NGS’ NG/LNG SNAPSHOT July 16-31, 2025
National News Internatonal News
NATIONAL NEWS
City Gas Distribution & Auto LPG
Gujarat tops in domestic PNG adoption against non-Ujjwala LPG connections
Ahmedabad: Gujarat is nearing 36 lakh domestic piped natural gas (PNG) connections till April 2025, according to data from the Petroleum Planning and Analysis Cell (PPAC) of the Ministry of Petroleum and Natural Gas. Another data set that points to growing domestic PNG use is from the Petroleum and Natural Gas Regulatory Board (PNGRB). It says that Gujarat has a 39.7% share or 32.88 lakh domestic PNG connections against non-Ujjwala LPG connections of 82.75 lakh in the state. PPAC has put the number of domestic PNG connections at 35.93 lakh as of April 30, 2025.
Although Maharashtra has the highest number of domestic PNG connections at 40.42 lakh according to PPAC, Gujarat tops the country in terms of domestic PNG connections against non-Ujjwala LPG connections with around 39%, which is far higher than Maharashtra’s 14%.
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PPAC states that Gujarat is a clear leader in the adoption of PNG by commercial and industrial users. India has a total of 45,518 commercial PNG connections, out of which 24,122 are in Gujarat. Out of 20,556 industrial PNG connections nationwide, Gujarat has 5,851 connections at the end of April 2025.
Milind Torawane, MD of Gujarat Gas Ltd, said, “Gujarat has always been a leader in the PNG segment, and over the years, the position has become stronger. Gujarat had early discoveries of natural gas in Ankleshwar, Dahej, and Hazira, and PNG adoption started decades ago. In the last two decades, we have seen significant PNG adoption, and the main reason is the state govt’s policy, which has supported the growth of PNG connections. The pipeline network is key infrastructure, and the state enabled it widely in the last two decades. Also, 70% of the country’s imported gas lands at Gujarat ports, which also plays an important role. It is user-friendly, so people have adopted this quickly in Gujarat because of infrastructure availability, and in new buildings in cities, gas connection has become a new normal.”
Sources said that PNG adoption has been slower in the country than expected, and the govt is taking various steps to increase the share of gas as fuel in the country’s energy basket.
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₹1,950 crore CGD project in Bankura, Purulia to be completed by FY30
The Rs 1,950 crore City Gas Distribution (CGD) project in West Bengal’s Bankura and Purulia districts aims to provide Piped Natural Gas (PNG) connections to 555,000 households, over 250 commercial units, and more than 35 industrial consumers, officials said.
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Prime Minister Narendra Modi on Friday laid the foundation stone for the project that aims to provide Piped Natural Gas (PNG) to both retail households and industrial projects in the two districts of West Bengal.
The project will establish 29 Compressed Natural Gas (CNG) stations for vehicular fuel across the two districts in line with authorisation from the Petroleum and Natural Gas Regulatory Board (PNGRB), a statement said.
The project is scheduled for completion by March 15, 2030. Once operational, it is expected to serve a population of over 65 lakh with cleaner, reliable, and cost-effective fuel solutions, Bharat Petroleum said.
According to BPCL Director (Refineries) and acting Chairman & Managing Director, Sanjay Khanna, the initiative marks a significant step towards expanding access to clean and affordable energy in India.
The project is also expected to create over 15 lakh man-days of direct and indirect employment, supporting local economies in Bankura and Purulia.
The CGD network will contribute to India’s net-zero ambitions by promoting natural gas as a cleaner alternative to traditional fuels.
It is projected to cut greenhouse gas emissions by 27 per cent, or 191,000 metric tonnes over 25 years equivalent to planting nearly 3.46 lakh trees annually.
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Megha Gas commissions mother station in Sambhal, Uttar Pradesh
In a notable development, Megha City Gas Distribution Private Limited has commissioned mother station at Balaji Filing Station, Babrala in Sambhal district of Uttar Pradesh. Besides, it has also inaugurated its ninth compressed natural gas (CNG) station on national highway (NH-509) in partnership with Balaji Filing Station.
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The Petroleum and Natural Gas Regulatory Board (PNGRB) has authorised Megha Gas to lay city gas distribution (CGD) infrastructure in 62 districts across 22 geographic areas (GA) in ten states of Andhra Pradesh, Telangana, Tamil Nadu, Karnataka, Odisha, Maharashtra, Madhya Pradesh, Punjab, Rajasthan and Uttar Pradesh.
More information:https://cgdindia.net/megha-gas-commissions-mother-station-in-sambhal-uttar-pradesh/
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Natural Gas/ Pipelines/ Company News
“More than 25 lakh families will benefit”: Hardeep Singh Puri on inauguration of 132 km natural gas pipeline in West Bengal
Durgarpur (West Bengal) [India], July 19 (ANI): Union Minister for Petroleum and Natural Gas, Hardeep Singh Puri, said that the newly inaugurated 132 km natural gas pipeline in West Bengal will benefit more than 25 lakh families, underlining the Prime Minister Narendra Modi’s vision of ‘One Nation One Gas Grid.’
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Addressing the public in Durgapur on Tuesday, Hardeep Singh Puri said that the government has increased the gas pipeline to 25,000 km, which was 1500 km in 2014.
“Until 2014, the country had only 15,000 km of natural gas pipelines. PM Modi ji decided that we have to build 33,500 km of pipeline by 2030. Today, we can proudly say that we have increased it to almost 25,000 km,” he said.
“Today, the inauguration of a 132 km long gas pipeline by the auspicious hands of the Prime Minister is a part of this chain. More than 25 lakh families will get the benefit of natural gas. This is clean energy and more affordable,” he added.
Later, in a post on X, Hardeep Singh Puri said that a gas pipeline becomes the “development line” for any region it passes through.
“The gas pipeline becomes the ‘development line’ for any region it passes through. This project will ensure a smooth supply of natural gas to millions of households in the region,” he said on X.
On Tuesday, PM Modi inaugurated and dedicated to the nation development projects worth over Rs 5,400 crore in Durgapur, West Bengal, including the 132 km long natural gas pipeline.
Underlining that in the past 10-11 years, India has made unprecedented progress in gas connectivity, the Prime Minister stated that LPG has reached households across the country during this decade, earning global recognition.
He emphasised the government’s work on the “One Nation, One Gas Grid” vision and the launch of the Pradhan Mantri Urja Ganga Yojana. Under this initiative, gas pipelines are being laid across six eastern states, including West Bengal
Noting that the goal is to deliver affordable piped gas to industries and kitchens in these states, the Prime Minister remarked that gas availability will enable vehicles to run on CNG and industries to adopt gas-based technologies. He expressed satisfaction that Durgapur’s industrial region has now become part of the National Gas Grid.
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India-US energy ties: GAIL eyes deal with Donald Trump championed Alaska LNG project; New Delhi’s push to import natural gas
State-owned gas utility GAIL Ltd has entered initial discussions to import liquefied natural gas (LNG) from the proposed Alaska LNG project. India is in talks with energy developer Glenfarne as it looks to boost energy imports from the United States. The move is aimed at reducing its trade surplus with Washington and is part of a wider effort to strike a trade deal that could help avoid steep US tariffs, as per Reuters.
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However, sources familiar with the matter said the viability of any deal will hinge on the landed cost of gas from Alaska, which is a key factor in GAIL’s decision-making process.
While Glenfarne declined to confirm discussions with GAIL, it told Reuters in an that “Alaska LNG’s growing commercial momentum reflects the project’s competitive economic and geostrategic advantages.”
The $44-billion Alaska LNG project, which has struggled to get off the ground for over a decade and was backed by US President Donald Trump, recently gained attention after Thailand’s state-owned PTT signed a 20-year deal to purchase 2 million tonnes of LNG annually.
So far, around 50 companies have expressed interest in the project, which is expected to export up to 20 million tonnes of LNG per year. A final investment decision on the first phase, a 765-mile pipeline transporting gas from Alaska’s northern fields to the Anchorage region, is expected later this year.
India, the world’s fourth-largest LNG importer, is aiming to increase the share of natural gas in its energy mix from 6% to 15% by 2030 as part of its efforts to cut carbon emissions. GAIL, which already holds long-term contracts for 15.5 million tonnes of LNG annually, including 5.8 million tonnes from the US, is planning to expand its domestic import capacity.
The company intends to raise the capacity of its Dabhol terminal from 5 million tonnes to 6.3 million tonnes by mid-2027 and to 12.5 million tonnes by 2031-32, Reuters reported.
Earlier this year, GAIL also sought bids to acquire equity in an existing or upcoming LNG project, due for commissioning by 2030.
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Mahanagar Gas to invest Rs 1,500 crore in battery, biogas ventures to diversify beyond CNG
Mumbai’s Mahanagar Gas Limited plans to diversify its operations. The company will invest ₹1,500 crore in new energy segments. This includes setting up a battery manufacturing unit and a compressed biogas production facility. The company has partnered with International Battery Company for a giga factory in Karnataka. Construction is scheduled to begin later this quarter.
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New Delhi: Mumbai-based natural gas distribution company Mahanagar Gas Limited – a unit of public sector undertaking GAIL – is investing about ₹1,500 crore, along with partners, to set up a battery manufacturing unit and a compressed biogas production facility over the next two years in a bid to diversify operations.
Mahanagar Gas Ltd managing director Ashu Shinghal told ET that, amid the government push towards cleaner mobility solutions, the company is looking to expand its footprint in non-fossil fuel options and has earmarked capital for a foray into new energy segments.
He said, “At present, almost 70% of our revenues come from CNG. We conducted a study along with BCG. In essence, going forward, we have determined we will be present in at least one non-fossil fuel-related segment to secure growth opportunities in future.”
The company has already forged a joint venture with US-based International Battery Company to set up a giga factory in Karnataka. The government has completed land allocation for the project, construction for which is scheduled to commence later this quarter. MGL and IBC together are investing around ₹900 crore to set up the facility, which is expected to be commissioned by the end of next year. The investments will be made by IBC and MGL in proportion to their stake in the JV (ratio of 60:40).
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Pipeline Infrastructure Ltd and Crown LNG partner for Kakinada gas connectivity
Under the agreement, Crown LNG’s proposed 7.2 MTPA Gravity-based Structure and Regasification Unit (GBSRU) at Kakinada will be connected with the PIL pipeline. Pipeline Infrastructure Ltd (PIL) and Crown LNG Holdings Ltd have signed an initial agreement to establish crucial pipeline connectivity between Crown LNG’s proposed terminal and PIL’s existing pipeline network in Kakinada, Andhra Pradesh, according to a PTI report.
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The agreement was signed on July 10 by Akhil Mehrotra, Managing Director of PIL, and Swapan Kataria, CEO of Crown LNG Holdings Ltd, marking a significant step in expanding gas access in the region.
Under the terms of the agreement, Crown LNG’s proposed 7.2 MTPA Gravity-based Structure and Regasification Unit (GBSRU) at Kakinada will be connected with the PIL pipeline. This connectivity is contingent upon the satisfaction of various terms and conditions, the joint statement said.
PIL, a special-purpose vehicle under the Energy Infrastructure Trust (InvIT), currently owns and operates a vital 1,400-km pipeline stretching from Kakinada to Baruch in Gujarat.
This extensive network is currently utilised by major players like Reliance Industries Ltd for transporting natural gas from offshore fields to end-users across the country.
