite having nearly 300 sunny days a year, Punjab’s installed solar capacity stands at just 1.2 GW, accounting for only 1.5% of India’s total 82 GW base. The Punjab Renewable Energy Development Agency (PEDA) had targeted 4 GW by 2022 but has achieved less than one-third of that. In contrast, states like Rajasthan (18 GW), Gujarat (14 GW), and Karnataka (16 GW) have surged ahead.
“If these reforms are implemented, Punjab can emerge as a renewable energy leader in North India,” Sharma concluded.
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CNG Price Increased In Pune, Pimpri-Chinchwad & Industrial Hubs From October 2 Midnight
Pune: The retail price of Compressed Natural Gas (CNG) for vehicular use in Pune city, Pimpri-Chinchwad, and adjoining industrial and IT hubs such as Chakan, Talegaon, and Hinjawadi, has been revised upward by ₹1 per kg. With effect from midnight of October 2, the new CNG retail selling price stands at ₹90.75 per kg inclusive of taxes. Officials have attributed the hike to a rise in the input cost of natural gas used for the CNG segment.
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While announcing the revision, the distributor emphasised that despite the increase, CNG remains significantly cheaper compared to conventional fuels. Currently petrol is retailing at around ₹103.99 per litre and diesel at about ₹90.52 per litre in Pune. Passenger cars running on CNG continue to enjoy savings of nearly 47% in comparison with petrol and about 24% in comparison with diesel. For autorickshaws, the savings are estimated at around 25%. The price of Domestic Piped Natural Gas (PNG), which is used in households, will remain unchanged.
This price adjustment comes at a time when energy markets are experiencing volatility due to global crude fluctuations and exchange rate movements. These factors have affected India’s fuel pricing in recent months. In April this year, the Union government raised the special additional excise duty on petrol and diesel by ₹2 per litre to bolster revenues. This happened despite global oil prices softening.
At the state level, Maharashtra introduced a 1% increase in the one-time vehicle tax on private CNG and LNG vehicles from July 1. This included high-end cars as well. These policy measures, coupled with higher input costs, have added pressure on energy companies.
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Govt to set up 2000 MWh battery storage plant for solar power in Rajasthan
MNRE approved the state government’s request for a four-hour battery cycle, which is more suitable for Rajasthan where solar resources are rich for long-duration charging and the peak-hour power demand is higher. In a bid to meet the non-solar and peak hour demand in the evenings, the energy department floated tenders for a 2,000 MWh (megawatt hours) battery storage plant, adding to its 4,000 MWh capacity across two projects already under development.
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On Wednesday, the ministry of new and renewable energy (MNRE) approved the state government’s request for a four-hour battery cycle, which is more suitable for Rajasthan where solar resources are rich for long-duration charging and the peak-hour power demand is higher, compared to other states.
“With battery storage, the government is trying to supply cheaper solar power even during evening and morning hours, helping us to become self-reliant. This will reduce our dependence on exchange power which is costlier in the evenings and other peak hours when solar power is not available,” said Ajitabh Sharma, principal secretary (Energy).
With solar energy now being generated from various sources, including industrial grid-scale, rooftop plants, and Kusum projects, the energy department is working to map the cumulative generation and consumption patterns to better manage renewable power in the state and store the excess power generated during the day.
“Though this is the final lot of our current plan for setting up 6,000 MWh of BESS in Rajasthan, more battery storage capacity will come as generation, consumption, and grid stability requirements crystallise,” added Sharma.
A Battery Energy Storage System (BESS) stores electrical energy in rechargeable batteries for later use, stabilises the grid, and supplies power when it is required. These systems charge from renewable sources like solar and wind, then supply energy during peak demand or low generation periods at lower costs.
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LNG Use / LNG Development and Shipping
India Looks to Buy More LNG After Prices Fall to 16-Month Low
India’s liquefied natural gas buyers are looking to procure shipments after spot prices of the industrial and power plant fuel fell to the lowest in more than a year. Indian Oil Corp. released a tender to purchase supply for end-October to early-November delivery, while rival importers Gujarat State Petroleum Corp. and GAIL India Ltd. are expected to soon follow, according to traders with knowledge of the matter. Buyers are taking advantage of the weak prices to refill storage, and feed rising demand from fertilizer producers, the traders said.
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Asian LNG prices fell to the lowest level since May 2024 on Wednesday on weak demand from top buyers China and Japan. That presents an opportunity for Indian importers, which typically ramp up spot purchases when LNG becomes cheaper than alternative fuels.
Shipments for delivery to India are trading around the low-$10 per million British thermal units range, according to traders. A surge in buying could reverse declining deliveries to India, which are down about 9% so far this year from the same period in 2024.
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LNG demand for ships set to at least double by 2030 globally
Massive LNG export projects in the US and Qatar are expected to cause a supply glut by 2030, reducing prices and improving its competitiveness against conventional and more-polluting fuel oil. Demand for liquefied natural gas as a marine fuel will at least double by 2030 as abundant supply and rising emissions regulations spur orders for ships that can run on it, industry executives said. Massive LNG export projects in the US and Qatar are expected to cause a supply glut by 2030, reducing prices and improving its competitiveness against conventional and more-polluting fuel oil.
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LNG is pulling ahead of other fuels in decarbonising shipping, which accounts for nearly 3 per cent of emissions, as supply and infrastructure hurdles cloud the outlook for cleaner alternatives methanol and ammonia.
“Owners ultimately will choose the fuel that gives you the lowest cost,” said Tuomas Maljanen, associate director for LNG and new energy at shipbroker Fearnleys.
“LNG is great because the infrastructure is there. It’s readily available … maybe later on it’s going to be, hopefully, quite cheap as well,” he added.
Singapore, the top bunkering hub, led global LNG bunkering activity in the third quarter, followed by China and the Netherlands, according to consultancy Rystad Energy, and it plans to issue additional bunker supply licences.
Global LNG bunkering volumes could surpass 4 million tons by end-2025 and double by 2030, said Jo Friedmann, senior vice president of supply chain research at Rystad Energy.
French energy major TotalEnergies expects global LNG and bio-LNG bunker demand to surge to 15 million tons by 2030.
Some 781 dual-fuelled ships can now use LNG, according to ship certifier DNV.
“Based on today’s orderbook, the number of vessels will be 1,417 by 2030, but we expect this to increase as new orders are confirmed,” said Kristian Hammer, product manager AFI & senior consultant at DNV.
Immediate reduction
Refuelling with LNG reduces emissions from fuel oil by 19 per cent on a “well-to-wake” basis, which refers to emissions from extraction to usage, according to Mitsui O.S.K. Lines., which owns the second largest shipping fleet.
It operates 15 LNG dual-fuelled vessels and has an additional 42 on order.
“Until zero or near-zero fuels are widely available, LNG remains a realistic decarbonisation option for shipping in terms of availability, cost-effectiveness, and safety,” the company said.
Danish shipping giant Maersk, which until last year focused only on green methanol as an alternative fuel, has ordered 20 LNG dual-fuelled container ships for delivery between 2028 and 2030.
TotalEnergies expects LNG to outpace other alternative bunker fuels methanol and ammonia after 2030.
“Renewable methanol and ammonia production remain in their infancy, with limited bunkering infrastructure and a lack of economic competitiveness against conventional fuels that need to be addressed before scalable adoption is possible,” it said.
Regulations
Europe’s FuelEU regulation, which took effect this year, limits fuel carbon intensity for ships calling on ports there and is expected to drive adoption of LNG bunkering.
This month, an International Maritime Organization committee will vote on a rule drafted in April that imposes emissions fees on ships that breach it and rewards vessels burning cleaner fuels from 2028. However, the US rejected the deal and a group of top shipping companies are demanding changes.
“Until the IMO regulations take effect, LNG-bunkering activity remains highly sensitive to LNG bunker prices, especially for vessels operating on non-EU routes,” said Rystad’s Friedmann.
LNG bunker prices were on average $247 per metric ton higher than marine fuel in the first nine months of this year, S&P Global data showed, though excess LNG supply set to come online towards the end of the decade is widely expected to pressure prices.
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Oil India, Mahanagar Gas ink pact to explore LNG and clean energy opportunities
Oil India Ltd (OIL), a Maharatna public sector enterprise, and Mahanagar Gas Ltd (MGL) have signed a Memorandum of Understanding (MoU) to collaborate on opportunities across the liquefied natural gas (LNG) value chain and emerging clean energy segments.
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The agreement was signed on October 6, 2025, by senior executives from both companies in the presence of OIL’s Director (Operations) and Director (HR), and MGL’s Managing Director.
“The collaboration will focus on assessing technical and commercial viability of LNG in the heavy-duty transport segment and on exploring projects in clean energy. Our objective is to take feasible pilots to commercial scale,” said OIL’s Director (Operations).
MGL’s Managing Director added, “This collaboration with OIL will help accelerate adoption of cleaner fuels in the long-haul transport sector. It will enable corporates to move towards greener logistics solutions and contribute to reducing the overall pollution footprint.”
The tie-up comes as both companies expand their presence in the natural gas ecosystem. OIL has outlined an ambitious plan to ramp up gas production while advancing its clean energy roadmap. MGL, meanwhile, has already ventured into LNG retailing and continues to explore new clean fuel initiatives.
Shares of Oil India closed 1.34% higher at ₹420.25 on the NSE on Monday.
Separately, the state-run firm expects the $20-billion TotalEnergies-operated Mozambique LNG project—where it holds a stake—to resume development by the end of this year, after being halted in 2021 due to militant attacks.
In September, OIL also signed an MoU with GAIL (India) to strengthen collaboration across the natural gas value chain and expand access to cleaner energy.
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Energy minister reviews LNG terminal expansion in Aqaba
AMMAN — Minister of Energy and Mineral Resources Saleh Kharabsheh on Saturday toured the Sheikh Sabah Al Ahmad Liquefied Natural Gas (LNG) Terminal in Aqaba to review ongoing development works at the facility. Kharansheh said the terminal represents a vital pillar in the Kingdom’s efforts to secure a sustainable and resilient energy system, according to a ministry statement.
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Kharabsheh also held a meeting with Project Manager Omar Badoor from the Aqaba Development Corporation and the contractor, in the presence of National Electric Power Company (NEPCO) Director General Sufian Bataineh, Jordan Oil Terminals Company (JOTC) Logistics Director Ashraf Rawashdeh, and Oil and Gas Directorate Director at the ministry, Iman Awad.
During the meeting, he was briefed on the project’s latest progress and developments and discussed the challenges and obstacles affecting its implementation.
The project aims to preserve the option of importing liquefied natural gas (LNG) for power generation and industrial use, as a strategic measure to ensure a continuous energy supply in case any of the current sources are disrupted. It also contributes to lowering electricity generation costs.
The Aqaba Development Corporation, in cooperation with the Ministry of Energy and the National Electric Power Company (NEPCO), is overseeing the implementation of the project. It includes the construction of an onshore regasification unit (ORU) with a capacity of up to 700 million cubic feet per day, along with the replacement of the current floating storage and regasification unit (FSRU) with a new floating storage unit (FSU).
The project is being financed through two concessional loans, the first amounting to KD 18.2 million from the Kuwait Fund for Arab Economic Development, and the second valued at KD 21 million from the Arab Fund for Economic and Social Development.
The tender for the construction of the onshore regasification unit was awarded to a joint venture of AGP International Holdings Pte Ltd, Gas Entec Co. Ltd, and Issa Haddadin& Partner at a cost of $125 million. The project is expected to be completed within 22 months of its commencement and to enter service in September 2026.
https://jordantimes.com/news/local/energy-minister-reviews-lng-terminal-expansion-in-aqaba
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Electric Mobility/ Hydrogen/Bio-Methane
TKIL, SoHHytec to Build Green Hydrogen Plant in India
The Indian REITS Association (IRA) has become a member of the Global REIT Alliance, a coalition representing the global Real Estate Investment Trust (REIT) sector. The alliance, launched at the European Public Real Estate Association’s 2025 ReThink conference in Stockholm, aims to promote cross-border cooperation, policy dialogue, and market standardisation for the growth of REITs as an investment asset class.
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The Global REIT Alliance, which includes members from 24 countries, focuses on promoting global awareness of securitised real estate, supporting sustainable investment, providing industry benchmarks, improving access to market data, and fostering collaboration among REIT markets.
Preeti Chheda, Executive Committee member of IRA and CFO of Mindspace Business Parks REIT, highlighted that the membership will facilitate knowledge exchange with international peers and enhance the global integration ofIndia’s REIT market. Peter Verwer, spokesperson for the Alliance, said India’s participation brings perspective from a rapidly growing market.
Established in 2023 under the guidance of the Securities and Exchange Board of India, IRA’s founding members include Brookfield India Real Estate Trust, Embassy Office Parks REIT, Mindspace Business Parks REIT, and Nexus Select Trust.
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Adani Green Energy shares in focus amid Andhra Pradesh transmission fee row in Rs 7,000 MW solar deal
Adani Green share price: Adani Green Energy’s Rs 7,000 MW solar supply deal with Andhra Pradesh faces hurdles over transmission fee waivers, potentially delaying power offtake, while the company navigates ongoing regulatory and legal challenges in India and abroad. Shares of Adani Green Energy are expected to be in focus on Friday, October 3, as its Rs 7,000 MW solar power supply agreement with the state of Andhra Pradesh faces fresh hurdles.
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The deal, already under the shadow of a US bribery investigation, has run into additional complications over demands by the state government to waive transmission charges, according to a Reuters report.
According to the report, Andhra Pradesh has sought guarantees that the central-mandated transmission fee, which could increase the cost of solar power by about 40%, will be waived—an ask that is difficult to fulfil legally.
The fee is embedded in central regulations and would require intervention at a policy level to be modified or waived.
The development could potentially delay or impact the offtake under a 2021 agreement signed by Adani Green, Andhra Pradesh, and the Solar Energy Corporation of India (SECI)—a government entity tasked with ensuring all contractual terms are adhered to.
Since April, Adani has reportedly sent multiple letters to the Andhra Pradesh government urging it to begin drawing power as per the agreement.
In its most recent correspondence, Adani Green informed the state that it is ready to supply 4,312 MW of solar power. The total agreement covers 7,000 MW of solar generation, making it one of the largest renewable power supply deals in the country.
The situation adds to Adani Green’s ongoing operational challenges, as the company navigates regulatory and legal complexities both in India and abroad.
Adani Green shares closed 2.8% higher at Rs 896.15 on the BSE on Wednesday.
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Karnataka Bio-Energy Board plans to set up retail outlets for biodiesel sale
The Dasara exhibition this year showcased several social welfare programmes implemented by all departments of the Karnataka government. In stalls set up on the exhibition premises, the departments aim to spread awareness and enable the people of the State to benefit from various government schemes, with both informative displays and live demonstrations.
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Giving priority to new and renewable energy resources, the State has already made achievements in solar and wind energy. Now, similar emphasis has been laid on the bio-energy sector, with planning and implementation of schemes that are expected to further strengthen the field.
The Karnataka State Bio-Energy Development Board has set up a stall called the ‘Bio-Energy Pavilion’ to provide information and demonstrations on projects taken up and shed light on the future roadmap in the bio-energy sector. Board Chairman S.E. Sudheendra, along with Dasara Exhibition Authority Chairman Ayub Khan, inaugurated the stall.
The State government has recently appointed the Board as the nodal agency for the sale of Biodiesel B100, and has issued orders and guidelines to facilitate the establishment of retail outlets for open sales, Mr. Sudheendra said.
An agreement has also been signed with the Karnataka Exhibition Authority to work on waste collection, bio-fuel production, and distribution in Mysuru, and plans are under way to produce and distribute biodiesel and compressed biogas in the coming days, he informed.
Within a few months, there will be a comprehensive transformation in the bio-energy sector, creating a favourable environment for investors, Mr. Sudheendra explained.
Mr. Sudheendra lauded the State government for initiating various incentives and subsidies to encourage bio-energy production and expressed hope that these measures will soon be implemented.
With the support of the exhibition, the Board aims to introduce the entire spectrum of the bio-energy sector to stakeholders, who in turn are expected to join hands in areas like raw material supply, production, and distribution, thereby playing a significant role in the country’s energy production, he added.
The Board’s Managing Director Shivashankar L., Deputy Conservator of Forests Lohith B.R., Hunsur Social Forestry Deputy Conservator of Forests Fayaz, Project Consultant Dayananda G.N., NIE College BRIDC Centre Coordinator Shyam Sundar, and others were present.
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ANERT to make Kerala a key player in green hydrogen economy
With its 2040 renewable energy transition goal and 2050 carbon neutrality target, the Agency for New and Renewable Energy Research and Technology (ANERT) aims to position Kerala as a frontrunner in India’s green hydrogen economy. The Green Hydrogen Policy, currently before the Cabinet for release by the end of FY 2025–26, represents a comprehensive approach that integrates policy enablers, capacity-building programs, and on-ground pilot projects, Harshil R Meena, CEO, ANERT said.
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The State with its extensive coastline, world-class ports, skilled workforce, and strong renewable energy potential, offers immense opportunities to take the lead in green molecules. “Our cost target is to drive green hydrogen prices toward 30 per cent reduction by 2030 through demand creation, open access reforms, and strategic incentives”, he said.
The policy incentives include 25 per cent capital expenditure support for the first 100 MW of electrolysers, capped at ₹1.5 crore per MW (minimum eligible project size is 50 MW or above). “We have earmarked ₹50 crore for establishing the first Green Hydrogen Hub entity in Kerala”, he added.
“We have committed ₹133 crore to a comprehensive multi-pilot programme called Kerala Hydrogen Valley Innovation Cluster (K-HVIC) covering production, storage, transport, and end-use applications. Of this, ₹53 crore is supported by the Department of Science & Technology, with the balance funded by industry partners”, Meena said.
ANERT is also developing a mobility project with ₹34.84 crore in funding from the Automotive Research Association of India (ARAI) to deploy four hydrogen vehicles and establish two hydrogen refuelling stations. “We have announced ₹200 crore for Viability Gap Funding, grants, and equity participation to anchor hydrogen hubs in Kochi and Thiruvananthapuram, and have earmarked ₹300 crore to assemble and enable land parcels along the West Coast Canal corridor through PPP models”, he said.
Kerala’s green hydrogen strategy focuses on both domestic applications and export opportunities. For domestic substitution, the plan is to replace a significant portion of imported diesel, LPG, and grey industrial hydrogen with locally produced green hydrogen, paired with solar, pumped hydro, and future marine energy resources.
On the export front, the port-adjacent locations and logistics capabilities position the State to produce and ship green ammonia and, in the longer term, green hydrogen derivatives to international markets.
“We are developing initial Hydrogen Valleys at Kochi and Thiruvananthapuram to co-locate production facilities, mobility applications, industrial off-takers, and R&D centres”, he said.
The transition to green hydrogen offers Kerala strategic, economic, and environmental benefits, strengthening energy security by lowering dependence on imported power and fossil fuels.
On the availability of land to set up hydrogen plants, the ANERT CEO said that the HVIC will utilise state-owned and industry parcels near ports, refineries, logistics yards, and industrial estates. Along the West Coast Canal corridor, there was an allocation of ₹300 crore to enable multi-site aggregation and develop common infrastructure through PPP arrangements.
“By 2030, our target is approximately 30 per cent reduction by 2030 and striving for a further 50 per cent cut in the long term to bring the cost to or below ₹200 per kg through competitive renewable power, higher utilisation factors enabled by hybrid renewable energy systems with storage, and maturing supply chains”, Meena said.
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PEDA inks pact with IISC for green hydrogen production
This initiative will produce green hydrogen from paddy straw. The collaboration aims to tackle stubble burning and improve air quality. It will also create new income for farmers and jobs in the green energy sector. The Punjab Energy Development Agency (PEDA) has signed a memorandum of understanding (MoU) with the Indian Institute of Science (IISc), Bengaluru, to establish a pioneering pilot demonstration project for the production of green hydrogen from biomass, particularly paddy straw.
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The MoU, signed by Neelima, chief executive officer, PEDA, and the registrar, IISc, Bengaluru, was formally exchanged between Neelima and Prof S Dasappa of the Interdisciplinary Centre for Energy Research (ICER), IISc. The exchange took place in the presence of Shripad Naik, Union minister of state for new and renewable energy & power, during the 5th International Conference on Recent Advances in Bio-Energy Research at Sardar Swaran Singh National Institute of Bio-Energy (SSS-NIBE), Kapurthala.
Congratulating PEDA for the transformative collaboration, Punjab new and renewable energy minister Aman Arora emphasised that the partnership with the IISc underscored the state’s commitment to clean energy innovation, leveraging agricultural waste to produce green hydrogen. This initiative, he noted, was crucial for creating a circular economy that empowers farmers, cleans the environment, and fuels industries with carbon-free energy, ultimately building a robust, pristine, and energy-independent Punjab.
Arora highlighted that the collaboration would establish a pioneering facility to demonstrate the technical and commercial viability of green hydrogen production from agricultural residues.
The project will tackle stubble burning, improve air quality, and boost the rural economy by creating new revenue streams for farmers and generating employment opportunities in the green energy sector. This initiative will significantly advance India’s National Green Hydrogen Mission and support Punjab’s ambitious renewable energy goals, he added.
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Three major ports recognised as Green Hydrogen Hubs
Three major Indian port authorities – Deendayal, V.O. Chidambaranar, and Paradip have been formally recognized as Green Hydrogen Hubs. This initiative aligns with the nation’s net-zero goals by 2070, fostering industrial participation and investment in clean fuel technologies through a cluster-based development model.
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The centre has formally recognised Deendayal Port Authority (Gujarat), V.O. Chidambaranar Port Authority
(Tamil Nadu), and Paradip Port Authority (Odisha) as Green Hydrogen Hubs. Commenting on the development, Union Ports, Shipping and Waterways Minister, Sarbananda Sonowal said, “Ports are important nodes in the transition towards net zero by 2070.”
The green hydrogen mission adopts a cluster-based development model. This approach enhances early-stage project viability, enables infrastructure convergence, and helps achieve economies of scale in identified regions, an official statement said.
Recognition of these ports is expected to catalyse industrial participation, attract green investments, and promote innovation in clean fuel technologies.
The current scheme guidelines for setting up Hydrogen Valley Innovation Clusters (HVIC) and Green Hydrogen Hubs provide the framework for identifying and supporting potential regions capable of large-scale hydrogen activity, the statement added.
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DMRC invites bids for supply of 500 million units of renewable energy
In a major step towards expanding its renewable energy footprint, the Delhi Metro Rail Corporation (DMRC) has invited bids for the supply of 500 million units (MUs) of renewable energy every year. The initiative marks another milestone in DMRC’s ongoing efforts to promote sustainable and environment-friendly operations.
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At present, the DMRC meets a substantial part of its electricity requirement through green sources by sourcing around 350 MUs annually from Rewa Solar Park and generating an additional 40 MUs from rooftop solar plants installed across its stations, depots and staff colonies. With this, renewable energy accounts for about 33 per cent of the total power used during operational hours and nearly 65 per cent during daytime operations.
DMRC invites bids for supply of 500 million units of renewable energy
Aims to raise share in its total power portfolio from 33% to over 60%
The DMRC also generates its own solar power from photovoltaic panels installed on the rooftops of stations, depots and residential colonies.