With this latest agreement, Crown LNG will now also be able to leverage PIL’s robust pipeline infrastructure for the efficient transportation of its imported natural gas, further diversifying the sources of gas supply within India.
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GAIL’s Jamnagar-Loni Pipeline Gears Up for 100% Expansion to Meet Soaring LPG Demand
New Delhi: In a major development for India’s petroleum infrastructure, GAIL (India) Limited has received the Petroleum and Natural Gas Regulatory Board’s (PNGRB) approval to double the capacity of its flagship Jamnagar-Loni LPG pipeline (JLPL). The current capacity of 3.25 MMTPA will now be expanded to 6.5 MMTPA, reinforcing GAIL’s dominance in the LPG transmission segment.
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GAIL’s Longest Pipeline Enters Next Phase of Growth
The JLPL pipeline, India’s longest LPG pipeline, is already operating at full capacity. With LPG demand witnessing a consistent annual growth of 6% over the last decade, GAIL’s decision to expand the pipeline comes at a strategically critical time. The increased capacity is expected to address future surges in domestic LPG consumption and ensure uninterrupted supply to key distribution zones.
Three-Year Deadline Set for Project Completion
As per PNGRB’s authorization terms, GAIL is expected to complete the expansion project within three years. This move is likely to significantly augment GAIL’s business performance while contributing to the government’s larger energy access and infrastructure goals.
About GAIL (India) Ltd
GAIL (India) Limited is India’s leading natural gas company with diversified operations across gas transmission, LPG production, petrochemicals, city gas distribution, and E&P. The company owns and operates over 13,000 km of natural gas pipelines and is playing a key role in building a gas-based economy for the country.
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Policy Matters/ Gas Pricing/ Others
PNGRB flags anomalies in PNG pricing to domestic consumers
According to the PNGRB, some city gas distribution entities have been using a telescopic pricing structure—a model where the per-standard cubic meter (SCM) price of PNG increases once consumption crosses a specified threshold. The Petroleum and Natural Gas Regulatory Board (PNGRB) has identified irregularities in the pricing practices adopted by certain city gas distribution (CGD) companies supplying piped natural gas (PNG) to domestic households.
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In a public notice issued on July 14, 2025, the board called for immediate corrective action to ensure fairness and compliance with regulations.
According to the PNGRB, some CGD entities have been using a telescopic pricing structure—a model where the per-standard cubic meter (SCM) price of PNG increases once consumption crosses a specified threshold. “Such pricing practices may inadvertently facilitate the unauthorised use of subsidised APM gas by commercial consumers who may be misclassified as domestic consumers,” the notice stated.
At the heart of the issue is, the Administered Price Mechanism (APM) gas, which is supplied to CGD companies at concessional rates to promote affordable clean energy access for households and the transport sector.
The Ministry of Petroleum and Natural Gas had issued clear guidelines in August 2022 mandating the allocation of APM gas for domestic PNG and CNG transport use. The Board observed that the uniform APM procurement price was not being passed on uniformly to end consumers. Instead, genuine domestic households with higher usage — often due to larger families or specific energy needs — were being charged steeper tariffs, undermining the spirit of the subsidy framework.
To address these discrepancies, the PNGRB has directed all CGD companies to:
Review consumption patterns to detect anomalies, particularly unusually high usage inconsistent with typical household consumption.
Investigate and rectify misclassifications, ensuring that commercial establishments do not access subsidized domestic gas.
Implement uniform pricing for PNG supplied to all domestic households, regardless of consumption levels.
The Board emphasised that such measures are necessary to uphold equity, transparency, and consumer interest, as enshrined in Chapter III, Section 11 of the PNGRB Act, which mandates fostering fair trade and competition in the sector.
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PNGRB directs city gas companies to stop volume-based differential pricing
The Petroleum and Natural Gas Regulatory Board (PNGRB) has directed city gas distributors to cease differential pricing for household piped natural gas (PNG). This directive aims to eliminate the practice of charging higher rates based on consumption levels.
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PNGRB approves pivotal reforms in natural gas pipeline tariff regulationsANI
New Delhi: The Petroleum and Natural Gas Regulatory Board (PNGRB) has directed city gas companies to charge a uniform rate for household fuel, regardless of consumption levels, in a bid to end the practice of some firms charging higher prices beyond a certain usage threshold.
“It has come to the Board’s notice that certain city gas distribution (CGD) entities are implementing a telescopic pricing structure for piped natural gas (PNG) domestic consumers, wherein the per SCM (Standard Cubic Meter) price of natural gas escalates as consumption surpasses a predefined threshold,” the downstream regulator said. “Such pricing practices may inadvertently facilitate the unauthorized use of subsidized administered price mechanism (APM) gas by commercial consumers who may be misclassified as domestic consumers.”
The regulator further said that “genuine domestic consumers with higher consumption levels may be unfairly subjected to elevated charges,” despite the government supplying natural gas to CGD entities at a uniform rate.
The domestic gas is sold to companies “at a concessional rate compared to market or spot LNG prices,” the regulator said.
PNGRB also advised city gas companies to undertake a thorough review of consumption patterns and “investigate anomalous cases where domestic consumers exhibit significantly higher usage relative to industry average” and, based on the findings, take suitable corrective measures.
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Supply PNG to households at a uniform rate, PNGRB tells CGD firms
The Petroleum and Natural Gas Regulatory Board (PNGRB) has directed City Gas Distribution (CGD) entities to supply piped natural gas at a uniform rate to all domestic household consumers, irrespective of their daily consumption levels. The oil regulator said this taking note of a telescopic pricing structure for piped natural gas domestic consumers that certain CGD entities are implementing in which the per standard cubic metre (SCM) price of the gas escalates as consumption goes past a predefined threshold.
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“Such pricing practices may inadvertently facilitate unauthorised use of subsidised APM (administered pricing mechanism) gas by commercial consumers who may be misclassified as domestic consumers. Additionally, genuine domestic consumers with higher consumption levels may be unfairly subjected to elevated charges, despite natural gas being supplied to CGD entities at a uniform APM rate,” PNGRB said.
Advising CGD firms to undertake a “thorough review of consumption patterns and investigate anomalous cases where domestic consumers exhibit significantly higher usage relative to industry average,” PNGRB said based on the findings, suitable corrective measures should be instituted as per the regulations.
It also cited the government guideline under which the natural gas allocation is made at a concessional rate compared to market or spot LNG prices with an aim to promote the adoption of the fuel across domestic households and transport sector.
Differential pricing of fuel and the resultant challenges, however, are not uncommon in the oil industry with the national oil companies in the past grappling with diversification of the heavily subsidised liquefied petroleum gas (LPG) cylinders. Meant for use only by households, the 14.2 kg cylinder in the past found its way to commercial establishments such as tea stalls, eateries and restaurants. Eventually, it was through a combination of measures, from change in the pricing structure, direct benefit transfer to targetted subsidy, the menace was reined in to a large extent.
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Rajasthan Cabinet clears City Gas Distribution Policy-2025 to promote clean energy access
Minister Sumit Godara informed that the Rajasthan City Gas Distribution (CGD) Policy-2025 has been approved to promote a gas-based economy. The Rajasthan Cabinet, chaired by Chief Minister Bhajan Lal Sharma, held a meeting on Monday at the Chief Minister’s Office and approved several key decisions aimed at encouraging planned urban development, promoting medical tourism, advancing the energy sector including renewable energy, and enhancing employee welfare.
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A significant decision among these was the approval of the Rajasthan City Gas Distribution (CGD) Policy-2025, which seeks to strengthen the gas-based energy framework within the state.
Minister Sumit Godara informed that the Rajasthan City Gas Distribution (CGD) Policy-2025 has been approved to promote a gas-based economy. The policy is designed to facilitate the supply of clean, safe, and environment-friendly natural gas to the general public while helping to reduce carbon emissions across the state.
He stated that the implementation of this policy will lead to increased investment in the infrastructure for City Gas Distribution (CGD). It will also support the expansion of PNG (Piped Natural Gas) and CNG (Compressed Natural Gas) networks, particularly in small towns and urban areas that currently lack access to such facilities.
To streamline the regulatory process, the policy introduces simplified and time-bound procedures for CGD companies. It focuses on easing the processes for obtaining permissions, land allocation, and government approvals required to set up and operate gas infrastructure in Rajasthan.
By making these steps more efficient, the policy aims to remove bureaucratic delays and promote a more business-friendly environment for investors and energy companies.
Single-window system in place
As part of the implementation mechanism, the policy also mandates the development of a dedicated CGD portal. This digital platform will serve as a single-window system to manage all applications, track approval status, and provide necessary information to stakeholders. The portal is expected to improve transparency, accountability, and operational speed in handling CGD-related activities.
The Rajasthan City Gas Distribution Policy-2025 will remain in effect until March 31, 2029, or until another policy is introduced to replace it. This five-year validity gives the government a framework for mid-term review and course correction, if needed.
The policy supports the state’s broader goal of transitioning to cleaner sources of energy and reducing its dependence on conventional fossil fuels. It is aligned with national-level objectives of expanding the use of natural gas in residential, industrial, and transportation sectors.
By increasing access to natural gas, especially in regions previously underserved, the policy is expected to bring multiple benefits—environmental sustainability, public health improvements, and economic investment in energy infrastructure.
In conclusion, the approval of the CGD Policy-2025 marks a step forward in Rajasthan’s clean energy agenda. It creates a clear pathway for expanding natural gas infrastructure, simplifies processes for companies, and lays the groundwork for cleaner urban energy consumption across the state.
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India taking steady, confident steps towards oil self-sufficiency: Hardeep Singh Puri
Petroleum and Natural Gas Minister Hardeep Singh Puri today said, India is taking steady, confident steps towards oil self-sufficiency. In a social media post the minister said the country is securing its energy future, step by step. He informed that one million square km offshore area is now open for oilfield exploration and 99 percent of ‘No-Go’ areas have been cleared. Mr Puri highlighted that this is a great time for entrepreneurs and industry leaders to look at oil and gas exploration in India. He emphasised that the country’s city gas distribution networks have ushered in a revolution.
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Govt to make 5-year policy to promote CNG, piped gas
Jaipur: The state govt will prepare a five-year action plan for infrastructure development and facility expansion to promote domestic piped natural gas (DPNG) and compressed natural gas (CNG). Principal secretary (mines and petroleum) T Ravikanth said Tuesday that as per the budgetary announcement, a target has been set to provide DPNG connections to 1.25 lakh homes and start 89 new CNG stations this year. While preparing the action plan for the next five years, the targets set by the Union petroleum and natural gas ministry will also have to be kept in mind, he said.
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In a meeting with representatives of 13 CGD (city gas distribution) service providers, he urged them to take measures to ensure compliance with safety standards, especially of vehicles used in transportation of CNG-PNG.
State govt has already introduced a CGD policy to promote green energy and ecosysytem.
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LNG Use / LNG Development and Shipping
GAIL inks long term LNG sales & purchase agreement with Vitol Asia
Under the agreement, Vitol will deliver LNG to GAIL from its global LNG portfolio; the deal follows the signing of a binding term sheet between the two firms in January last year, GAIL said. State-run GAIL announced on Monday that it has executed a long-term LNG Sales and Purchase Agreement (SPA) with Vitol Asia for supplying around 1 Million Tonnes Per Annum (MTPA) of Liquefied Natural Gas (LNG) over a period of about 10 years, beginning 2026.