In a major step towards expanding its renewable energy footprint, the Delhi Metro Rail Corporation (DMRC) has invited bids for the supply of 500 million units (MUs) of renewable energy every year. The initiative marks another milestone in DMRC’s ongoing efforts to promote sustainable and environment-friendly operations.
At present, the DMRC meets a substantial part of its electricity requirement through green sources by sourcing around 350 MUs annually from Rewa Solar Park and generating an additional 40 MUs from rooftop solar plants installed across its stations, depots and staff colonies. With this, renewable energy accounts for about 33 per cent of the total power used during operational hours and nearly 65 per cent during daytime operations.
The new tender aims to select a solar power developer to set up a grid-connected captive generating plant along with a battery energy storage system (BESS) anywhere in India. The plant will supply 500 MUs of renewable energy annually to the DMRC facilities in Delhi and the National Capital Region.
Through this initiative, the DMRC aims to raise the share of renewable energy in its total power portfolio from the current 33 per cent to over 60 per cent, including its upcoming Phase IV expansion network. Once implemented, the DMRC will become the first Metro rail project in India to source more than 60 per cent of its total power from renewable sources, marking a significant stride towards low carbon and sustainable urban transport.
The project is expected to be completed within 15 months from the date of award, with a power purchase agreement period of 25 years. The bid process will be conducted in accordance with the approved government norms.This initiative aligns with the Government of India’s Panchamrit strategy, the five-point climate action agenda announced at COP26, and reflects the DMRC’s commitment to a cleaner and more resilient energy future.
Notably, the Delhi Metro sources its electricity from both renewable and non-renewable sources. Renewable sources include off-site solar power plant at the Rewa Ultra Mega Solar project in Madhya Pradesh.
Meanwhile, the DMRC also generates its own solar power from photovoltaic panels installed on the rooftops of stations, depots and residential colonies. As of 2025, the total on-site rooftop solar capacity was 51 MW. It also sources a small amount of electricity from a waste-to-energy plant in Ghazipur.
While the remaining portion of the energy mix is met by power supplied from DISCOMs in Delhi, Uttar Pradesh and Haryana.
In a step towards the sustainability goal, the DMRC had also installed the country’s first vertical bifacial solar plant at the Okhla Vihar Metro station.
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INTERNATIONAL NEWS
Natural Gas / Transnational Pipelines/ Others
US: ARM Energy Approves $2.3B Texas Gas Pipeline
ARM Energy Holdings LLC on Thursday announced a FID (final investment decision) to proceed with the Mustang Express Pipeline project, designed to add 2.5 billion cubic feet a day of natural gas transport capacity on the Texas Gulf Coast.
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The pipeline system represents an investment of $2.3 billion, ARM Energy and Pacific Investment Management Co (PIMCO) said in a joint statement. “Mustang Express Pipeline will be constructed and operated by ARM Energy, along with its financial partners, PIMCO and associated co-investors”, they said.
Expected to be completed late 2028 or early 2029, the project will have a 178-mile mainline from the Katy Hub to Port Arthur. The conveyor, 42 inches in diameter, will total 236 miles in length, the companies said.
Mustang Express is supported by an anchor shipper commitment from Sempra Infrastructure for the provision of feed gas for its Port Arthur LNG Phase II project, the statement said.
Houston, Texas-based ARM Energy plans an open season this month for the project’s remaining capacity.
ARM Energy contracted Jindal Tubular USA for the mill capacity and Solar Turbines Inc for the turbines for the project’s three gas-driven compressor stations, which will have a total capacity of 300,000 horsepower, the statement said.
Mustang Express will “significantly enhance the efficiency of the U.S. natural gas supply chain”, ARM Energy chief executive Zach Lee said. “By linking two of the most prolific natural gas-producing regions in the U.S. directly to LNG export facilities in Texas, we are helping ensure a reliable supply of natural gas for liquefaction and export with a route that crosses four storage facilities – delivering positive impacts for global energy needs and Texas communities”.
PIMCO managing director and portfolio manager Adam Gubner said the project “reflects our commitment to invest in infrastructure to support LNG expansion in the U.S., while also providing compelling long-term investment opportunities for our clients looking for attractive risk-adjusted returns”.
Last month Sempra announced a positive FID on the project, which it said would double the current terminal’s liquefied natural gas capacity to 26 million metric tons per annum (MMtpa).
In May the U.S. Department of Energy (DOE) granted phase II a permit to export to countries without a free trade agreement (FTA) with the U.S., marking the resumption of federal permitting for LNG export to non-FTA nations following a pause by the previous administration.
Phase II is now authorized to export the equivalent of 698 billion cubic feet a year of natural gas, or about 13.5 MMtpa of LNG according to Sempra, to FTA and non-FTA countries on a non-additive basis until 2050. Sempra received the FTA portion of the permit July 2020.
https://www.rigzone.com/news/arm_energy_approves_23b_texas_gas_pipeline-10-oct-2025-182050-article/
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Nigeria and Morocco advance gas pipeline project with joint venture
A strategic energy partnership between Morocco and Nigeria reached a pivotal milestone with the establishment of a dedicated joint venture to manage their ambitious $25 billion trans-African gas pipeline project. The newly formed entity will oversee financing and implementation of this massive infrastructure initiative, marking a transition from planning to operational phases.
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According to the Moroccan Office of Hydrocarbons and Mines (ONHYM), this development marks a major step in structuring the project’s financing and preparing for its implementation. The creation of the new joint company now provides a clear and integrated governance framework, based on a more structured technical and financial vision.
The pipeline infrastructure will span approximately 6,000 kilometers along West Africa’s Atlantic coastline, representing one of the continent’s most significant energy undertakings. The system is designed to transport between 15 and 30 billion cubic meters of gas annually, fundamentally transforming regional energy accessibility and security.
Technical feasibility studies completed in 2025 have confirmed the pipeline’s routing, which will traverse 13 coastal nations including Benin, Togo, Ghana, Côte d’Ivoire, and Senegal, among others. The infrastructure will serve approximately 400 million people while providing connections to landlocked nations including Niger, Burkina Faso, and Mali.
International financial institutions have demonstrated strong support for the initiative. The European Investment Bank, Islamic Development Bank, and OPEC Fund for International Development have committed substantial resources, with the United Arab Emirates joining as a strategic partner. This diverse funding coalition underscores confidence in the project’s economic viability and regional significance.
The governance structure features a parent company overseeing regional entities responsible for specific pipeline segments, ensuring coordinated management across multiple jurisdictions. This organizational framework, endorsed by the Economic Community of West African States (CEDEAO), provides transparency and operational efficiency essential for cross-border infrastructure of this magnitude.
The pipeline will ultimately connect to existing European gas networks through Morocco’s established infrastructure, positioning the kingdom as a crucial energy bridge between Africa and Europe while advancing continental integration objectives championed by King Mohammed VI.
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Hungary buys gas from France’s Engie, diversifying supply from Russia
BUDAPEST, Oct 2 (Reuters) – Hungary on Thursday signed its biggest ever deal to buy liquefied natural gas from French firm Engie (ENGIE.PA), a second agreement in as many months that will diversify its supply away from top energy provider Russia. U.S. President Donald Trump said last month he would urge Hungary to stop buying Russian oil, part of a push to pressure NATO allies to cut energy ties with Moscow over its war with Ukraine. Hungarian Prime Minister Viktor Orban said dropping Russian energy would be a disaster for Hungary’s economy.
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On Thursday Hungarian natural gas wholesaler MVM CEEnergy agreed to buy 400 million cubic metres of gas a year from Engie between 2028 and 2038. Given Hungary consumes around 8 billion cubic metres of gas a year, that would cover 5% of its demand.
The deal follows another Hungary signed last month with Shell to buy 200 mcm of natural gas a year from January 2026, equal to around 2.5% of its demand.
Hungary’s Foreign Minister Peter Szijjarto said at the signing ceremony for the Engie deal that it was the longest-term LNG contract in Hungary’s history, and will serve as a pillar to the country’s energy security.
“Diversification for us does not mean that we replace an existing, well-functioning supply relationship with another,” he added.
Slovakia and Hungary have rejected European Commission plans to phase out Russian gas and other energy imports, deepening a rift with Brussels over relations with Moscow.
“We do not accept any pressure or coercion in this issue and we will not pay a war premium,” Szijjarto said.
Engie did not specify the origin of the gas it will supply to Hungary. European LNG buyers and traders often source their gas from multiple producers including the U.S., the Middle East, Africa, Australia and sometimes Russia.
Hungary signed a 15-year deal in 2021 with Russia to buy 4.5 billion cubic metres of gas annually, and increased purchases from Gazprom last year, importing some 7.5 billion cubic metres of Russian gas via the Turkstream pipeline.
Szijjarto said last month that Hungary had imported 5 billion cubic metres of gas via Turkstream by the end of August, which meant this year’s gas imports via Turkstream could hit a record high.
Hungary, which ships gas to Slovakia via an interconnector, also buys gas from Romania, and smaller volumes via the HAG pipeline which runs from Austria into Hungary.
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Columbia: Halfway River First Nation partners with Arc Resources to develop natural gas fields in Montney
Halfway River First Nation has formed a new partnership with the Calgary based Arc Resources Ltd. to begin developing a natural gas field in the Montney region. The agreement, announced at the end of July, allows the Nation’s own energy company, Tsaa Dunne Za Energy (TDZE), to develop up to 36 connected land parcels.
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That’s about 23,000 acres of land, located right next to the existing Attachie project, operated by Arc resources.
TDZE will work with ARC Resources to develop part of the tenure land and use existing infrastructure already in place.
In July 2024, Halfway River First Nation finalized a historic deal giving it control of 34,000 hectares of natural gas rights in the Montney Region.
That “first of its kind” agreement with the province gave the Nation to decide how petroleum and natural gas resources are developed in the area.
In addition, it also gave them management of infrastructure assets, such as pipelines, production facilities, and electricity infrastructure.
The agreement was tied to a new landscape planning pilot designed to protect Treaty 8 rights while allowing sustainable development in northeastern communities.
The Attachie project falls within the area covered by this planning pilot.
“We are proud to participate in the landscape planning pilot through our Attachie project and advance responsible energy development in B.C.,” said ARC Resources president and CEO Terry Anderson.
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UK: Major gas pipe upgrade work closing Nocq Road
Large-scale works are set to begin in St Sampson as part of plans to upgrade Guernsey’s gas infrastructure. Guernsey Energy said it would start work to replace metal pipes with more durable plastic ones, which involves closing Nocq Road from Monday, with an expected completion date of 12 December.
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Different parts of the road will be closed during the work, which is being carried out in four phases.
Network operations manager, Richard Beharrell, said the work would be the next step in modernising Guernsey’s infrastructure so it could provide a reliable gas supply and support the island’s net zero target.
He said: “We appreciate the residents and businesses patience during these necessary improvements.”
Guernsey Energy said it would use a trenchless method to minimise disruption by reducing the amount of digging required, but this method can not always be used so some trench digging would be required.
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New Guinea: All eyes on Papua New Guinea’s offshore oil and gas
Papua New Guinea is on track to become an offshore gas producer before the end of the decade, thanks to Twinza’s Pasca A project. There are also hopes of large offshore oil discoveries, with two separate drilling campaigns being planned in a prospective new offshore basin.
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Papua New Guinea looks set to join the ranks of the world’s offshore oil and gas producers in the next three to four years, following the recent Pasca A Gas Agreement between project owner Twinza and the PNG government.
The December 2024 agreement enabled Pasca to enter front-end engineering and design (FEED) in February 2025, with an eye to reaching a final investment decision (FID) on the first phase in mid-2026.
Progress on FEED has been “good” and the project is on track to meet its timelines, according to Roppe Uyassi, CEO PNG for Twinza.