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Under the agreement, Vitol will deliver LNG to GAIL from its global LNG portfolio. The deal follows the signing of a binding term sheet between the two firms in January last year, the country’s largest gas utility said.
Speaking on the occasion, Sanjay Kumar, Director (Marketing) at GAIL, said” GAIL is expanding its long-term LNG portfolio to meet demand growth. We are pleased to partner with Vitol Asia and this agreement represents a key milestone in reinforcing GAIL’s capability to reliably serve its diverse and evolving customer base.”
Jay Ng, Chief Financial Officer of Vitol Asia and Executive Committee Member, said, “Vitol is honoured to extend its relationship with GAIL to a long term LNG supply contract. The growing Indian market is core to Vitol’s strategy and Vitol’s diversified portfolio enables it to offer India a stable supply of cleaner and competitive energy.”
India emerged as the world’s fourth-largest LNG importer in 2024, with demand expected to rise steadily over the next decade. The Government of India has set an ambitious target to increase the share of natural gas in the country’s primary energy mix from the current 6 per cent to 15 per cent by 2030. Supporting this vision, India’s LNG regasification capacity has seen substantial growth, nearly doubling from 21 MTPA in 2014.
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Deepak Fertilisers Enters ₹1,200 Crore LNG Regasification Agreement with Petronet LNG
Deepak Fertilisers and Petrochemicals Corporation Limited (DFPCL) has entered a long-term agreement with Petronet LNG Limited (PLL) for the regasification of Liquefied Natural Gas (LNG). The contract, valued at ₹1,200 crore with a potential additional outlay of up to 20% over its five-year duration, will see Petronet LNG regasify approximately 25 TBTUs of LNG annually, primarily at its Dahej terminal, after an initial ramp-up period. The regasified gas will be supplied to DFPCL’s manufacturing facilities at Taloja for internal consumption.
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Strategic Implications
The agreement ensures a stable supply of regasified LNG for Deepak Fertilisers’ manufacturing units at Taloja, enhancing operational efficiency and reliability. By securing a long-term regasification arrangement, DFPCL mitigates potential supply chain disruptions and price volatility associated with natural gas.
Operational Details
Petronet LNG will primarily utilize its Dahej terminal for the regasification process. The contract involves an initial ramp-up period, after which the full annual capacity of 25 TBTUs will be regasified. The regasified gas will be used internally by DFPCL for its manufacturing processes.
Financial Considerations
The contract is valued at ₹1,200 crore, with a provision for an additional outlay of up to 20% over the five-year period. This financial commitment underscores the strategic importance of a reliable LNG supply for DFPCL’s operations.
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India’s HPCL seeks 10 LNG cargoes for March 2026-December 2027 delivery, sources say
SINGAPORE, July 21 (Reuters) – India’s Hindustan Petroleum Corp (HPCL) has issued a tender seeking 10 cargoes of liquefied natural gas (LNG) for delivery from March 2026 to December 2027 to its Chhara import terminal in western India, two industry sources said on Monday.
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HPCL is seeking one cargo per month for delivery in March, April, October and November in 2026, and in February, April, June, August, October and December in 2027, added one of the sources.
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ONGC board approves true-up amount of up to ₹5,082 cr for Mozambique LNG project
The Area 1 Mozambique Project, located in the Rovuma Basin, is a significant natural gas discovery with substantial potential. However, in the recent past, the Mozambique project has faced disruptions due to security concerns. ONGC is actively working towards restarting the project. Shares of ONGC closed marginally higher at ₹246.40 on BSE.
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The board of state-owned energy giant Oil and Natural Gas Corporation Ltd (ONGC) on Tuesday, July 22, approved a true-up amount of up to ₹5,082 crore that will be spent over FY26-27 by subsidiaries of ONGC Videsh involved in the Area 1 Mozambique LNG project, according to a stock exchange filing.
ONGC Videsh has 16% participating interest in Area 1 Mozambique project and it is managed through its stepdown companies – ONGC Videsh Rovuma (OVRL) and Beas Rovuma Energy Mozambique (BREML), the update said.
The company’s board has approved the receipt of the true-up amount, which is payment or adjustment made for estimated costs, of up to ₹5082.39 crore from the LNG project in Mozambique. In particular, BREML would incur ₹1,270.62 crore and ₹635.31 crore during 2025-26 and 2026-27, respectively, the company said.
ONGC Videsh Rovuma would incur a true-up amount of ₹2,117.61 crore and ₹1,058.85 crore during 2025-26 and 2026-27, respectively.
In April, the company initiated a postal ballot seeking shareholder approval for critical financial undertakings related to its operations in Mozambique. The company had planned to advance up to ₹1,500 crore from OVL to BREML, a joint venture subsidiary.
The Area 1 Mozambique Project, located in the Rovuma Basin, is a significant natural gas discovery with substantial potential. However, in the recent past, the Mozambique project has faced disruptions due to security concerns. ONGC is actively working towards restarting the project.
Separately, the majority of the analysts tracking the company in May projected up to a 50% upside on ONGC shares after the company reported its fourth quarter earnings. ONGC reported a net profit of ₹6,448 crore in the March quarter, which was below Street estimates of ₹8,804 crore, and down 22% from the previous quarter’s ₹8,240 crore.
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Ashok Leyland fuels LNG boom in trucks, eyes tie-ups with city gas giants
The plan is being floated as the Petroleum and Natural Gas Regulatory Board (PNGRB) is expecting a multi-fold jump in the number of LNG trucks from 700 at present to 500,000 by 2040. Commercial vehicle major Ashok Leyland is in talks with leading city gas distribution companies to ensure the availability of liquefied natural gas (LNG) in their compressed natural gas (CNG) retail outlets, according to a top company executive.
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The plan is being floated as the Petroleum and Natural Gas Regulatory Board (PNGRB) is expecting a multi-fold jump in the number of LNG trucks from 700 at present to 500,000 by 2040. “Original equipment manufacturers and customers are talking about the availability of fuel stations. We find that many city gas distribution (CGD) companies are getting into selling both CNG and LNG in the same fuel station. We are in talks with Adani, AG&P Pratham, Think Gas, and Mahanagar Gas to ensure the availability of LNG once the market evolves,” Sanjeev Kumar, president, MHCV business of Ashok Leyland, told Business Standard.
At present, India is in the process of expanding the LNG infrastructure through setting up stations along major highways and the Golden Quadrilateral. “The penetration of LNG is very slow now. There is a definite advantage in terms of total cost of ownership (TCO) of a vehicle when it comes to LNG over diesel. This is a new concept where a fuel pump can provide both CNG as well as LNG. The chemical formula is the same; the only question is about how you store the gas. We feel that at some point of time, it will start picking up,” Kumar added.
According to the plan, CGD firms will enter into a tripartite deal with OEMs, along with prospective customers and fleet owners. “They are looking for some tripartite agreement, where they are sure about the supply of vehicles by OEMs, and some sense coming from their customers in terms of putting up vehicles,” he said. At present, companies like Tata Motors, Ashok Leyland, and Blue Energy Motors are mainly offering LNG-powered trucks.
Kumar also batted for complete LNG corridors to be in place for the segment to pick up. “We have seen major developments happening in the West, and some in the South also. Unless one complete corridor is in place, it will be difficult for operators also,” he added. The company is looking at all options of alternate fuels now.
According to a demand assessment study conducted by the PNGRB, India is expected to see a rise in LNG trucks in the next 15 years as the fuel offers to reduce user consumption and cut carbon emissions in the freight sector. The study says that LNG trucks in India may increase from around 700 trucks in FY24 to nearly 200,000 by 2040 in a Good-to-Go (GtG) scenario and to 500,000 in a high-growth Good-to-Best (GtB) scenario. Interestingly, China already has a network of around 800,000 trucks and 6,000 refuelling stations.
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Petronet seeks $1.4 bn loan to fund petrochemical plant, LNG terminal
Local lenders including Axis Bank, State Bank of India and Union Bank of India are considering to join the facility, which is among the company’s largest fundraising exercises. India’s largest importer of natural gas Petronet LNG Ltd. is seeking a loan of at least 120 billion rupees ($1.4 billion) for a new petrochemical plant and an LNG terminal, according to people familiar with the matter.
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Local lenders including Axis Bank, State Bank of India and Union Bank of India are considering to join the facility, which is among the company’s largest fundraising exercises, said the people, who asked not to be identified discussing private matters. The borrower is seeking bids from banks in groups or individually, they said, adding that SBI Capital Markets has been appointed as adviser for the deal.
The facility for triple-A rated Petronet comes at a period of muted activity for India’s loans space, where bank lending grew 9.5per cent as of June 27, the lowest growth rate since March 2022, according to the latest data from the Reserve Bank of India. If the financing goes through, it would be one of the biggest local currency loans for the country this year, according to Bloomberg-compiled data.
Spokespeople for Axis Bank, Petronet, SBI, SBI Capital Markets and Union Bank of India didn’t immediately reply to emails from Bloomberg News seeking comment.
Proceeds from the loan will partially fund the construction of a new petrochemical complex in Dahej, located in the southwest coast of Gujarat in India, the people said, adding that it will help diversify the company’s earnings beyond the LNG space. The project is estimated to cost 206.85 billion rupees, according to the company’s website.
The New Delhi-based firm is also setting up a separate five million tons land-based LNG import terminal at Gopalpur, located on the east coast in Odisha.
The latest loan could carry a tenor of more than 10 years, the people said. The pricing could be lower than SBI’s one-month marginal cost of funds based lending rate of 7.95per cent currently, a benchmark gauge of local currency borrowings, two of the people said.
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Electric Mobility/ Hydrogen/Bio-Methane
STL leads the way in sustainable optical fibre manufacturing with Green Hydrogen
MUMBAI, India, July 17, 2025 /PRNewswire/ — STL (Sterlite Technologies Ltd.) (NSE: STLTECH), a global leader in optical and digital solutions, has achieved a major milestone in sustainable manufacturing by collaborating with Hygenco for Maharashtra’s first green hydrogen and green oxygen production facility for optical fibre. The green hydrogen project, centred in Chhatrapati Sambhaji Nagar, Maharashtra, will supply green hydrogen and oxygen to STL’s glass preform facility.
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This green hydrogen facility will enable STL to become one of the world’s first optical fibre manufacturers to deploy 100% green hydrogen in its production processes and support its goal to achieve Net Zero by 2030. Hygenco will build, own and operate the facility, ensuring a reliable and commercially viable supply for 20 years.
Speaking on the successful commissioning of the green hydrogen plant, Rahul Puri, CEO – Optical Networking Business, STL, said, “By leveraging 100% green hydrogen for its glass preform manufacturing, STL is setting a new global benchmark for decarbonization in the optical fibre industry. Our collaboration with Hygenco exemplifies our commitment towards sustainability and operational excellence. We are proud to lead the way in integrating green hydrogen into large-scale manufacturing and look forward to continuing our efforts to build a greener, more resilient future for India and the world.” “Green Hydrogen has the potential to be a game-changer in India’s journey towards sustainability. Our long-term engagement with STL represents a bold step forward in decarbonising industrial processes. We are proud to enable STL to lead the global optical fibre industry into a new era of green manufacturing,” said Amit Bansal, CEO, Hygenco Green Energies Pvt. Ltd.
STL’s semiconductor-grade Glass Preform manufacturing facility in Chhatrapati Sambhaji Nagar is Industry 4.0-enabled plant. It focuses on producing Glass Preforms, essential for creating high-quality optical fibres. Hydrogen and oxygen play a vital role in the optical fibre manufacturing process, serving as fuel in blast furnaces to convert silica particles into glass. Through a strategic Green Hydrogen collaboration with Hygenco, STL aims to reduce carbon emissions by ~30% annually. The plant now features advanced autonomous energy management systems, real-time monitoring, and automated control technologies, enhancing safety and operational efficiency.
About STL – Sterlite Technologies Ltd: STL is a leading global optical and digital solutions company providing advanced offerings to build 5G, Rural, FTTx, Enterprise and Data Centre networks.
Read more, Contact us, stl.tech | Twitter | LinkedIn| YouTube About Hygenco Green Energies Pvt. Ltd: Hygenco develops scaled up commercially attractive green hydrogen and green ammonia assets. Hygenco is determined to invest US$2.5 billion over next 3 years and targets to commission 10 GW of green hydrogen and ammonia assets by 2030.
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‘Andhra Pradesh to be a Green Hydrogen Valley’ – Declared Honourable CM Sri Chandrababu Naidu at the Green Hydrogen Summit 2025, SRM AP
Amaravati, Andhra Pradesh, India (NewsVoir) The Honourable Chief Minister of Andhra Pradesh, Sri Nara Chandrababu Naidu, inaugurated the Green Hydrogen Summit-2025 at SRM University-AP. Dr V K Saraswat, Member of NITI Aayog, Dr Chandra Sekhar Pemmasani, Minister of State for Rural Development and Communications, Govt. of India, Sri K Vijayanand IAS, Chief Secretary, Govt. of Andhra Pradesh, and Dr P Sathyanarayananan, Pro-Chancellor of SRM University-AP, graced the event as the guests of honour. The two-day summit involved government agencies, researchers, policymakers and industrialists to address the critical need for a clean energy transition for a cleaner, more sustainable and forward-looking future.
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In his inaugural address, the Honourable CM Sri Nara Chandrababu Naidu termed the Green Hydrogen Summit, a historical forum that brought together global experts and industries in Andhra Pradesh to work towards affordable, cost-effective clean energy. He stated that with the Andhra Pradesh Green Hydrogen and Green Ammonia Policy, with a Rs 10,00,000 crore investment, offering 7.5 lakh jobs in green hydrogen and its derivatives, and ideological balance, no other state has stronger prospects in working towards green hydrogen development and storage. He also declared Amaravati as Green Hydrogen Valley, which will focus on affordable, cost-effective clean energy. He said, “This landmark summit marks a significant step towards protecting nature, a circular economy, and sustainability.” Guest of Honour, Dr V K Saraswat, Honourable Member, NITI Aayog commented on the significance of opting for cleaner fuels and energy resources. He said, “Green Hydrogen, which is at the heart of the National Hydrogen Mission, is a step towards achieving a sustainable, carbon-neutral future.” Prof. D Narayana Rao, Executive Director-Research, SRM Group of Institutions, in his brief about the Summit stated, “Today the world looks at India with admiration as we contribute to solving global issues plaguing humankind, such as clean energy, water remediation, clean environment, and sustainable growth.” He outlined the various initiatives by the ministries of the state – Road Transport and Highways, Petroleum and Natural Gas, Steel – have already taken up green hydrogen projects that align with their sector. He also said SRM University-AP will establish an Innovation centre for Green Hydrogen Technologies.
With a vision to develop Andhra Pradesh as a hydrogen hub, Dr Chandra Sekhar Pemmasani, Minister of State for Rural Development and Communications, Govt. of India, remarked that right investments and government policies can drive green hydrogen plants to produce clean energy that is scalable and profitable. The Chief Secretary of the State, Sri K Vijayanand IAS, also remarked that the development and utilisation of hydrogen technologies necessitate specific expertise and skill development. The top universities of the nation, such as SRM AP, with advanced research infrastructure and intellect, can innovate and solve the pressing demands for cleaner energy fuel.
Mr Pranav Tanti, CEO and President of Synergen Green Energy also said that Andhra Pradesh is a highly favourable state to establish an industry for Green Hydrogen.
Aiming to nurture innovation and skill development in the clean energy space, Dr P Sathyanarayanan, Pro-Chancellor of SRM AP, announced the Department of Energy Engineering launch at the SRM Institute of Emerging Technology. “If our generation is the last to use fossil fuels, the next generation must lead the clean energy revolution. With their ideas, innovation, and courage, the youth will carry this transformation forward,” Commented Dr P Sathyanarayanan.
The Green Hydrogen Summit 2025, jointly organised by SRM University-AP, Government of Andhra Pradesh, IIT Tirupati, IISER Tirupati, Ministry of New and Renewable Energy, Govt. of India, New & Renewable Energy Development Corporation of Andhra Pradesh Ltd. and the SRM Institute of Science and Technology, Tamil Nadu, explores the research and development, innovation, commercialisation of green hydrogen. Keynote addresses, plenary sessions and conclaves with industry stalwarts, research organisations, and policymakers aim to open new frontiers in the green hydrogen sector.
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SRM University to develop a green hydrogen car
SRM University of Amaravati, is aiming at develop a ‘Green Hydrogen’ powered car within the next three years, which will be tested on the National Highway between Guntur and Vijayawada, revealed Dr. D. Narayana Rao, Executive Director – Research of the university. Dr. Narayana Rao told The Hindu, on the concluding day (Saturday) of the two-day ‘Green Hydrogen Summit-2025‘ held at Neerukonda in Amaravati capital city, that the university aims to reduce the cost of producing green hydrogen from the current ₹350 to ₹200 per kilogram in the next couple of years. We also seek to lower the electricity consumption required to produce one kilogram of green hydrogen from the present demand of 50 units to 40 units. As assured to Chief Minister Nara Chandrababu Naidu during the Summit’s inaugural session, the University is committed to engaging all stakeholders in the sector to produce affordable green hydrogen in the State and contribute to developing Andhra Pradesh as a hub for this technology.
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Transport sector
Mr. Narayana Rao further explained that green hydrogen, with its remarkable attributes, such as high energy density has wide- ranging applications in different sectors including transportation. He predicted that in the next three years, hydrogen powered cars, buses, JCBs, trains and airplanes will be a reality in India and globally.
He said: “Today, steel industries worldwide use coal, but, green hydrogen can serve as an excellent substitute. Steel produced using green hydrogen is known as green steel, and European countries now insist on importing only green steel. So, it is imperative for countries involved in bulk production of steel to transition to hydrogen in the coming years.”
Pudimadaka hub
He explained that the government of India has launched the National Hydrogen Mission (NHM) with an impressive outlay of ₹19,750 crore. The key objectives of NHM are indigenous manufacturing of electrolysers, particularly pressurised alkaline electrolysers, fuel cells, creating job opportunities and to produce 5 million metric tonnes of green hydrogen by 2030. These goals present both opportunities and challenges before industry, national research institutions and universities. Aligning with the NHM, the government of Andhra Pradesh has taken swift steps to developing Pudimadaka near Visakhapatnam as a green hydrogen hub. The target set by Mr. Naidu for this hub is to produce 1.5 million metric tonnes of green hydrogen and 3 lakh tonnes of green ammonia.
Objectives of SRM University Amaravati
Dr. Rao explained that, “The first goal of SRM University is developing a hydrogen powered combustion engine for the car.” He expressed hope that an automobile manufacturer would come forward to develop such a car. He added that, the Ministry of Railways has already developed a hydrogen-powered fuel cell-based train with ten coaches and they will be demonstrating it in September 2025, between the Jind-Sonipat route in Haryana.
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MCD set to roll out biogas plants in dairy colonies
First plant in Nangli Dairy to start in August; project aims to process cattle dung into CNG and manure, cutting off key waste source polluting the river. NEW DELHI: In a bid to curb pollution in the Yamuna River, the Municipal Corporation of Delhi (MCD) is installing biogas plants in dairy colonies to process cattle dung and prevent it from entering the drainage system.
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The first such plant, located at Nangli Dairy, will begin operations from August, with similar projects underway in Goyla and Ghoga dairies, officials said. Chairperson of the Standing Committee, Satya Sharma, said this initiative is part of a larger plan to ensure scientific management of organic waste, particularly from dairy clusters that have long been a source of pollution.
She added that Chief Minister Rekha Gupta had recently directed the MCD to take concrete steps to reduce waste flowing into the Yamuna, prompting the civic agency to expedite all related works.
According to MCD officials, over 1,500 dairies operate in Nangli and Goyla areas, generating substantial amounts of cattle dung. At present, a significant portion of this waste flows untreated through small drains into the Najafgarh Drain, which connects directly to the Yamuna. Once operational, the biogas plants will process dung into energy and manure, effectively cutting off a key source of river pollution.
The biogas plant in Nangli is set to go live in August, while work in Goyla and Ghoga dairies is expected to be completed by next year. “Officials have been directed to ensure there are no delays in setting up and operating these units,” Sharma said. Apart from aiding Yamuna cleaning efforts, the plants are also expected to help control foul odors, improve hygiene, and promote the use of clean energy. “These plants are a sustainable step toward environmental protection and align with the Delhi government’s vision of a cleaner, greener and waste-free city,” she added.
Each plant, built at an estimated cost of Rs 16 crore, will process up to 200 MT of cattle dung per day. The biogas generated will be converted into CNG, reducing dependence on fossil fuels, while the byproduct — organic manure — will be used in MCD’s horticulture operations.
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L&T to build India’s maiden green hydrogen plant at IOC’s refinery
The plant will run round-the-clock using renewable energy to supply 10,000 tonnes of green hydrogen annually to IOC for 25 years, a crucial step in India’s National Green Hydrogen Mission. L&T Energy GreenTech, a subsidiary of Larsen & Toubro will be setting up India’s maiden green hydrogen plant at Indian Oil’s Panipat refinery in Haryana on a build-own-operate basis, a company filing said on July 21.
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The plant will run round-the-clock using renewable energy to supply 10,000 tonnes of green hydrogen annually to IOC for 25 years, a crucial step in India’s National Green Hydrogen Mission. This also aligns with IOC’s strategy to decarbonise refining operations and add to India’s net-zero ambitions. At the plant, green hydrogen will be produced using high-pressure alkaline electrolysers, made at Hazira-based L&T Electrolysers. The step sets up LTEG to be a key player in the green hydrogen ecosystem, setting a precedent for industrial-scale adoption across refineries, fertilisers, and other sectors.
Subramaniam Sarma, Deputy Managing Director & President, L&T said the project “not only deepens our partnership with IOC but also reinforces our capability to deliver large-scale clean energy solutions.”
Green hydrogen is essentially the hydrogen gas produced by splitting water using renewable energy sources. The project marks IOC’s entry into the green hydrogen space, with India’s largest-ever green hydrogen project to date. The project is slated to be commissioned by December 2027 and the green hydrogen produced here will replace fossil-derived hydrogen in IOC’s refinery operations, reducing carbon emissions.