“The important stage will be when we start our tendering later this year. That’s when we’ll have a good handle of where we’re looking at with the FID target date,” Uyassi tells Business Advantage PNG.
Ease of developing offshore
The project’s offshore location means its workforce requirements will be smaller than for onshore oil and gas projects, Uyassi says.
“In saying that, we have an exciting opportunity to create employment and to give offshore oil and gas exposure to Papua New Guineans,” he says.
“Our workforce will be largest during the production phase,” Uyassi explains, “and that’s where a lot of our local employment opportunities will come into play. We’ve got time to plan that out.”
An updated independent assessment in 2023 concluded that Pasca could deliver K15 billion in revenues to PNG over a 25-year production life. The study also highlighted Pasca’s potential to sequester up to 200 million tonnes of CO2, something which could prove supportive in attracting project financing.
“I’m in no doubt that we will have those conversations where we have to talk in detail about ESG [environmental, social and governance],” Uyassi says.
Offshore exploration heats up
The development of PNG’s offshore oil and gas resources reflects a worldwide trend, with a Global Energy Monitor study finding that the vast majority of new projects discovered, sanctioned and started up in 2024 were located in the oceans. At least 12 projects reached FID in 2024, all of which were offshore. At the same time, 85 per cent of new discoveries by volume were located in offshore fields.
In PNG, state-owned energy company Kumul Petroleum is also looking to prove up gas reserves in two offshore fields close to Pasca A in the Gulf of Papua and is exploring the possibility of a floating LNG solution to speed up its development.
Meanwhile, in the Torres Basin southeast of Port Moresby, TotalEnergies and Malaysia’s Petronas are preparing for drilling for hydrocarbons at their jointly owned Mailu-1 exploration well (Petroleum Prospecting Licence 576), PNG’s first deepwater well, in the final quarter of 2025.
Noble, a leading offshore drilling contractor for the oil and gas industry, says it has received a US$34.2 million contract for the approximately 47-day program, with an option to drill three additional wells.
Unlisted Australian explorer Larus Energy is also hoping to drill the Nanamarope Prospect in the adjacent PPL 579 in 2026.
“We want to follow TotalEnergies’ drilling of Mailu-1 to test a different play type in the Torres Basin testing the Miocene sand reservoirs at Nanamarope, which is different to the Mailu-1 well’s target of Eocene carbonate reservoirs,” Larus Managing Director John Chambers tells Business Advantage PNG.
“Both prospects however rely on a similar hydrocarbon source rock which has been proven from seeps onshore and offshore in the Larus acreage,” he says.
Larus is currently in talks with several large international oil companies – some of which have never operated in PNG – to participate in a potential joint venture.
“We’re trying to get a farm-in partner to pick up equity in return for funding an [exploration] well,” Chambers says, noting that the costs of the drilling campaign could reach around US$100 million.
“Exploration in deep water takes deep pockets but we are finding interest from both private investors and large oil companies.”
Potential ‘game changer’
Larus has been active in PNG since 2009, although for a long time it only explored onshore or in shallow waters offshore. It ventured around 100 kilometres offshore into deeper waters in 2023 when it contracted PXGEO 2, one of the world’s largest seismic vessels, to conduct a 3D survey over 1,865 square kilometres.
Chambers, who previously served as vice president of Santos PNG, says the survey identified the potential for several “very large prospects” and changed the understanding of that part of the Torres Basin.
“Potentially you’ve got a new oil basin here in PNG. It’s probably one of the few in the world that hasn’t yet had a well put in it, so it could be a game changer.”
https://www.businessadvantagepng.com/all-eyes-on-papua-new-guineas-offshore-oil-and-gas/
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Iran adds 10 trillion cubic feet of gas to its reserves
DUBAI, Oct 6 (Reuters) – A new discovery in the Pazan gas field in southern Iran has been made with 10 trillion cubic feet of natural gas, Oil Minister Mohsen Paknejad said on Monday according to his ministry’s news outlet Shana.
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Iran holds the world’s second largest natural gas reserves, but most of its production is consumed domestically or lost to flaring, and the country faces a gas imbalance during high demand months.
“This field has 10 trillion cubic feet of gas, and if we consider a 70% recovery rate we can reach 7 trillion cubic feet,” Paknejad said, adding that the new reserves could help cover Iran’s existing imbalances in the coming years.
Paknejad added the new find was made after a pause of 8 years in exploration activities at the field and estimated it would take 40 months before extraction can begin.
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US: OPAL Fuels and SJI launch renewable natural gas facility in New Jersey
EGG HARBOR TOWNSHIP, N.J. – OPAL Fuels Inc. (NASDAQ:OPAL), a $395 million market cap renewable energy company currently trading below its InvestingPro Fair Value, and South Jersey Industries (SJI) announced Monday that their renewable natural gas (RNG) facility at Atlantic County Utilities Authority’s (ACUA) solid waste landfill in Egg Harbor Township has commenced commercial operations.
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The facility captures and processes landfill gas into RNG for use as transportation fuel, marking the first project to deliver RNG into South Jersey Gas’s pipeline system. With a nameplate capacity of 2,500 SCFM of landfill gas, the facility is expected to produce more than 650,000 MMBtu or over 4.6 million gasoline gallon equivalent per year of RNG. This expansion aligns with OPAL Fuels’ impressive 12.2% revenue growth over the last twelve months.
“This project reduces emissions, improves local air quality, creates jobs, and strengthens American energy independence,” said Adam Comora, Co-Chief Executive Officer of OPAL Fuels.
The project represents the first collaboration between OPAL Fuels and SJI under their previously announced 50/50 joint venture to develop RNG facilities. A second collaboration, the Burlington RNG Facility in Florence Township, New Jersey, is currently in development.
“This project underscores our commitment to innovation and continuing efforts in renewable energy solutions,” said Chet Benham, President of SJI Renewable Energy Ventures.
ACUA President Matthew DeNafo noted that the project makes ACUA “the first public solid waste facility in New Jersey to host an RNG project.”
A ribbon-cutting ceremony at the facility is planned for later in October 2025.
The information in this article is based on a press release statement from the companies involved.
In other recent news, Opal Fuels Inc. reported its financial results for the second quarter of 2025, which showed a significant miss on earnings and revenue forecasts. The company’s earnings per share (EPS) were $0.03, falling short of the expected $0.10, resulting in a 70% negative surprise. Additionally, revenue was reported at $80.5 million, below the forecasted $86.27 million. In another development, Opal Fuels announced that Lance Moll, a veteran from FedEx Freight, will join its board of directors effective October 1, 2025. Moll brings over three decades of experience in logistics and transportation, having previously served as President and CEO of FedEx Freight. During his leadership, FedEx Freight saw a 30% increase in revenue and nearly tripled its operating income. These developments mark recent changes and challenges for Opal Fuels.
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Nigeria-Libya Gas Pipeline Project
The negotiations were between Nigeria’s Minister of State for Petroleum Resources (Gas), Ekperikpe Ekpo, and Libya’s Oil Minister, Dr. Khalifa AbduAlsadik. It was held on the sidelines of the Gastech Exhibition and Conference 2024 in Houston, USA. The negotiation lingered on seeking avenues for energy cooperation. Further, it considered examining the feasibility of building a cross-country gas pipeline stretching from Nigeria to North Africa.
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Delegates from the two nations participated in the talks, such as their counterparts from Nigeria National Petroleum Company Limited (NNPCL) and Libya’s Ministry of Oil. The action was part of broader activities aimed at strengthening regional energy cooperation and catalyzing the development of Africa’s natural gas infrastructure. The project is of monumental significance as it will facilitate projects such as Libya’s offshore oil exploration project, Block 16/4. The project is located at the coast, northwest of Libya, and is headed by a regional subsidiary of Italian energy giant Eni. Moreover, it is responsible for managing the company’s oil and gas operations in North African countries with major focus on Libya. The company is re-entering the C1-16/4 exploratory well, known as BESS-3.
The company aims to complete drilling to its planned final depth of 10,520 feet (3,200 meters). Drilling on the C1-16/4 well originally began on March 11, 2020. However, operations were halted shortly after due to the COVID-19 pandemic. The initial drilling reached 1,012 feet before the well was temporarily abandoned on April 14, 2020. The C1-16/4 well is located in Contract Area D (MN-41), approximately 95 kilometers offshore from the Libyan coast.
Conception of the Idea of the Project
The discussion surrounding the construction of a regional pipeline between Nigeria and Libya has been ongoing for quite some time, as both nations are major oil and gas producers in Africa.
In the year 2022, the then Libya’s Oil Minister, Mohamed Aoun, proposed that the ongoing project of the $13 billion Nigeria-Morocco Gas Pipeline (NMGP) from Nigeria should pass through Libya instead of passing through Algeria, which is another resource-rich African country.
The cross-border pipeline is expected to transport gas from Nigeria to other African nations and the European market upon completion.
The pipeline spans 5,600 km and will pass through 13 African countries: Nigeria, Benin Republic, Togo, Ghana, Cote D’Ivoire, Liberia, Sierra Leone, Guinea, Guinea Bissau, Gambia, Senegal, Mauritania, and Morocco.
Significance/Benefits of the Nigeria-Libya Gas Pipeline Project
The proposed Libya-Nigeria gas pipeline project holds significant potential for both countries and the broader region. Here are some key points:
Economic Benefits: This mega pipeline could bring forth substantial economic benefits for Libya and Nigeria by facilitating the export of natural gas to the neighbouring continent Europe. This would provide a new revenue stream and help diversify their economies1.
Energy Security: For the neighbouring continent Europe, the upcoming pipeline will offer an alternative source of natural gas, enhancing energy security and reducing dependence on the Russian gas.
Regional Cooperation: This pipeline project upon completion will promote regional cooperation and integration, as it involves and will pass through multiple African countries. This could eventually lead to improved political and economic ties across the continent.
Infrastructure Development: The construction of the pipeline would entail significant infrastructure development, this project will eventually create jobs and boosting local economies along the route.
Environmental Impact: By providing a much cleaner energy source compared to its alternatives coal and oil, the pipeline could contribute to reducing greenhouse gas emissions and supporting global climate goals.
Generally, the Libya-Nigeria pipeline project brings forth a strategic initiative with far-reaching implications for economic growth, energy security, and regional cooperation in the African region.
https://constructionreviewonline.com/nigeria-libya-gas-pipeline-project/
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Natural Gas / LNG Utilization / Bio-LNG
Canada: Shell-led LNG Canada prepares to start Train 2
HOUSTON/Calgary Oct 2 (Reuters) – Shell-led (SHEL.L), LNG Canada has begun the process of starting up its second 6.5 million tonnes per annum (mtpa) liquefied natural gas processing unit known as Train 2 in Kitimat, British Columbia, a company spokesperson told Reuters on Thursday.
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The startup of Train 2, however, is happening as the company continues to experience technical problems at Train 1, according to two people with knowledge of its operations. The train was reported by sources to have technical issues in July, a month after it had started first production.
LNG Canada is the first major LNG export facility in Canada, and the first on the west coast of North America that provides direct access to Asia, the world’s largest LNG market.
The facility took almost seven years to be built and has been operating at less than half its stated capacity, the people said.
“We have had to swap out the supercore, and while string 2 is running, string 1 is down,” one of the two people told Reuters.
When asked about the technical issues, the company spokesperson pointed to ongoing export activity at the terminal and said flaring that started on September 11 had ended.
“A 14th cargo departed the LNG Canada facility on September 30. A 15th cargo is expected to depart in the coming days,” the spokesperson said.
In September, LNG Canada exported less of the superchilled gas than the month before, with only four cargoes leaving the port for a total export of just under 0.3 million metric tons compared with the 0.4 million tons it sold in August, according to preliminary ship tracking data from financial firm LSEG.