Previously, IOC had cancelled two tenders, following very little interest from the industry to develop the project. The tender was first floated on September 2024, and the deadline was pushed twice to January 2025, on participating companies’ insistence.
“This project reflects our end-to-end green energy capabilities — from electrolyser manufacturing to execution and operation. With cutting-edge technology and a skilled team, we are confident of delivering a high-performance, zero-emission plant that sets new industry benchmarks,” said Derek Shah, Head – Green Manufacturing & Development, L&T.
Shares of L&T are sharply off early lows, in line with the broader market rebound, while shares of IOC are trading flat on July 21.
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IIT-BHU scientists develop green hydrogen from sugarcane waste
The research team isolated successfully a novel hydrogen-producing bacterial strain, alcaligenes ammonioxydans SRAM, from sewage sludge wastewater. In a major breakthrough in sustainable energy research, scientists at Indian Institute of Technology (BHU) have developed an innovative method for producing green hydrogen using sugarcane biomass waste and a newly isolated bacterial strain.
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The pioneering research, conducted at Biomolecular Engineering Laboratory of the School of Biochemical Engineering, has been published in leading international journals, including International Journal of Hydrogen Energy and Fuel.
According to Prof Abha Mishra, lead investigator and in charge of the laboratory, as well as associate dean (research and development) at IIT (BHU), the development has positioned the institute at the forefront of global biohydrogen innovation.
The research team isolated successfully a novel hydrogen-producing bacterial strain, alcaligenes ammonioxydans SRAM, from sewage sludge wastewater. The strain demonstrated exceptional efficiency in converting sugarcane bagasse-an abundant agricultural waste in India’s largest sugarcane-producing state, UP-into hydrogen gas.
“The strain showed excellent potential for large-scale application. It serves as an efficient biocatalyst capable of transforming lignocellulosic biomass into clean energy,” said Prof. Mishra.
The bacterium, now officially registered in the NCBI GenBank, produces hydrogen through dark fermentation-a low-energy, anaerobic process that offers both economic and environmental benefits.
Alongside hydrogen, the bacterium also showed potential for producing eco-friendly biopolymers, opening avenues for sustainable material development. A patent application has been filed to secure the intellectual property of the innovation. To optimise the hydrogen yield, the team employed advanced computational tools such as ANN-MATLAB and Python-based modelling. These tools helped fine-tune key parameters, enhancing reproducibility and efficiency of the process.
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Kerala’s ANERT gets nod to become renewable energy hub; to offer training, hydrogen pilot projects
Training programmes for stakeholders – including technicians, students, local bodies, and government departments – will cover cutting-edge subjects like AI/ML in renewable energy, circular economy, hydrogen energy, and blockchain. Kerala’s Agency for Non-conventional Energy and Rural Technology (ANERT), an autonomous organisation to gather and disseminate useful knowledge in various fields of non-conventional energy, energy conservation, and others, is set to transform into a Knowledge Hub for Renewable Energy, following administrative approval of its latest plan schemes.
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The proposals focus on strengthening research, innovation, training, and green hydrogen infrastructure.
As per the decision, ANERT will offer research fellowships and internships for fresh postgraduates in science and engineering to bridge the shortage of trained manpower in the renewable energy sector.
Selected candidates will receive a stipend of ₹15,000 per month for internships, while research fellowships will follow KSCSTE norms.
Training programmes for stakeholders – including technicians, students, local bodies, and government departments – will cover cutting-edge subjects like AI/ML in renewable energy, circular economy, hydrogen energy, and blockchain.
Faculty Development Programmes and high-end short-term training for academics and officials are also planned, in collaboration with global agencies such as GIZ Germany and SIDA.
In a major push towards clean fuels, ANERT’s Green Energy Hub project will feature pilot initiatives on green hydrogen production, storage, and refuelling.
A Centre of Excellence for Green Hydrogen is planned in partnership with premier institutions like IITs and CSIR labs.
Viability Gap Funding (VGF) will be offered to ensure cost-effective hydrogen generation from renewable energy sources.
The total funding requirement for the current year is ₹6.5 crore, including ₹5.66 crore in State share and ₹84 lakh for manpower and project overheads.
ANERT’s revamped initiatives mark a major stride towards Kerala’s green transition and skill development.
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L&T to build India’s maiden green hydrogen plant at IOC’s refinery
The plant will run round-the-clock using renewable energy to supply 10,000 tonnes of green hydrogen annually to IOC for 25 years, a crucial step in India’s National Green Hydrogen Mission.L&T Energy GreenTech, a subsidiary of Larsen & Toubro will be setting up India’s maiden green hydrogen plant at Indian Oil’s Panipat refinery in Haryana on a build-own-operate basis, a company filing said on July 21.
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The plant will run round-the-clock using renewable energy to supply 10,000 tonnes of green hydrogen annually to IOC for 25 years, a crucial step in India’s National Green Hydrogen Mission. This also aligns with IOC’s strategy to decarbonise refining operations and add to India’s net-zero ambitions. At the plant, green hydrogen will be produced using high-pressure alkaline electrolysers, made at Hazira-based L&T Electrolysers. The step sets up LTEG to be a key player in the green hydrogen ecosystem, setting a precedent for industrial-scale adoption across refineries, fertilisers, and other sectors.
Subramaniam Sarma, Deputy Managing Director & President, L&T said the project “not only deepens our partnership with IOC but also reinforces our capability to deliver large-scale clean energy solutions.”
Green hydrogen is essentially the hydrogen gas produced by splitting water using renewable energy sources. The project marks IOC’s entry into the green hydrogen space, with India’s largest-ever green hydrogen project to date. The project is slated to be commissioned by December 2027 and the green hydrogen produced here will replace fossil-derived hydrogen in IOC’s refinery operations, reducing carbon emissions.
Previously, IOC had cancelled two tenders, following very little interest from the industry to develop the project. The tender was first floated on September 2024, and the deadline was pushed twice to January 2025, on participating companies’ insistence.
“This project reflects our end-to-end green energy capabilities — from electrolyser manufacturing to execution and operation. With cutting-edge technology and a skilled team, we are confident of delivering a high-performance, zero-emission plant that sets new industry benchmarks,” said Derek Shah, Head – Green Manufacturing & Development, L&T.
Shares of L&T are sharply off early lows, in line with the broader market rebound, while shares of IOC are trading flat on July 21.
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India’s first hydrogen-powered train coach successfully tested at ICF Chennai: Union Minister Ashwini Vaishnaw
According to the Union Railway Minister Ashwini Vaishnaw’s social media X post, the country is working on a 1,200 horsepower hydrogen train, which will help India to place itself amongst the leaders in hydrogen-powered train technology. Union Railway Minister Ashwini Vaishnaw on Friday (July 25, 2025) announced that the Indian Railways has successfully tested the country’s First hydrogen-powered coach at the Integral Coach Factory (ICF) in Chennai.
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According to the Minister’s social media X post, the country is working on a 1,200 horsepower hydrogen train, which will help India to place itself amongst the leaders in hydrogen-powered train technology
.”First Hydrogen powered coach (Driving Power Car) successfully tested at ICF, Chennai. India is developing 1,200 HP Hydrogen train. This will place India among the leaders in Hydrogen powered train technology,” Mr. Vaishnaw posted on ‘X’
.In 2023, Mr. Vaishnaw informed Rajya Sabha that Indian Railways has envisaged running 35 Hydrogen trains under “Hydrogen for Heritage” at an estimated cost of ₹80 crore per train and ground infrastructure of Rs 70 crore per route on various heritage and hill routes.
Additionally, the Indian Railways has also awarded a pilot project for retrofitment of a Hydrogen Fuel cell on an existing Diesel Electric Multiple Unit (DEMU) rake along with ground infrastructure at the cost of ₹111.83 crores, which is planned to be run on the Jind-Sonipat section of Northern Railway.
The running cost of a Hydrogen fuel-based train is not established in IR scenario. It is estimated that the initial running cost of the Hydrogen fuel train set will be higher, which will subsequently reduce with an increase in the number of trains. Further, the use of Hydrogen as fuel provides larger benefits in the direction of green transportation technology to support zero carbon emission goals as a clean energy source.
Last year, in a significant step towards promoting sustainable transportation solutions, Hardeep Singh Puri, Minister of Petroleum & Natural Gas, showcased India’s advancements in green hydrogen mobility by demonstrating a hydrogen-fuelled bus powered by India’s oil PSU Indian Oil to the Prime Minister of Bhutan, Shri Tshering Tobgay and his delegation.
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INTERNATIONAL NEWS
Natural Gas / Transnational Pipelines/ Others
US: Tallgrass Launches Open Season for New Permian Gas Pipeline
(P&GJ) — Tallgrass has launched a binding open season to solicit shipper commitments for firm transportation service on a planned new natural gas pipeline connecting the Permian Basin to multiple U.S. markets. The open season began July 21, 2025, and will allow shippers to secure capacity to transport Permian Basin gas to Rockies Express Pipeline (REX) markets and other delivery points as outlined in the open season terms.
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According to Tallgrass, the project is designed to expand access to affordable natural gas for key U.S. industrial, agricultural, and data center markets.
“By connecting the Permian Basin to Rockies Express and multiple delivery points, this project will enable affordable and plentiful natural gas to access markets broadly across the U.S., including multiple major markets that are key hubs of activity for industrial, agricultural, and data center development,” Tallgrass said in the announcement.
Prospective shippers are encouraged to contact John Garnsey at Permian@Tallgrass.com or by phone at +1 (720) 730-2524 to complete a confidentiality agreement and obtain additional project details, including rates, terms, and conditions of service.
https://pgjonline.com/news/2025/july/tallgrass-launches-open-season-for-new-permian-gas-pipeline
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Brazil: Equinor wins installation licence for major Brazil gas pre-salt pipeline
Production from the Raia field in the Campos basin is expected to begin in 2028. Norwegian oil giant Equinor has obtained a key licence to begin installation activities at a big ultra-deepwater development in Brazil’s Campos basin.
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Equinor plans to have the Raia pre-salt field on stream in 2028 via a floating production, storage and offloading vessel to be supplied by Japanese player Modec.
The project will be a game-changer in Brazil, as the Raia development will be the first to treat gas offshore and be connected to the national grid without further onshore processing.
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German: Pipeline Consortium Lands Major German Energy Project
A consortium led by Friedrich Vorwerk Group SE has secured a substantial pipeline contract from Gasunie Deutschland, a transmission system operator, to construct the 86-kilometer (53-mile) ETL 182 energy transmission conduit. The order, valued in the mid-hundreds of millions of euros, is a joint venture between the Friedrich Vorwerk Group (Friedrich Vorwerk and Bohlen & Doyen) and Austria’s HABAU Group (PPS Pipeline Systems and HABAU).
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Preparatory construction is slated to begin in late 2025, with main construction expected in 2026, aiming for commissioning in 2027.
The ETL 182 pipeline is critical to meet the anticipated surge in gas transport demand driven by new liquefied natural gas (LNG) import terminals in Brunsbüttel and Stade/Bützfleth.
The pipeline, with a planned diameter of DN 1400, will link the “Elbe Süd” network point in the Stade district with “Achim” in the Verden district, facilitating nationwide transmission across Germany’s natural gas network.
This project is deemed essential for ensuring a secure and diversified gas supply in Germany, with the German federal government’s LNG Acceleration Act underscoring its energy industry necessity for both households and industrial sectors.