When fully operational, the facility is expected to convert about 2 billion cubic feet of gas per day (bcfd) to LNG, which market participants have hoped will boost Canadian natural gas prices. The slow ramp-up of LNG Canada, however, has contributed to daily spot prices slumping to record lows last week, as it has failed so far to drain a gas glut that built in anticipation of increasing demand from the plant, causing pipeline congestion.
Gas storage in Western Canada remains at last year’s record highs, according to investment bank Jefferies, and Reuters reported last week that some gas producers are aggressively cutting output in an effort to ease an ongoing glut.
LNG Canada is a joint venture between Shell, Malaysia’s Petronas (PGAS.KL), PetroChina <601857.SS>, Japan’s Mitsubishi Corp <8058.T>, and South Korea’s KOGAS <036460.KS>.
On Tuesday, MidOcean – an LNG company backed by EIG and Saudi Aramco – announced a plan to buy a fifth of the Petronas venture that holds a 25% share of LNG Canada.
https://www.reuters.com/business/energy/shell-led-lng-canada-prepares-start-train-2-2025-10-02/
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Singapore: LNG demand for ships set to at least double by 2030 globally
SINGAPORE, Oct 2 (Reuters) – Demand for liquefied natural gas as a marine fuel will at least double by 2030 as abundant supply and rising emissions regulations spur orders for ships that can run on it, industry executives said. Massive LNG export projects in the U.S. and Qatar are expected to cause a supply glut by 2030, reducing prices and improving its competitiveness against conventional and more-polluting fuel oil.
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LNG is pulling ahead of other fuels in decarbonising shipping, which accounts for nearly 3% of emissions, as supply and infrastructure hurdles cloud the outlook for cleaner alternatives methanol and ammonia.
“Owners ultimately will choose the fuel that gives you the lowest cost,” said Tuomas Maljanen, associate director for LNG and new energy at shipbroker Fearnleys.
“LNG is great because the infrastructure is there. It’s readily available … maybe later on it’s going to be, hopefully, quite cheap as well,” he added.
Singapore, the top bunkering hub, led global LNG bunkering activity in the third quarter, followed by China and the Netherlands, according to consultancy Rystad Energy, and it plans to issue additional bunker supply licences.
Global LNG bunkering volumes could surpass 4 million tons by end-2025 and double by 2030, said Jo Friedmann, senior vice president of supply chain research at Rystad Energy.
French energy major TotalEnergies (TTEF.PA), expects global LNG and bio-LNG bunker demand to surge to 15 million tons by 2030.
Some 781 dual-fuelled ships can now use LNG, according to ship certifier DNV.
“Based on today’s orderbook, the number of vessels will be 1,417 by 2030, but we expect this to increase as new orders are confirmed,” said Kristian Hammer, product manager AFI & senior consultant at DNV.
IMMEDIATE REDUCTION
Refuelling with LNG reduces emissions from fuel oil by 19% on a “well-to-wake” basis, which refers to emissions from extraction to usage, according to Mitsui O.S.K. Lines. (9104.T), which owns the second largest shipping fleet.
It operates 15 LNG dual-fuelled vessels and has an additional 42 on order.
“Until zero or near-zero fuels are widely available, LNG remains a realistic decarbonisation option for shipping in terms of availability, cost-effectiveness, and safety,” the company said.
Danish shipping giant Maersk (MAERSKb.CO), which until last year focused only on green methanol as an alternative fuel, has ordered 20 LNG dual-fuelled container ships for delivery between 2028 and 2030.
TotalEnergies expects LNG to outpace other alternative bunker fuels methanol and ammonia after 2030.
“Renewable methanol and ammonia production remain in their infancy, with limited bunkering infrastructure and a lack of economic competitiveness against conventional fuels that need to be addressed before scalable adoption is possible,” it said.
REGULATIONS
Europe’s FuelEU regulation, which took effect this year, limits fuel carbon intensity for ships calling on ports there and is expected to drive adoption of LNG bunkering.
This month, an International Maritime Organization committee will vote on a rule drafted in April that imposes emissions fees on ships that breach it and rewards vessels burning cleaner fuels from 2028. However, the U.S. rejected the deal and a group of top shipping companies are demanding changes.
“Until the IMO regulations take effect, LNG-bunkering activity remains highly sensitive to LNG bunker prices, especially for vessels operating on non-EU routes,” said Rystad’s Friedmann.
LNG bunker prices were on average $247 per metric ton higher than marine fuel in the first nine months of this year, S&P Global data showed, though excess LNG supply set to come online towards the end of the decade is widely expected to pressure prices.
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Iraq: Excelerate Energy to develop integrated floating LNG import terminal in Iraq
U.S.-based LNG company Excelerate Energy has received an official award letter from the government of Iraq to develop an integrated floating liquefied natural gas (LNG) import terminal. The Woodlands, Texas, company said the proposed terminal will allow Iraq to import LNG to support domestic power generation, stabilize the national grid and diversify from unreliable natural gas supply sources.
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The development of the integrated floating import terminal will be led by Excelerate in coordination with the Iraqi government.
The move has the backing of Iraq’s Prime Minister Mohammed Shia’ al-Sudani. Deputy Prime Minister and Foreign Minister Fuad Hussein congratulated Excelerate president and CEO Steven Kobos during a meeting on September 25 on the margins of the 80th United Nations General Assembly in New York City.
The U.S. Department of State’s Thomas Lersten, senior official to the office of the under secretary for economic growth, energy, and the environment, also attended the meeting and underscored the strategic importance of U.S. LNG to the administration’s energy dominance agenda.
The award letter is a preliminary step, and development of the terminal remains subject to the successful negotiation and execution of binding commercial agreements, Excelerate said, which is actively engaged with Iraqi authorities to finalize the necessary contracts.
“This award is a testament to the strategic partnership between Excelerate Energy and the Government of Iraq,” said Steven Kobos. “We are honored to be selected for this critical infrastructure project and look forward to working closely with Iraqi leadership to bring it to fruition.”
Excelerate offers a full range of flexible regasification services from floating LNG terminals to infrastructure development to LNG supply and power generation.
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Colombia: Ecopetrol Plans Another LNG Import Terminal in Colombia at Port
Ecopetrol SA is finalizing a plan to configure part of a Colombian port into a facility to import liquefied natural gas as the nation faces a growing shortfall of the fuel. The state-run oil company aims to use existing infrastructure in the port of Coveñas to import LNG, Ecopetrol Chief Executive Officer Ricardo Roa said Monday in Bogotá. The port along Colombia’s Caribbean coast is owned by the company’s pipeline unit Cenit. The Coveñas LNG project would startup in the first quarter of 2027, Roa said.
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“We’re developing a strategic energy hub in order to guarantee in the medium and long term that Colombia has energy security,” he said.
Colombia began importing liquefied natural gas in 2016 for power generation. At the end of last year the country turned to the fuel to meet demand from households and businesses as the nation’s reserves dwindled. The South American nation is facing a deficit of 4% of total gas demand, and the gap is expected to widen to as much as 20% next year.
While this year’s shortfall is being met by spare capacity at Colombia’s only LNG import terminal in Cartagena, known as SPEC, additional infrastructure needs to be built to meet demand.
Read More: Colombia Resumes Talks With Venezuela to Plug Gas Shortfall
The Coveñas LNG project comes in addition to a smaller planned facility from Ecopetrol in Colombia’s Pacific port that is slated to start operating around August of next year.
In an initial phase, the Coveñas LNG terminal, known as a floating storage and regasification unit, or FSRU, would import about 110 million cubic feet a day of gas. In a second phase, once a larger oil pipeline is converted to carry fuel to the interior of the country, it could bring in as much as 400 million cubic feet a day, according to Roa.
Ecopetrol will open a request for proposals in the coming days for companies interested in providing regasification services, Roa said.
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Jordan: Energy minister reviews LNG terminal expansion in Aqaba
AMMAN — Minister of Energy and Mineral Resources Saleh Kharabsheh on Saturday toured the Sheikh Sabah Al Ahmad Liquefied Natural Gas (LNG) Terminal in Aqaba to review ongoing development works at the facility. Kharansheh said the terminal represents a vital pillar in the Kingdom’s efforts to secure a sustainable and resilient energy system, according to a ministry statement.
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Kharabsheh also held a meeting with Project Manager Omar Badoor from the Aqaba Development Corporation and the contractor, in the presence of National Electric Power Company (NEPCO) Director General Sufian Bataineh, Jordan Oil Terminals Company (JOTC) Logistics Director Ashraf Rawashdeh, and Oil and Gas Directorate Director at the ministry, Iman Awad.
During the meeting, he was briefed on the project’s latest progress and developments and discussed the challenges and obstacles affecting its implementation.
The project aims to preserve the option of importing liquefied natural gas (LNG) for power generation and industrial use, as a strategic measure to ensure a continuous energy supply in case any of the current sources are disrupted. It also contributes to lowering electricity generation costs.
The Aqaba Development Corporation, in cooperation with the Ministry of Energy and the National Electric Power Company (NEPCO), is overseeing the implementation of the project. It includes the construction of an onshore regasification unit (ORU) with a capacity of up to 700 million cubic feet per day, along with the replacement of the current floating storage and regasification unit (FSRU) with a new floating storage unit (FSU).
The project is being financed through two concessional loans, the first amounting to KD 18.2 million from the Kuwait Fund for Arab Economic Development, and the second valued at KD 21 million from the Arab Fund for Economic and Social Development.
The tender for the construction of the onshore regasification unit was awarded to a joint venture of AGP International Holdings Pte Ltd, Gas Entec Co. Ltd, and Issa Haddadin& Partner at a cost of $125 million. The project is expected to be completed within 22 months of its commencement and to enter service in September 2026.
https://jordantimes.com/news/local/energy-minister-reviews-lng-terminal-expansion-in-aqaba
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Global LNG Development
Mozambique: Eni Agrees to Build $7.2 Billion LNG Export Plant in Mozambique
Eni SpA gave financial approval to build a $7.2 billion floating liquefied natural gas project in Mozambique that will double the nation’s production of the fuel, adding to global supply just as a wave of new production hits later this decade. The Coral Norte project off Mozambique’s northern coastline will be able to produce 3.6 million tons of LNG a year and will use the same design as Coral Sul, which started exporting the fuel in 2022.
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The approval marks a turning point in the southern African nation’s LNG developments to export its significant gas discoveries, which had been set back by security issues over the past few years. Momentum has returned in recent months with both TotalEnergies SE and Eni readying contractors and signing agreements for preliminary work to develop the deposits that can transform the economy of one of the world’s poorest nations.
“The project is expected to boost Mozambican economy as well as the competitiveness of the local industries,” Eni said in a statement. It will create “more new jobs and opportunities for national enterprises.”
Coral Norte will be located in the nation’s Area 4 concession.
Eni’s floating platforms in Coral Sul have been less impacted by insurgency as they’re dozens of miles offshore and out of reach from the militants.
While the project’s location makes it less susceptible to militant attacks, all such facilities also have supply chains on land that can be exposed. Onshore projects by TotalEnergies and Exxon were held up by an Islamic State-linked insurgency after intensifying attacks prompted a freeze in plans more than four years ago.
Mozambique’s military — with help from regional forces — has pushed back militants since 2021, but violence has surged in recent weeks. Attacks are on track to reach a record this year, the UN Office for the Coordination of Humanitarian Affairs said in a report Sept. 29.
The country expects to earn about $23 billion from Coral Norte over 25 years, the government said earlier this year. It badly needs revenue after delays to onshore LNG export projects it had banked on to help repay a $900 million eurobond that starts amortizing in 2028.
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US company wins Iraq LNG terminal deal
Iraq has awarded a contract to a US company for the installation of a floating terminal which imports liquefied natural gas to power its gas-thirsty electricity plants. Excelerate Energy, which is based in Texas, said it has received an official award letter from the Iraqi government to develop the terminal.