Friedrich Vorwerk anticipates sustained high demand in pipeline construction due to ongoing plans to connect new natural gas power plants and LNG import terminals, as well as the proposed 9,040-kilometer (5,617-mile) hydrogen core network.
The company highlights its extensive service and technology portfolio, alongside decades of experience, as key factors in addressing future energy infrastructure needs.
https://www.pipeline-journal.net/news/pipeline-consortium-lands-major-german-energy-project
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Africa: New Pipeline Deals to End Africa’s Energy Poverty
Shifting from dirty fossil fuels to cleaner, renewable energy is the ultimate goal of the global Just Transition campaign. But, Africa has another priority: eradicate energy poverty first. New cross-border oil and gas pipeline projects aim to do just that, as a means of supporting Africa’s unique transition to the global Just Transition agenda. More than 600 million Africans still lack access to electricity, and 900 million are without clean cooking solutions, according to a 2024 World Bank fact sheet.
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Yet, Africa is sitting on 125 billion barrels of crude oil and 620 trillion cubic feet of natural gas.
“This very statistic has led the citizens of Africa, not only corporations, to rally behind the call to ‘make energy poverty history,” said African Energy Chamber Executive Chairman NJ Ayuk in a statement.
“And it is large-scale oil and gas projects that will achieve this goal.”
While the global Just Transition advocates for a shift from fossil fuels to green energy, Africa is grappling with another priority that continues to stir debate around a central question.
How can Africa transition fairly, addressing energy poverty by utilising the continent’s vast, largely untapped oil and gas reserves, without abruptly abandoning economies that still rely heavily on fossil fuels?
Renowned scholar and policy strategist, Professor Arthur G.O. Mutambara, champions a Global South-led approach to the Just Energy transition, urging developing nations to reject external dictates that fail to consider their countries’ unique development realities.
In an excerpt in his April 2025 book, Artificial Intelligence: A Driver of Inclusive Development and Shared Prosperity for the Global South, Mutambara emphasises that while the shift from fossil fuels to renewable energy is essential, it must be done on terms defined by the Global South, with equity, dignity, and development at the core.
He also argues that the number one issue for the Global South is addressing energy poverty.
“If to eradicate energy poverty, citizens of these economies must burn fossil fuels for a couple more decades, so be it,” he argues in the book.
As activists around the world — and across Africa — continue to demand an immediate push away from fossil fuels, Africa is seeing a rise in cross-border oil and gas pipelines.
Recent advancements include: the signing of a bilateral oil pipeline agreement between the Republic of Congo and Russia; an agreement between Nigeria and Equatorial Guinea to fast-track a joint natural gas pipeline; and an announcement that the East African Crude Oil Pipeline (EACOP) has exceeded 50% completion rate, are among significant milestones recorded over the second quarter of 2025.
According to the latest update on the construction of EACOP in Uganda and Tanzania, the pipeline is progressing well with a continued focus on safety, environmental sustainability, and local community engagement.’
The 1,443-km EACOP is set to link Uganda’s oil fields in the Lake Albert region to the port of Tanga in Tanzania, facilitating the export of up to 246,000 barrels per day.
TotalEnergies (62%) is the project’s key shareholder, with Uganda National Oil Company Limited (UNOC) and Tanzania Petroleum Development Corporation (TPDC) each holding 15% shares. Upon completion, the project will be the longest heated crude oil pipeline in the world.
As countries push to expand access to natural gas energy and reduce reliance on biomass, regional pipelines capitalise on the continent’s abundant hydrocarbon resources.
“New pipelines have the potential to deliver LPG and natural gas to underserved regions, reducing dependence on biomass and accelerating the shift toward cleaner household and industrial energy,” said Ayuk.
In June, the Republic of Congo finalised a pipeline cooperation agreement with Russia, laying the foundation for the Pointe-Noire-Loutete-Maloukou-Trechot oil pipeline.
The deal encompasses joint planning, financing, construction, and operation, and is expected to be executed within three years.
In the same month, Nigeria and Equatorial Guinea signed a bilateral agreement to expedite the development of a joint natural gas pipeline, known as the Gulf of Guinea Gas Pipeline (GOGGP).
The cross-border project is expected to boost regional gas trade, expand export capacity, and support the transition to cleaner energy sources.
“This is more than just a treaty; it is a shared economic vision between two friendly nations. Nigeria stands ready to collaborate fully with Equatorial Guinea to make the GOGGP a reality,” said Nigeria’s Minister of State for Petroleum Resources (Gas), Rt. Hon. Ekperikpe Ekpo during the signing of the agreement in Nigeria.
To illuminate Africa’s energy narrative, the annual Africa Energy Week, scheduled for the end of September and early October, has strategically incorporated a Just Energy Concert on the eve of the main event.
“The just energy transition concert aims to inspire a new era of innovation, celebration and progress across Africa’s energy sector by integrating two promising industries: culture and energy,” said the Organisers of the event on their website.
Beyond new projects, existing infrastructure players are also expanding their roles. The West African Gas Pipeline Company (WAGPco), backed by Chevron and other shareholders early in the year, began routine maintenance on the pipeline to ensure it continues to deliver Nigerian gas to Benin, Togo, and Ghana, supporting electricity generation and industrial energy needs across the region.
During the West African Gas Pipeline Committee of Ministers (CoMs) meeting in Accra in April, WAPCo Managing Director, Michelle Burkett, called for stronger collaboration among member states and stressed the urgency of coordinated action to stabilise gas flow and drive energy security in the sub-region.
“Our ability to fully unlock the WAGP’s potential, is increasingly shaped by the collective effort from all stakeholders,” said Burkett.
In southern Africa, the Republic of Mozambique Pipeline Investments Company, which operates the Mozambique–South Africa Gas Pipeline, recently opened a new office in Maputo. The move is part of a broader strategy to deepen regional integration and improve gas distribution systems.
“It reinforces our strategic focus on sustainability, reliability, and regional integration in the energy sector. It also supports our goal of ensuring a stable, uninterrupted energy supply, not only for Mozambique but for the entire Southern African region,” said the Republic of Mozambique Pipeline Investments Company (ROMPCO) Chief Executive Officer, Mlandzeni Boyce.
The momentum behind these regional pipeline projects coincides with plans to operationalise the US$5 billion African Energy Bank (AEB) this year.
Established by the African Petroleum Producers’ Organisation (APPO) and the African Export-Import Bank (Afreximbank), the AEB will offer tailored financing solutions to help close funding gaps for oil and gas project developments across the continent.
https://newscentral.africa/new-pipeline-deals-to-end-africas-energy-poverty/
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Congo: Azule Energy announces major offshore gas discovery in the Angolan Congo Basin
The Azule Energy consortium has identified a significant gas and condensate field during Angola’s first exploration drilling dedicated to gas, marking a milestone for the country’s energy sector. Azule Energy, a joint venture bringing together BP, Eni and a group of Angolan companies, has revealed the discovery of a major natural gas and condensate field in block 1/14, located in the Lower Congo Basin. This announcement was made by the country’s Agência Nacional de Petróleo, Gás e Biocombustíveis (ANGP – National Agency of Petroleum, Gas and Biofuels), highlighting the unprecedented nature of this drilling, which was fully dedicated to gas exploration.
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A first for Angolan gas exploration
The Gajajeira-01 well enabled the identification of rock layers containing both gas and condensates, according to initial information provided by Azule Energy. Discovered gas volumes could reach 1 trillion cubic feet, while associated condensate reserves are estimated at one hundred million barrels. This is the very first exploration well specifically designed for gas exploration in the country, representing a notable development for the local industry.
Block 1/14, where the discovery was made, is operated jointly by Equinor, holding 30%, Sonangol Pesquisa e Produção (E&P) with 25%, and the private Angolan company Acrep S.A., which holds 10%. The remaining shares are divided among the partners of the Azule Energy consortium. The partnership between international operators and national companies illustrates the collaborative dynamic structuring Angola’s oil and gas sector.
Congo Basin potential and sector outlook
Azule Energy Chief Executive Officer Adriano Mongini described this step as “historic” for the country’s gas exploration, according to a statement released by the company. He highlighted that this success confirms the potential of the Lower Congo Basin, a region already known for its oil reserves and now recognised for its gas resources.
Next phases will include further assessments to determine the commercially recoverable volume of the field. This discovery comes as Angola seeks to diversify its energy resources and strengthen the exploitation of its non-oil deposits. The ANGP indicated that the drilling campaign in block 1/14 will continue with other exploration wells targeting identified gas formations.
Confirmation of such a significant gas volume in a region previously underexplored for this resource is attracting the interest of international operators present in the country. According to ANGP, the discovery made by the consortium led by Azule Energy could lead to new phases of development in the Congo Basin.
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Africa: Technip Energies signs major contract for floating natural gas unit in Africa
Technip Energies has secured a contract to lead preparatory works for a floating liquefied natural gas unit in Africa, confirming its presence in the international gas infrastructure market. Technip Energies, an engineering group based in Paris, announced that it has won a contract covering the preliminary design of a floating liquefied natural gas (FLNG) unit on the African continent. The contract, which remains valid until September 30, 2025, marks a new step for the company in the African natural gas market. According to the company, this is a key project aimed at supporting the development of energy infrastructure in the region. The contract value has not been disclosed at this stage.
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Technip Energies, recognised player in the FLNG market
Technip Energies has established expertise in delivering floating liquefied natural gas units. To date, the company has delivered three operational FLNG units worldwide, representing a total capacity of 8.2 mn tonnes per year. Previous projects include PFLNG SATU in Malaysia, Prelude FLNG in Australia and Coral Sul FLNG in Mozambique. These installations enable the production, storage and transfer of liquefied natural gas directly at sea, avoiding the need for onshore infrastructure.
Deployment in Africa and gas market outlook
The signing of this contract confirms growing interest in floating liquefaction technologies in Africa. FLNG installations are considered by companies for their ability to access offshore reserves and accelerate the commercialisation of natural gas. According to Technip Energies, regional demand for such installations remains supported by the search for new export opportunities.
Contract duration and activity schedule
The contract awarded to Technip Energies covers the preliminary works phase until the end of September 2025. This stage notably includes technical planning and project feasibility studies. The company has not disclosed the client’s identity or the exact location of the floating unit on the African continent. According to data published by Technip Energies, the FLNG project portfolio remains a strategic development focus for the company.
The group’s technical capability in the liquefied natural gas sector is demonstrated by the previous delivery of complex units and the securing of long-term contracts. A Technip Energies spokesperson stated that “the company’s expertise in the FLNG field continues to support its international ambitions”, according to a statement released by the group.
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US: NGI Projects 52 Bcf Natural Gas Storage Injection, Expanding Surplus Amid Rising LNG Demand
NGI is expecting a 52 Bcf injection into Lower 48 underground storage for the week ending July 11. This compares with last year’s 18 Bcf injection for the similar week and the 41 Bcf five-year average. Such an injection would push the current storage balance versus the previous five-year average to more than 190 Bcf, up from a range of 173 to 179 Bcf that has been in place since June 20.
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Henry Hub traded in a range from $3.04-3.275 over the past week, NGI weekly price data showed. The NGI Henry Hub August contract, meanwhile, settled at $3.317 on Friday.