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The facility will enable the importation of LNG to support domestic power generation, help stabilise the national grid and allow Iraq to diversify from unreliable natural gas supply sources, Excelerate said in a statement this week.
Iraq controls the world’s fifth largest proven oil deposits. Its decision followed a sharp decline in Iranian gas supplies, which account for nearly 40 percent of the power generation at Iraq’s gas-run power facilities.
A memorandum of understanding with Turkmenistan to import gas also failed to materialise following US objections, as the gas had to pass through Iran.
Officials said last month the floating terminals would be installed off Basra in southern Iraq, but they did not make clear where the LNG would come from.
Iraqi officials have visited Qatar over the past month for a possible LNG supply agreement while imports from Oman were also discussed during a recent visit to the sultanate by Iraq’s prime minister Mohammed Al-Sudani.
Officials said the import of LNG is temporary pending the completion of major gas field development projects which Iraq hopes will make it self-sufficient in gas by 2028.
Iraq, Opec’s second largest oil producer after Saudi Arabia, is suffering from a power supply shortage of more than 10 gigawatts because of gas supply disruptions.
https://www.agbi.com/oil-and-gas/2025/10/us-company-wins-iraq-lng-terminal-deal/
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Gaz-System completes strategic gas pipeline and secures three more key investments
Gaz-System, Poland’s transmission operator, has completed the construction of the Kędzierzyn-Koźle – Racibórz gas pipeline. In Southern Poland, the company commissioned a 37-kilometre-long pipeline with a diameter of 1000 millimetres. The new infrastructure significantly increases access to natural gas in the Silesian and Opole regions and enables the connection of the new Rybnik gas and steam power block, with a capacity of over 880 megawatts (MW), to the network. It can supply energy to up to two million households.
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The pipeline, together with the Racibórz – Rybnik pipeline and the Rybnik block connection, forms a network over 80 kilometres long.
“I would like to emphasise that the Kędzierzyn-Koźle – Racibórz gas pipeline is another important infrastructure investment in southern Poland, implemented by our company under the ‘Coal to gas’ programme,” said Elżbieta Kramek, Vice-President of GAZ-SYSTEM. “In December 2024, we completed the construction of the Oświęcim – Tworzeń gas pipeline. The financial support provided by the European Union’s FEnIKS (European Funds for Infrastructure, Climate and Environment) programme is crucial for the implementation of these projects.”
On the sidelines of the pipeline launch, agreements were signed to secure co-financing for three additional investments under the FEnIKS 2021–2027 Programme: two gas pipelines and the Lwówek Gas Compressor Station. The total value of these investments is 1.5 billion zlotys, with EU support totalling 884.5 million zlotys.
EU funding was awarded for three infrastructure projects:
Construction of the Lewin Brzeski – Nysa gas pipeline, which will connect with the North-South Corridor and serve as a new power supply source for the southern region of Opole Voivodeship, with EU funding of 197.8 million zlotys;
Construction of the Lwówek Gas Compressor Station, implemented under the Transit Gas Pipeline System Programme (SGT), which will integrate the national transmission system with transit infrastructure, significantly increasing the security and efficiency of gas supplies, with EU funding of 559.9 million zlotys;
Construction of the Wężerów – Przewóz gas pipeline (DN700) together with accompanying infrastructure, which will improve the capacity and reliability of the transmission network, with EU funding of 126.8 million zlotys.
https://ceenergynews.com/oil-gas/gaz-system-gas-pipelines/
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Hungary secures 10-year LNG contract with Engie through 2038
Hungary has signed a ten-year agreement with Engie for the annual import of 400 mn m³ of liquefied natural gas starting in 2028, reinforcing its energy diversification strategy despite its ongoing reliance on Russian gas.
Hungarian state-owned company MVM CEEnergy has signed a ten-year contract with Engie Energy Marketing Singapore for the annual delivery of 400 million cubic metres of liquefied natural gas (LNG) between 2028 and 2038. The announcement was made by Minister of Foreign Affairs and Trade Péter Szijjarto, highlighting a shift in Hungary’s energy policy direction.
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This volume represents approximately 4.5% of Hungary’s annual gas consumption, which reached 8.5 billion cubic metres in 2023. The contract foresees a cumulative delivery of four billion cubic metres over a decade, sourced from Engie’s global LNG supply network.
Partial diversification amid Russian dependency
Despite the relatively small share this contract accounts for in Hungary’s gas mix, the government views it as a strategic step. Péter Szijjarto stated that the deal marks “an important milestone for Hungary’s energy security,” reaffirming Budapest’s intention to diversify its sources without severing its long-standing ties with Moscow.
According to the latest data, Hungary imported approximately 7.8 billion cubic metres of gas between October 2023 and September 2024, a substantial portion of which came from Russia. Hungary’s position diverges from the targets set at the European level.
Agreement signed under geopolitical pressure
The signing comes as the European Commission has announced plans to phase out Russian gas imports by the end of 2027. Brussels aims to ban new contracts as early as this year and gradually end all flows within two years.
In 2024, Russia still accounted for 19% of the European Union’s gas imports, including both pipeline gas and LNG. Engie, which holds long-term supply agreements in Algeria and the United States, stated that the agreement “helps Hungary and the region diversify their gas sources.”
Transatlantic tensions frame the deal
The transatlantic context adds a political layer to the transaction. U.S. President Donald Trump has expressed willingness to strengthen economic sanctions against Russia, contingent on a significant reduction in European purchases of Russian hydrocarbons.
Hungary, while expanding its diversification efforts, has not questioned its current contracts with Russia, citing economic stability and cost concerns. The contract with Engie could thus serve as a diplomatic lever without fundamentally altering the country’s energy structure.
https://energynews.pro/en/hungary-secures-10-year-lng-contract-with-engie-through-2038/
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Brazil’s Petrobras imports natural gas from Argentina for the first time
SAO PAULO/RIO DE JANEIRO, Oct 6 (Reuters) – Brazil’s state-controlled oil company Petrobras (PETR3.SA), has made its first import of non-conventional natural gas from Argentina’s Vaca Muerta reserve in the Neuquen basin, the company said on Monday.
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In a statement, the firm noted the natural gas was transported on Friday via pipelines from Argentina to Bolivia, and from there to Brazil, totaling 100,000 cubic meters of gas produced by companies POSA, its subsidiary in the country, and Pluspetrol.
The initiative fulfills the aspirations of Brazilian President Luiz Inacio Lula da Silva, who has been urging Petrobras to take steps to increase the domestic supply of natural gas, as he aims to reduce prices for consumers.
“This logistical and commercial solution opens a new possibility for importing natural gas into Brazil, reflecting Petrobras’ commitment to increasing supply and to the sustainable development of the natural gas market,” Director of Energy Transition and Sustainability Angelica Laureano said.
According to an agreement signed by the companies, Petrobras may import up to 2 million cubic meters of natural gas on an interruptible basis, the company said.
The transportation of natural gas from Argentina via Bolivia was extensively negotiated over the past year, in discussions that also involved the countries’ governments.
Petrobras was not the first Brazilian firm to carry out such an import. In April, TotalEnergies sent gas from Vaca Muerta to Matrix Energia in Sao Paulo via pipelines. That transaction moved 500,000 cubic meters per day over a 10-day period.
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Oman Commodity Trading Firm Takes Another Shot at LNG Expansion
Oman’s state-owned commodities trading firm plans to grow its liquefied natural gas business from a fraction of its portfolio to one of its biggest fuels through domestic and international deals. “LNG has to become one of our biggest products,” OQ Trading Chief Executive Wail Al Jamali said in an interview. “It’s the fuel of the future.”
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Oman has its own LNG production facilities run by the state and international companies, and this is not the first time Dubai-based OQT has looked to expand its trading of the super-chilled fuel. After a previous effort a few years ago that didn’t work out, the firm decided to redefine its trading team, Al Jamali said.
“We’re starting with a new team with new ideas,” he said. “It’s not our first stint in LNG but it’s the one that I’m personally leading.”
The firm traded 2 million tons of LNG last year. OQT has an agreement with Oman LNG to receive 750,000 tons a year for four years starting in 2026 and another for 600,000 tons a year from Mexico’s Amigo LNG, if the project comes to fruition. Oman plans to expand its LNG production with a fourth train by 2029, which may be another source of supply.
“Once we’re active with Oman LNG it makes it easier to start taking a bit more risk and putting some positions on and building a portfolio,” said Al Jamali. “We start local and then go global.”
OQT wants its enlarged LNG business to be on a par with its oil products and crude businesses, which together accounted for 96% of its volumes in 2024.
Aside from LNG, OQT is sizing up downstream oil acquisition targets that use distillate and gasoline, Al Jamali said. The firm took a stake in African fuel retailer Hass Petroleum in 2017, and would like to make a similar-but-larger investment using its own balance sheet and possibly in partnership with parent company OQ.
“We need a short where I can decide if I tender out to the market or I give some of it to my own trading entity,” said Al Jamali. “The size needs to be substantial. We are now trading 55 million tons so it needs to be something that moves the needle for us.”
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Vistra Advances Major Gas Fleet Acquisition with FERC Approval
Vistra Corp. has received key regulatory approval from the Federal Energy Regulatory Commission (FERC) for its planned acquisition of a 2,600-megawatt natural gas generation fleet from Lotus Infrastructure Partners. Vistra, a leading integrated retail electricity and power generation company, announced a significant step forward in its strategic expansion plans today, confirming that it has received crucial regulatory approval from the Federal Energy Regulatory Commission (FERC) for its previously announced acquisition of seven modern natural gas generation facilities.
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The highly anticipated transaction, which involves acquiring certain subsidiaries owning the facilities from Lotus Infrastructure Partners, is proceeding as planned and is expected to close either late this quarter or in the first quarter of 2026.
The fleet of assets is set to add approximately 2,600 megawatts (MW) of reliable generating capacity to Vistra’s already diverse portfolio. This capacity is distributed across seven facilities: five combined-cycle gas turbine plants and two combustion turbine plants. The strategic locations of these assets are a key component of the deal, as they are situated in major energy markets, including PJM, New England, New York, and California. By broadening its geographic footprint, Vistra aims to strengthen its ability to reliably serve customers across a wider area, a move that aligns with its focus on reliability and transforming the energy landscape.
Vistra’s announcement today highlighted not only the receipt of the FERC approval on October 2 but also the prior expiration of the waiting period mandated under the Hart-Scott-Rodino Antitrust Improvements Act of 1976 (HSR). These two milestones represent the clearance of major federal regulatory hurdles for the acquisition.
Despite these significant advancements, the transaction is not yet complete. Vistra noted that the acquisition remains subject to approval by the New York Public Service Commission and other customary closing conditions. Given the size and strategic importance of the assets in question, final state-level regulatory sign-off is a necessary next step.
First announced in May, this acquisition underscores Vistra’s commitment to maintaining a reliable, efficient power generation fleet that includes natural gas, nuclear, coal, solar, and battery energy storage facilities. The company, which operates from California to Maine and is headquartered in Irving, Texas, positions itself as a leader in transforming the energy landscape with an unyielding focus on reliability, affordability, and sustainability.
As Vistra moves closer to finalizing the deal, the integration of these modern gas generation units will enhance its operational flexibility and its capability to provide essential resources to customers, businesses, and communities.
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Ukraine: Naftogaz secures a 62 million euro loan to purchase natural gas
Ukraine’s state-owned energy utility, Naftogaz Group, has secured a 3 billion hryvnia (62 million euro) loan from Ukraine’s state-owned Oschadbank to purchase imported natural gas, announced CEO Sergii Koretskyi. Naftogaz and Oschadbank have partnered successfully for over 15 years.
Naftogaz secures a 62 million euro loan to purchase natural gas
“The need to import additional gas volumes arises due to massive enemy attacks on our gas infrastructure,” stated Sergii Koretskyi. “Together with our Ukrainian and international partners, we are working to mobilise financial and other resources to ensure a stable winter heating season amid Russia’s ongoing terrorist strikes. I thank the Ukrainian Government team and Oschadbank for their support.”
Ukraine received a 300 million euro loan from the EIB in early October, also for gas purchases. The European Bank for Reconstruction and Development (EBRD) had previously given Naftogaz a 500 million euro revolving loan for a similar purpose in August. This critical funding aims to increase the resilience of Ukraine’s energy sector and replenish long-term gas reserves ahead of winter.
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Argentina’s YPF, ENI finalize Vaca Muerta LNG deal
BUENOS AIRES, Oct 10 (Reuters) – Italy’s Eni and Argentina’s YPF have finalized a engineering agreement on a Vaca Muerta liquefied natural gas (LNG) project, they said in a presentation on Friday to sign the deal. Eni and YPF in June signed an initial accord to cooperate on the development of gas resources from the Vaca Muerta field in Argentina.
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Eni at that time said the deal would cover production, treatment, transportation and liquefaction of gas through floating units for a total capacity of 12 million metric tons per year.
“YPF will be responsible for the upstream, and we will be responsible for the floating liquefaction,” Eni CEO Claudio Descalzi said at the event on Friday. “We need to reach the market before 2029.”
YPF CEO Horacio Marin said the project will require drilling 800 new wells and aims to double the company’s 2024 gas production.
Marin estimated the initiative will need $25 billion in infrastructure investment and $15 billion for upstream development.
https://www.reuters.com/business/energy/argentinas-ypf-eni-finalize-vaca-muerta-lng-deal-2025-10-10/
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LNG as a Marine Fuel/Shipping
Japan: ORLEN completes first LNG delivery to Japan
ORLEN has completed its first delivery of 100 million m3 of natural gas to Japan, one of the world’s largest LNG importers. The new co-operation highlights ORLEN’s commercial and shipping capabilities and strengthens the group’s position in the global LNG market. The cargo was supplied to Osaka Gas and transported by gas carrier Ignacy Jan Padarewski, the newest vessel in ORLEN’s fleet.
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“For the first time in our history, we have delivered LNG to the Japanese market. We are consistently implementing the goals set out in our strategy. While pursuing our core business, we also reinforce the region’s energy security and independence. At the same time, we are expanding into markets where we have not previously operated, increasing our growth potential and building long-term value for our shareholders. The contract with Osaka Gas is an important milestone in our international growth and paves the way for future co-operation,” said Ireneusz Fafara, CEO and President of the ORLEN Management Board.
The delivery was carried out by gas carrier Ignacy Jan Padarewski, the newest addition to ORLEN’s fleet. This will be the 41st cargo handled by ORLEN’s London trading office with its own vessels, and the 15th in 2025. Ignacy Jan Paderewski entered service in Asia in 1H25 and returned to the region just a few months later with LNG from the US, further improving the efficiency of ORLEN’s trading operations.
“Working with reliable partners such as Osaka Gas allows us to build strong and effective relationships in the global LNG market. With a contract portfolio of about 6.5 million tpy over the coming years, we have the flexibility to ship cargoes to the most promising markets. Transactions such as the delivery to Japan are a natural part of our strategy to strengthen our trading position and confirm our growing role in the global LNG supply chain,” added Robert Soszynski, Vice President of the ORLEN Management Board.
https://www.lngindustry.com/lng-shipping/02102025/orlen-completes-first-lng-delivery-to-japan/amp/
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Canada: Shell-led LNG Canada Set to Load Second Unit’s First Cargo
Shell Plc.’s LNG Canada is currently on track to load its first liquefied natural gas cargo from the facility’s second unit as soon as this week as the project continues to ramp up in the next month, according to people familiar with the matter. The unit, known as Train 2, began activities to start on Tuesday, Bloomberg previously reported.
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Shippers were notified to have vessels ready as soon as early October to early November, according to the people, who asked not to be identified because the information is not public.
Train 2 start-up activities continue, according to an email from an LNG Canada spokesperson, who added that the project’s 15th cargo departed the facility Sunday.
The joint venture did not provide details on timing of the first cargo loading at Train 2.
The British Columbia facility is Canada’s first LNG project and is ramping up at a time when demand for gas is on the rise. The plant located along Canada’s west coast can help meet rising Asian demand and extend the nation’s position in the global LNG market.
Shell, the majority stakeholder in the project, earlier said that the two-train facility would ramp up to full capacity in 2026. Other stakeholders include Malaysia’s Petroliam Nasional Bhd., PetroChina Co., Mitsubishi Corp. and Korea Gas Corp.
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Egypt Asks LNG Shipments Be Delayed
Egypt is asking its liquefied natural gas suppliers to delay shipments scheduled for the rest of the year on weaker-than-expected demand. State-owned importer Egyptian Natural Gas Holding Co. has asked suppliers to defer at least 20 shipments slated for delivery through December, according to people with knowledge of the matter. The cargoes will be rescheduled for delivery in the first quarter of 2026, said the people, who asked not to be identified because the information isn’t public.
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Egypt’s energy ministry didn’t immediately respond to a request for comment outside of normal business hours.
The request comes as Egypt, which only became a net importer of the fuel in 2024 and more than doubled the amount of LNG it bought this year, struggles to assess its demand. The nation purchased a large volume of shipments earlier in 2025, with some of the deals having an element of flexibility.
Weaker imports into Egypt will help to free up supply for buyers in Europe, who have been forced to procure more LNG to replace Russian pipeline gas. This could help push down prices of the fuel.
https://www.rigzone.com/news/wire/egypt_asks_lng_shipments_be_delayed-10-oct-2025-182047-article/
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ExxonMobil to deliver LNG marine bunkering services
ExxonMobil is entering the LNG marine bunkering market, initially with two LNG bunker vessels, marking an important step in its efforts to help reduce greenhouse gas (GHG) emissions from the maritime sector. This move expands the company’s marine fuel portfolio of lower GHG emission options. Amy Wood, ExxonMobil Global Lower Emission Fuel Manager, commented: “Both LNG and bio-LNG can help reduce lifecycle GHG emissions compared with conventional marine fuels. As the maritime industry looks for scalable solutions to reduce GHG emissions, ExxonMobil is leveraging its skills and capabilities to deliver these fuel options.”
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With more than four decades of experience in LNG across the entire value chain, ExxonMobil brings deep expertise to this new venture. “Our combination of LNG expertise and a proven record as a trusted marine industry supplier is helping us deliver these fuel options. We’re entering the LNG bunker market, starting with two bunker vessels, which can provide the capability to supply both LNG and bio-LNG.”
The first vessel, chartered from Avenir LNG, is scheduled for delivery in 1Q27, followed by a second vessel from Evalend Shipping in 4Q27. These vessels will form the backbone of ExxonMobil’s initial LNG marine supply capability.
To help ensure continuity of service and meet customer needs ahead of the newbuild deliveries, ExxonMobil is actively developing complementary supply solutions. This approach enables early market entry and supports customers who are ready to adopt LNG as a marine fuel.
Supportive policies and rising demand for LNG in marine transportation are creating opportunities and ExxonMobil is positioned to serve marine customers by leveraging its integration, scale, and technical expertise.
While the initial deployment includes two vessels, ExxonMobil plans to expand its LNG bunkering fleet over time to support growing customer demand. This phased approach reflects the company’s long-term efforts to enable lower GHG emission marine fuels compared with conventional marine fuels at scale.
The LNG bunkering initiative is part of ExxonMobil’s broader plans to pursue up to US$30 billion in lower-emission solutions between 2025 and 2030, with about 65% directed towards reducing the emissions of other companies.
Amy Wood added: “We’re preparing for a multi-fuel future that helps meet society’s growing needs for energy and essential products, while helping to reduce GHG emissions.”
ExxonMobil emphasises that effective, technology-neutral policies are essential to accelerate the adoption of lower GHG emission marine fuels and drive innovation across the sector. These policy frameworks will be critical to scaling infrastructure, enabling innovative technologies and supporting the maritime industry’s energy transition.
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Technological Development for Cleaner and Greener Environment Hydrogen & Bio-Methane
Peru seeks input on rules to drive green hydrogen roll-out
Peru’s energy and mines ministry has opened consultation for the draft regulation of the green hydrogen promotion law. The proposed norm aims to establish the framework to regulate the development, implementation and supervision of activities contained in law 31992, which was published in March 2024 and amended a few months later.
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“Green hydrogen…is positioned as a key tool to address the challenges of the current energy landscape. This molecule emerges as an alternative to replace the use of natural gas and other fossil fuels,” according to the ministry.
“This change requires significant investments in infrastructure development and the adoption of associated technologies. It also creates the need for regulatory policies that promote the adoption of sustainable practices — socially, environmentally and economically — along the green hydrogen value chain.”
The ministry will accept comments for 15 calendar days at publicaciondgee@minem.gob.pe
The proposed regulation and supporting arguments are available in the Documents box in the right corner of the screen.
https://www.bnamericas.com/en/news/peru-seeks-input-on-rules-to-drive-green-hydrogen-roll-out
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SFU Clean Hydrogen Hub Joins Canadian Alliance of Hydrogen Hubs to Accelerate Clean Energy Innovation
Simon Fraser University’s Clean Hydrogen Hub has signed an agreement with three other leading Canadian hydrogen hubs conducting similar research and activities in developing hydrogen energy technologies.
The collaboration between SFU, Vallée de la Transition Énergétique (VTE, Québec), Newfoundland and Labrador Hydrogen Innovation Partnership (HyIP, Newfoundland), and the Edmonton Regional Hydrogen Hub (Alberta) will form the Pan-Canadian Alliance of Hydrogen Hubs, representing a major national milestone in advancing Canada’s leadership in clean hydrogen technologies. By linking hydrogen hubs from across Canada, the partnership aims to break down geographic barriers and leverage regional strengths, including the potential for interprovincial trade.
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The four partners have signed a memorandum of understanding (MOU), outlining their joint mission to accelerate the development of hydrogen technologies as a cornerstone of Canada’s transition to a low-carbon economy. Through collaboration, the hubs will grow a national hydrogen ecosystem to drive investment, scale breakthrough solutions, support workforce development, and ensure energy security and sustainability for generations to come.
The MOU outlines areas of mutual interest and cooperation, which include: supporting the advancement of hydrogen-related projects in each region; promoting the use, application, and commercialization of Canadian-developed hydrogen technologies; facilitating education, training, and community engagement at all levels; and ensuring knowledge transfer and sharing best practices across economic, financial, and technical domains.
“Simon Fraser University is thrilled to be a part of the Pan-Canadian Alliance of Hydrogen Hubs, a vital collaboration that will advance Canadian leadership in clean hydrogen technologies,” says Dugan O’Neil, SFU’s vice-president, research and innovation.
Climate Innovation is a strategic research priority for SFU, and the alliance furthers SFU’s commitments to engage in critical research partnerships that mobilize knowledge and support community-centred climate innovation. Aligned with Canada’s ambition to be a global energy superpower, the partnership will champion hydrogen as a critical pathway to net-zero, enabling cross-sectoral decarbonization, and enhance Canada’s international leadership in hydrogen energy innovation.
Hydrogen gas can be created cleanly from water via electrolysis and can be used as an alternative energy carrier or as an intermediary to create other products, such as clean methanol or ammonia. Unlike fossil fuel energy which releases CO2 into the atmosphere, the byproducts of electrolysis are water and oxygen, meaning that the use of hydrogen from sustainable sources can help dramatically reduce carbon emissions.