NGI’s estimate takes into account 77 cooling degree days for the period, up two from the prior week. The most recent period also saw a total 1.2% week/week decrease in renewable generation, as a 2.1% increase in solar output was more than offset by a 4.5% decline in wind production, according to U.S. Energy Information Administration data.
A 52 Bcf injection would put Lower 48 working gas on a pace to hit 3,937 Bcf by Nov. 1, assuming the remainder of the 2025 injection season comes in at the average of the previous five years. That would be high from a historical standpoint, but as U.S. LNG exports continue to grow, more storage is needed to serve global demand. NGI’s Forward Look price for November settled at $3.928 on Friday, substantially higher than NGI’s November 2024 Henry Hub bidweek index of $2.350.
2Q2025 earnings season kicks off this week, with Kinder Morgan Inc. reporting Wednesday after the market close and SLB Ltd. posting results on Friday.
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Ukraine offers underground storage for Azerbaijan’s natural gas to Europe
Ukraine is exploring greater cooperation with Azerbaijan in the gas sector, including the storage and transportation of natural gas, according to a statement from Ukraine’s Ministry of Energy. The statement came after 13th session of the Intergovernmental Commission on Economic Cooperation between Azerbaijan and Ukraine, held in Baku, News.Az reports, citing local media.
“We are open to new formats of cooperation in the gas sector. Specifically, Ukraine is offering its underground gas storage facilities to serve as an international gas hub. Our underground storage facilities are the largest in Europe and are available to foreign companies under a customs warehouse regime,” said German Galushchenko, Ukrainian Minister of Energy and co-chair of the commission.
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He emphasized the importance of enhancing the transit potential of both countries by developing transport corridors, particularly the Middle Corridor.
“We greatly appreciate the solidarity of the Azerbaijani people with Ukraine. Support in the energy sector has been especially vital, helping us maintain stability in our energy system under difficult conditions,” said Deputy Minister of Energy Mykola Kolesnyk.
He noted that, alongside the signing of a roadmap, both sides discussed further steps to deepen cooperation. These include joint energy projects, the development of renewable energy sources, and involving Ukrainian companies in the modernization of Azerbaijan’s energy infrastructure.
“Ukraine is interested in strengthening partnerships with Azerbaijani companies in energy, infrastructure, and innovation. We are open to new investments and projects,” the deputy minister added.
Kolesnyk also expressed the readiness of both public and private Ukrainian companies to participate in joint energy initiatives, particularly in cooperation with SOCAR and other Azerbaijani partners.
“Ukraine and Azerbaijan reaffirmed their commitment to strengthening strategic partnership in the energy sector, opening up new prospects for cooperation and contributing to the energy security of both countries,” the statement concluded.
https://news.az/news/ukraine-offers-underground-storage-for-azerbaijans-natural-gas-to-europe
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Qatar on course to be Middle East’s largest gas producer in the 2030s
Rystad Energy expects the Middle East region to overtake Asia this year as the world’s second-largest gas producer, behind North America. Rystad Energy expects the Middle East region to overtake Asia this year as the world’s second-largest gas producer, behind North America. Gas production in the region has expanded by about 15% since 2020, the consultants added, with producers intent on monetizing their gas resources and increasing exports to help satisfy global demand.
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At present, the region produces about 70 Bcf/d. That figure should rise by 30% by 2030 and 34% by 2035, Rystad added, due largely to projects in Saudi Arabia, Iran, Qatar, Oman and the UAE.
By 2030, the Middle East should produce a further 20 Bcf/d, equivalent to half of Europe’s current gas needs. However, that will depend on Brent prices holding steady at $70/bbl and oil-indexed gas prices remaining at $7-9 per million British thermal units (MMBtu).
If prices were to fall below $6 per MMBtu, that could delay new projects, with volume growth maybe pegged at 20% or less, depending on the duration of the price decline.
But producing countries in the region are currently working to have an additional 10 Bcf/d available for export by 2030, which could be offered to Europe and other growing markets in Asia. Total output from the Middle East could hit 90 Bcf/d by the end of this decade, Rystad predicted.
Source: Rystad Energy Upstream Solution, July 2025
Much of the growth should come from new projects that can produce cost-effectively below a threshold of $5 per thousand cubic feet, notably in Qatar, the UAE and Saudi Arabia.
Qatar’s offshore North Field expansion developments should lift the country’s LNG capacity by 80% by the end of the 2020s, from 77 to 142 MM metric tons/year, while maintaining a breakeven price of under $6/MMBtu.
Rahul Choudhary, vice president of Upstream Research at Rystad, said that Middle Eastern projects remain resilient even below this level due to their low breakeven costs, typically under $5/thousand cubic feet.
By 2028, the region should add 60 MMt/year of new capacity, with Qatar providing 48 MMt/year through its North Field East and North Field South offshore projects.
Iran currently leads Middle East gas production at about 25 Bcf/d, followed by Qatar at 16 Bcf/d and Saudi Arabia at 8 Bcf/d. Iran’s gas production should increase by 6% to about 26 Bcf/d toward the end of the decade, mostly from the South Pars Field in the Persian Gulf, despite production being partly shut down recently during the conflict with Israel.
Qatar’s gas output should rise by almost 50% to 24 Bcf/d, due to the ongoing development of the North Field. By the early 2030s, the country will likely overtake Iran as the Middle East’s largest gas producer, Rystad added
The UAE and Saudi Arabia should each contribute a further 3 Bcf/d of gas, while Israel’s production should rise by 1.5 Bcf/d following the next expansion phases at the offshore Leviathan and Tamar fields.
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Ghana: Eni boosts gas processing at Ghana offshore project
Following completion of major upgrades at the OCTP’s non-associated gas (NAG) system, gas processing capacity rose to 270 MMcfd on July 13, up 24 MMcfd from the system’s previous capacity of 246 MMcfd, Eni said. Eni SPA subsidiary Eni Ghana Exploration and Production Ltd.—on behalf of joint-venture (JV) partners Vitol Upstream Ghana Ltd. (VUGL) and Ghana National Petroleum Corp. (GNPC)—has expanded natural gas processing capacity of the JV’s integrated oil and gas development project on the Offshore Cape Three Points (OCTP) block, 60 km offshore western Ghana.
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Following completion of major upgrades at the OCTP’s non-associated gas (NAG) system, gas processing capacity rose to 270 MMcfd on July 13, up 24 MMcfd from the system’s previous capacity of 246 MMcfd, Eni said on July 15.
In addition to increasing gas supply to Ghana’s domestic market, the completed upgrading project further supports the nation’s commitment to a more sustainable energy future by allowing the country to reduce its current reliance on oil-fueled power generation in favor of a cleaner energy source, according to the operator.
To date, production of natural gas from OCTP powers about 34% Ghana’s electricity, Eni said.
Operational since August 2018, Eni—which holds a 44% stake in the project and acts as operator for partners VUGL (35.6%) and GNPC (20%)—said the OCTP provides about 70% of Ghana’s total domestic gas supply, mainly for electricity generation (OGJ Online, July 6, 2018).
Confirmation of the NAG system capacity expansion follows Eni Ghana’s late-May 2025 announcement that it will drill a sidetrack well in OCTP block to increase value and ensure long-term production sustainability of the project (OGJ Online, June 2, 2025).
System overview
An integrated project for development of oil and natural gas fields in 520-990 m of water, OCTP’s Sankofa and Gye Nyame fields are developed with wells and systems on the seabed, connected to the John Agyekum Kufuor floating production and storage unit (FPSO).
Gas is processed and transported via pipeline to onshore terminals near Sanzule where it is compressed and injected into the Western Corridor Gas Pipeline to be distributed to thermal power plants and industrial customers across the country. Oil is stored in the FPSO and offloaded to tankers for sale in the international market.
According to VUGL’s annual OCTP environmental and social monitoring report dated June 2024, the partnership completed debottlenecking work of the NAG system in early 2023 to boost capacity to 260 MMcfd.
In 2024, Eni Ghana also completed additional modifications required to increase capacity of the NAG system from the FPSO to OCTP’s onshore receiving facility (ORF), which included changes in orifice plates and Joule-Thompson (JT) valves, Petroleum Commission Ghana said in its 2025 Ghana Upstream Petroleum Business Report dated May 2025.
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Congo: Angola makes its first major offshore gas discovery
Azule Energy has confirmed Angola’s first major offshore natural gas discovery after drilling the Gajajeira-01 well in the lower Congo basin. According to information from the Angolan Ministry of Hydrocarbons, the discovered well contains over 1,000 billion cubic feet of gas and 100 million barrels of condensate. This colossal discovery could boost Angola’s ambitions to develop its LNG industry and attract new investors. Located approximately 60 km off the coast, this field demonstrates the diversification of Angola’s energy sector beyond oil and could strengthen its economy for years to come.
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Natural Gas / LNG Utilization / Bio-LNG
Belgium : NYK begins continuous use of bio-LNG fuel on car carriers
NYK has commenced the continuous use of bio-LNG fuel on its LNG-powered car carriers. The bio-LNG is supplied by Titan Supply B.V. at the Port of Zeebrugge in Belgium. The first vessel to receive the fuel was Daisy Leader on 15 June 2025, and the second was Sumire Leader on 18 July 2025.
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Bio-LNG, also known as liquefied biomethane, is purified liquefied methane gas (biogas) produced from biomass feedstock, such as animal manure and food wastes. By capturing methane that would otherwise be released into the atmosphere, greenhouse gas (GHG) emissions over the entire life cycle can be significantly reduced. The bio-LNG fuel supplied by Titan under the mass balance method is recognised as carbon neutral in the whole process from production to consumption (well-to-wake) and is ISCC EU certified, an international standard for sustainability, ensuring compliance with EU regulations and traceability throughout the supply chain.
Titan CEO, Niels den Nijs, said: “I would like to express my sincere respect for NYK’s decision to start using bio-LNG fuel. Titan’s mission is to provide solutions to help the shipping industry transition to cleaner fuels. We are very pleased to be able to accelerate our decarbonisation efforts together with NYK through this replenishment.”
NYK Fuel Group General Manager, Kaori Takahashi, added: “We are very pleased to begin the continued use of bio-LNG fuel. Bio-LNG fuel is a highly effective option for decarbonising the shipping industry, and we will continue actively promoting its use. This initiative will be an important step toward reducing our environmental impact further and achieving a sustainable future.”
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Azerbaijan’s SOCAR and Syrian Government Finalize Natural Gas Agreement
SOCAR signs gas supply deal with Syria, signaling renewed bilateral ties and supporting Syria’s energy independence under its new leadership. Azerbaijan’s state-owned energy company, SOCAR, has officially entered into a natural gas supply agreement with the Syrian government, marking a pivotal development in Syria’s quest for energy security and regional cooperation, according to media reports. The memorandum of understanding (MoU) was signed by Mikayil Jabbarov, Azerbaijan’s Minister of Economy and Chairman of SOCAR’s Supervisory Board, and Syria’s Minister of Energy, Mohammed al-Bashir.
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In a statement shared on the social media platform X, Minister Bashir highlighted the importance of the agreement, stating, “Today, I had the honor of accompanying President Ahmad Al-Sharaa during an official visit to Azerbaijan. During our meetings, we explored avenues to deepen cooperation in the natural gas sector to support Syria’s future energy needs.” Bashir emphasized that the deal represents a significant stride towards achieving energy independence and developing long-term partnerships that will benefit the Syrian people and the country’s broader national interests.