In September 2025, the federal government announced the first tranche of nation-building projects along with concepts for further development, which includes transformative strategies such as the Wind West Atlantic Energy project, a major wind power project in Nova Scotia.
The MOU builds on prior provincial joint initiatives such as the statement of co-operation on clean-energy solutions between BC and Newfoundland.
Hydrogen and its derivatives, produced from abundant clean electricity, can support federal export agreements, including the Canada-Germany Hydrogen Alliance being advanced by Natural Resources Canada, which presents an opportunity to develop transatlantic hydrogen hubs.
The four hubs allying in this MOU participated in a Transatlantic Hydrogen Hub Dialogue and exchange earlier in 2025 with the intent to further the exchange between Canadian and German regions on the development and expansion of hydrogen hubs. SFU seeks to advance the opportunity for BC-based technologies and expertise to partake in nation-building energy projects.
“Hydrogen represents a transformative opportunity for Canada to decarbonize our economy—spanning everything from production through to end use,” says Brent Lakeman, Executive Director, Edmonton Region Hydrogen Hub.
“Hydrogen hubs are at the forefront of this transition, catalyzing innovation and accelerating adoption. As Canada’s first hydrogen hub, the Edmonton region understands the importance of collaboration. By working together, sharing approaches, and building the infrastructure and workforce required, hubs across the country can help Canada realize hydrogen’s full potential in achieving a clean energy future.”
About the SFU Clean Hydrogen Hub
Based at Simon Fraser University, the Clean Hydrogen Hub is a one-megawatt testbed and global research and innovation platform dedicated to advancing hydrogen production, storage, and applications. The hub works across disciplines and sectors to reduce the costs of clean hydrogen production and co-develop technologies that will decarbonize Canada’s economy.
The Clean Hydrogen Hub is made possible through funding from PacifiCan, NorthX Climate Tech, FortisBC Energy Inc, the BC Ministry of Energy and Climate Solutions via the Innovative Clean Energy Fund, and the City of Burnaby.
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Throwback Thursday Story: CRRC Delivers 13 Large-Scale Electrolyzers to Cangzhou Green Hydrogen Port Project
CRRC Zhuzhou Institute has shipped 13 high-capacity 1,000Nm³/h electrolyzers to the Guohua Cangzhou Green Port Hydrogen City project, marking a key step in domestic hydrogen equipment scale-up. The units will support production of 100,000 tonnes of green ammonia per year and are expected to cut more than 400,000 tonnes of CO₂ emissions annually.
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CRRC Zhuzhou Institute has dispatched 13 of its independently developed 1,000Nm³/h electrolyzers to the Guohua Cangzhou Green Port Hydrogen City development, one of China’s flagship national demonstration projects. The delivery signals a milestone in the country’s effort to scale up homegrown hydrogen technology for industrial and port applications, with the installed equipment designed to flexibly operate across a 30–110% load range while maintaining stability and efficiency.
According to the company, the electrolyzers incorporate a “4-in-1” multi-tank parallel configuration alongside multi-level safety systems and advanced smart controls. This architecture, tested under variable load conditions, aims to boost reliability while allowing operators to fine-tune hydrogen production in line with renewable power inputs. The equipment will underpin the facility’s planned annual output of 100,000 tonnes of green ammonia, in turn offsetting over 400,000 tonnes of CO₂ per year.
CRRC says it will continue to innovate in areas such as electrolyzer-power matching, intelligent fault diagnostics, and unmanned factory operations to strengthen the competitiveness of China’s hydrogen equipment manufacturing base. The Cangzhou project itself forms part of Beijing’s broader dual carbon targets, with green hydrogen and ammonia positioned as core levers for cutting emissions in heavy industry and port logistics.
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OMV Starts Building Major EU Green Hydrogen Plant
OMV AG has laid the foundation stone for a 140-megawatt (MW) electrolyzer to produce up to 23,000 metric tons a year of hydrogen in Bruck an der Leitha, Lower Austria. Expected to start production 2027, it will be the biggest renewable hydrogen plant in Austria and Southeastern Europe and among the top five across the continent, Austria’s state-backed OMV said in a statement on its website. The plant’s electrolytic process to split water into hydrogen and oxygen will use wind, solar and hydro power.
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The plant will partly fuel OMV’s Schwechat refinery to cut carbon emissions by up to 150,000 metric tons per annum (MMtpa), around 10 percent of the refinery’s production-related emissions, OMV said.
The hydrogen facility and the refinery, which has a crude oil processing capacity of 9.6 MMtpa, will be connected via a 22-kilometer (13.67-mile) pipeline.
“OMV is investing a sum in the mid-hundreds of millions of euros in the plant”, the company said.
It said it is finalizing a funding agreement with the European Hydrogen Bank.
“We are creating an integrated ecosystem based on the use of green hydrogen – supported by technological innovation, modern infrastructure, political support and strong partnerships”, said chair and chief executive Alfred Stern. “Green hydrogen is a key component of our Strategy 2030 as a means of decarbonizing our fuel production and a key to OMV’s responsible transformation”.
OMV awarded Germany’s Siemens Energy AG the engineering, procurement and construction contract, including the supply of the plant’s electrolysis technology. OMV contracted Vienna-ased STRABAG AG for the civil construction work.
On April 30 OMV announced the start of production at its first commercial-scale green hydrogen facility, built with a capacity of 1,500 MMtpa at the Schwechat refinery. The plant uses a 10-MW PEM (polymer electrolyte membrane) electrolyzer powered by hydro, solar and wind energy.
The process avoids up to 15,000 metric tons of carbon dioxide (CO2) emissions a year, equivalent to the CO2 consumption of 2,000 persons per year based on a European Union average, according to OMV.
Output from the hydrogen plant will be used to decarbonize the refinery and produce more sustainable fuels and chemicals including sustainable aviation fuel and renewable diesel, OMV said.
Also on April 30 OMV and Abu Dhabi Future Energy Co PJSC (Masdar) said they had signed a letter of intent to collaborate on producing green hydrogen and derivatives.
The partnership would involve producing synthetic aviation fuel and other synthetic fuels, as well as synthetic chemicals, in Austria, the United Arab Emirates and northern and central Europe.
“By leveraging our combined capabilities, Masdar and OMV are looking to produce green hydrogen and derivatives at industrial scale, supporting decarbonization efforts and building the green hydrogen value chain”, Masdar chief green hydrogen officer Mohammad Abdelqader El Ramahi said.
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Italgas Opens Italy’s First Green Hydrogen Plant Integrated with City Gas Network
Located in Sestu, Sardinia, the solar-powered 500kW facility is expected to produce around 21 tonnes of hydrogen annually, increasing to 70 tonnes per year by 2028. The project, named Hyround, uses Power-to-Gas electrolysis technology to convert renewable electricity into hydrogen, which is then blended with natural gas and distributed to households, small businesses, and even a local dairy facility. Hydrogen from the site will also fuel a fleet of buses and supply an adjacent refuelling station funded in part by Italy’s National Recovery and Resilience Plan (PNRR).
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“Italgas’ Hyround confirms the central role of renewable gases and gas distribution networks as key elements of the energy transition,” said Paolo Gallo, CEO of Italgas Reti.
The €15 million investment includes €1.5 million ($1.6 million) in public funding from the PNRR and places Sardinia at the forefront of Italy’s hydrogen rollout strategy. The company’s leadership was joined at the ribbon-cutting by Minister of the Environment and Energy Security Gilberto Pichetto Fratin, alongside local and regional officials.
By integrating electrolysis, solar energy, and existing pipeline infrastructure, Hyround offers a live demonstration of how hydrogen can decarbonise distributed energy without waiting for a dedicated hydrogen grid. It also reflects growing EU support for using blended hydrogen in heating and transport applications as part of the broader gas network decarbonisation strategy. With national hydrogen production targets still in early stages, Italgas’ Sestu facility could set the tone for broader deployment of grid-integrated renewable hydrogen across Italy.
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A Bold New Blueprint for Economically Viable Solar Hydrogen
A review reimagines solar-driven water electrolysis not as a mere hydrogen production technology but instead as a relatively versatile platform for sustainable chemical manufacturing, according to Professor Fatwa F. Abdi from the School of Energy and Environment at City University of Hong Kong (CityUHK). This review article, published in Nature Reviews Clean Technology, argues that introducing high-value chemical syntheses into solar electrolysis systems could transform it from a cost-losing proposition into an economically compelling industry.
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The paper offers a bold new blueprint for using sunlight not just to make clean hydrogen but to produce high-value chemicals sustainably.
The problem today is that the chemical industry relies heavily on fossil fuels and energy-intensive processes.
But this review shows how solar-powered electrolysis can do better: on one hand, instead of wasting energy making low-value oxygen, we can replace that step with reactions that generate profitable products such as bioplastic precursors or specialty chemicals.
On the other hand, rather than simply collecting hydrogen gas, we can use it immediately to turn raw materials into useful compounds.
A crucial contribution is the call to match your technology to your market. Large-scale, centralized solar farms are perfect for mass-producing affordable, high-demand chemicals.
Meanwhile, smaller, flexible solar units are ideal for making expensive, low-volume specialty goods like pharmaceuticals or fine chemicals right where they’re needed the most.
“What we are suggesting is a cleaner chemical industry that doesn’t just cut emissions, but also stays economically viable,” explains Professor Abdi, whose research centers on turning sunlight directly into chemical energy through advanced photoelectrochemical systems and next-gen catalysts.
“Big centralized single-product plants make sense for cheap, high-demand chemicals. But expensive specialty chemicals are better produced in decentralized facilities that generate multiple products,” he points out.
“This isn’t just about making cleaner hydrogen, but making profitable hydrogen, since when solar electrolysis is turned into a chemical reactor, the whole system can pay for itself,” Professor Abdi says.
Laboratory demonstrations of these alternative reactions look promising. But scaling remains a challenge, which is why the researchers are calling for investment in pilot-scale systems and the use of advanced tools such as computer modeling and artificial intelligence to accelerate development.
They also emphasize the critical role of policy: carbon pricing, green chemistry subsidies, and tax incentives will be decisive in commercializing these technologies.
“This is the moment to align scientific innovation with market realities,” Professor Abdi adds.
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US research institute to invest R&D hub for hydrogen and carbon capture
US-based Honda Research Institute will spend $2.6m on a new Advanced Materials Science Lab which will support research and development for an array of next-generation technologies that could underpin future mobility solutions. Located on the Ohio State University SciTech Campus in Columbus, the facility will advance research in quantum technologies and other nanotechnologies, hydrogen fuel cells, carbon capture technologies, next-gen EV batteries and battery recycling.
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The campus is already home to Honda’s 99P Labs, which it established in 2018. The facility conducts research into energy and battery tech and mobility-related human-computer interaction.
“As Honda continues to invest in the future of mobility including what powers it, Ohio continues to be one of our most important centres of innovation,” said Dr Christopher Brooks, Chief Scientist and HRU-US division director.
The mobility giant has already made strides in the development of hydrogen fuel cell technology.
Earlier this year, Honda revealed the specs for its planned fuel cell module, which is scheduled to begin mass production in 2027. This will follow the scheduled mass production of a fuel cell generator in 2026.
Since March 2024, the company has also been conducting R&D into carbon capture facilities with the goal of commercialisation by the 2030s.
“Our goal with direct air capture technology is not only to achieve carbon neutrality for our corporate activities by 2050 but also to contribute to the broader societal goal of carbon neutrality,” stated Honda.
It is also working on a project called Dreamo, which is engineered microalgae that can absorb carbon dioxide. The idea is that this algae can grow rapidly (multiplying many times per day) and absorb emissions.
The plan is to supply CO2 emitted from boilers in Honda’s factories to algae cultivation facilities, capturing those emissions biologically.
This algae becomes CO2-rich biomass that can be used as feedstock for biofuels, plastics, or other materials.
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