The agreement appears to be aligned with recent geopolitical developments. Turkish President Recep Tayyip Erdogan recently mentioned that Azerbaijani President Ilham Aliyev had expressed Azerbaijan’s willingness to support Syria with natural gas supplies. This affirmation from Baku is now being formalized through the SOCAR agreement.
President Ahmad Al-Sharaa’s visit to Azerbaijan marks his first official diplomatic mission to the country since assuming office earlier this year. The Azerbaijani Presidential Office confirmed that comprehensive high-level discussions took place between President Aliyev and President Al-Sharaa, with ministers and senior officials from both countries participating in the deliberations.
President Aliyev addressed the historical context of the two nations’ relationship, noting that past administrations in Syria had adopted hostile policies toward Azerbaijan, which had led to a cooling of diplomatic and economic ties. However, Aliyev expressed optimism about the current Syrian leadership, indicating that the formation of a new administration in Damascus has opened the door for a more constructive and forward-looking bilateral relationship.
“The previous Syrian government’s unfriendly stance strained relations with many countries, including ours,” Aliyev remarked. “But with this new leadership, we see an opportunity to build mutually beneficial cooperation.”
In response, President Al-Sharaa conveyed his appreciation for Azerbaijan’s support and reaffirmed his government’s commitment to renewing and strengthening diplomatic and economic relations. He acknowledged that the previous regime had inflicted damage on Syria’s international ties but said his administration is determined to pursue a new era of diplomacy and collaboration.
The SOCAR gas deal is viewed as a strategic move that could pave the way for broader cooperation in the energy sector and beyond, providing Syria with much-needed resources while offering Azerbaijan an opportunity to expand its influence and partnerships in the region.
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4,000 CNG Trucks: Dangote Refinery’s Direct Fuel Deal Triggers Panic Among Tanker Drivers
With less than 30 days to the rollout of 4,000 Compressed Natural Gas (CNG) trucks by Dangote Refinery, the number of oil marketers signing up for direct fuel supply has grown to over 25, sparking fears among petroleum tanker drivers over possible job losses.
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The refinery is set to begin direct distribution of Premium Motor Spirit (PMS) to marketers and key sectors from August 15, potentially bypassing traditional tanker transport routes.
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Egypt’s Newest LNG Import Terminals Start Up, Easing Gas Crunch
Two new LNG floating terminals are now operational in Egypt, bringing some relief to the North African nation that last year turned into a net importer of the fuel due to domestic supply crunches and rising demand. The Energos Eskimo terminal, at Egypt’s Ain Sokhna port on the Red Sea, has received two liquefied natural gas cargoes since late last week, ship-tracking data on Bloomberg show. Another floating storage and regasification unit at the same location, Energos Power, is now operational and ready to receive fuel, according to the ship-tracking data and a person with direct knowledge of the information.
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Egypt depends on LNG to help provide power to its growing population and feedstock to the nation’s industries, with demand further rising in the hot summer months to meet cooling needs. Last year, the country turned from a net exporter into a net importer of the fuel as domestic production slumped. It’s imports had up until now been met through a single operational LNG terminal, the Hoegh Galleon vessel, also docked in Ain Sokhna.
LNG Deals
With local demand increasing, Egypt rented more floating terminals, and Egyptian Natural Gas Holding Co. agreed on large LNG deals with suppliers for deliveries starting in July. But a small number of cargoes were shifted to August as the new terminals were not yet operational, Bloomberg reported last week.
With both terminals now starting up, LNG tanker Isabella, loaded with a US cargo, docked by the Energos Eskimo terminal on Monday, according to ship-tracking data. It followed the arrival of the first cargo from Equatorial Guinea on the Grazyna Gesicka tanker, which completed unloading at the same terminal on Friday.
Energos Power, the third terminal, earlier this month received its cooldown cargo at the now-idled export terminal in Damietta, and has arrived at Ain Sokhna, the data show.
A fourth floating terminal, Energos Winter, is due to arrive next month to start the commissioning process later this year, according to people with direct knowledge of the information.
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Dangote Refinery receives 4,000 CNG trucks in Lagos ahead of August 15 fuel distribution rollout
Dangote Petroleum Refinery has announced the arrival of 4,000 brand-new Compressed Natural Gas (CNG) powered trucks in Lagos, marking a major milestone in its nationwide fuel distribution initiative scheduled to begin on August 15. The announcement was made on Saturday via the official Dangote Group X page and was accompanied by a video clip showing the vessel berthing at the port. In the footage, cranes were seen offloading the CNG trucks onto the company’s base, followed by a wide aerial view of hundreds of the newly imported vehicles lined up in an expansive formation.
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“We are delighted to receive 4,000 brand-new CNG trucks as part of our bold distribution initiative, championing cleaner energy and more efficient transportation across Nigeria and beyond,” the post read.
This delivery brings the company closer to implementing its N720 billion investment programme aimed at revolutionising Nigeria’s downstream sector by directly supplying refined petroleum products across the country.
From mid-August, the refinery plans to commence direct delivery of petrol and diesel to filling stations, industrial plants, and large-volume fuel consumers, eliminating logistics bottlenecks and cutting out middlemen.
What you should now
Nairametrics had earlier reported in June that the privately owned refinery would absorb over N1.07 trillion annually in fuel distribution costs as part of this scheme, a move expected to save Nigerians more than N1.7 trillion yearly by reducing energy costs.
The initiative is also projected to benefit over 42 million Micro, Small, and Medium Enterprises (MSMEs), help resuscitate dormant filling stations, and create more than 15,000 jobs across the logistics value chain.
With this fleet, the Dangote Refinery aims to meet Nigeria’s daily demand of 65 million litres of refined petroleum products comprising 45 million litres of Premium Motor Spirit (PMS), 15 million litres of diesel, and 5 million litres of aviation fuel.
The use of CNG-powered trucks is also expected to help reduce emissions and support the Federal Government’s drive to promote cleaner energy alternatives.
Industry stakeholders, including the Presidency, the Independent Petroleum Marketers Association of Nigeria (IPMAN), and energy analysts, had previously praised the initiative as a significant step toward curbing high distribution costs, stabilising fuel prices, and modernising Nigeria’s downstream petroleum sector.
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PCNGI to release list of newly approved CNG conversion centres nationwide
The Presidential Compressed Natural Gas Initiative (PCNGI) says it will soon release a comprehensive list of Compressed Natural Gas (CNG) vehicles conversion centres, including the newly approved ones, nationwide. Ms Matilda Johnson, Brand & Corporate Communications Manager, PCNGI, said this in a statement issued on Friday in Abuja. Johnson said that the move was to ease the stress encountered by motorists who choose to have alternative source of fueling for their vehicles.
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She said that the release of the list of the newly approved CNG conversion centres was necessary to correct a misleading report that the PCNGI intentionally pulled down a website of conversion centres nationwide, to conceal information.
“The website is undergoing scheduled updates to reflect a larger, more inclusive list of newly approved conversion centers, in line with our transparency standards,” she said.
According to her, an article published in a section of the media, represents a regrettable deviation from the principles of ethical journalism, while the writer relied on conjecture and unfounded innuendos to attack a nationally impactful programme.
“Since its launch, the PCNGI has facilitated over $800 million in private and public investments, created more than 100,000 direct and indirect jobs, and significantly accelerated the adoption of cleaner and cheaper energy alternatives.
“Today, over 100,000 CNG vehicles are operational across Nigeria — a fivefold increase in just one year.
“The recent landmark deployment by Dangote Group, featuring 4,000 CNG-powered trucks, 100 virtual pipeline vehicles, and multiple daughter stations, is just one high-profile testament to the Initiative’s impact.
“Additionally, our partnership with local MSMEs has led to the rise of over 300 conversion centers, from just seven at inception, with an average of 20 new centers opening weekly.”
Johnson regretted that tangible outcomes of the programme were neglected while the conveyor of the misinformation engaged in speculative reporting.
“The publication also irresponsibly misrepresented the role and identity of one Mr David Idakwo, who works with PCNGI, portraying him as a senior decision-maker at PCNGI.This is patently false.
“Idakwo, a mid-level field officer employed in late 2024, holds no executive role within the organisation and is not involved in strategic decision-making.
“Efforts to link his past private enterprise affiliations to allegations of nepotism are not only misleading but an affront to the right of every Nigerian to legitimate business pursuits.
“At PCNGI, we remain unwavering in our commitment to transparency, public accountability, and national development.
“Our ongoing efforts to ensure proper distribution of government-subsidised kits and enforce compliance have inevitably unsettled those seeking to benefit from corruption or sabotage,” she added.
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Fluxys awards Sacyr Proyecta contract for Zeebrugge LNG terminal
Fluxys has awarded Sacyr Proyecta a new contract involving the development of services at its LNG terminal in Zeebrugge, Belgium. The scope of the project includes the installation of new seawater open rack vaporisers (ORV) and their corresponding pumps, together with a new intake caisson at the terminal’s port facilities.
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This project aims to reduce CO2 emissions while maintaining the terminal’s send-out capacity and is part of Fluxys’ programme to achieve net-zero emissions in its own operations.
In the past, Sacyr Proyecta has executed several relevant projects at the LNG terminal in Zeebrugge with the aim of expanding the plant’s regasification capacity. Since 2011, Sacyr Proyecta has taken part in projects such as the development of FEED services for the fifth LNG tank, (semi-buried with a 180 000 m3 capacity) and for a second jetty capable of handling loading, unloading and ship-to-ship transfer operations with LNG carriers of various sizes, from 700 m3 to Q-Flex (217 000 m3).
During the EPC phase, developed from 2013 – 2020, Sacyr Proyecta was the programme management contractor (PMC) for Fluxys, which included the construction of the fifth tank of the Zeebrugge Plant and the associated boil-off gas (BOG) management facilities, as well as for the construction of a second berthing jetty.
Additionally in 2023, Sacyr Proyecta has completed an EPCM project to expand the regasification capacity of the LNG plant to 2.6 million Nm3/h, and in parallel, the installation of new seawater ORVs, enabling the reduction of CO2 emissions and also the addition of new LNG truck loading stations.
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ABL completes competency assessment for NLNG’s Head of Marine Operations role
ABL Group has completed the first in-country competency assessment for NLNG Shipping and Marine Services Ltd (NSML), marking a significant milestone in the company’s long-term commitment to marine operational excellence at Bonny Terminal in Nigeria. Daniel Wood, ABL’s Director of Ports & Harbours for Europe and West Africa, and Jim Jack, Senior Consultant, led the assessment of the Head of Marine Operations position in NSML.
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The evaluation is part of a broader project launched in conjunction with NSML in July 2023 to build and implement a robust marine competency framework tailored to NSML’s operational needs.
The assessment was anchored in the Head of Marine Operations Job Competency Profile (JCP), a comprehensive standard developed by ABL and aligned with internal maritime competency assessment standards. Using oral interviews and scenario-based analysis, the process tested leadership, marine safety, risk management, emergency response, and compliance with international legislation.
“This isn’t just a test of knowledge, it’s about judgement, leadership and alignment with NSML’S strategic marine goals. We were especially impressed by the candidate’s emphasis on morale, safety culture and operational integrity,” said Wood.
Ikenna Duru, who was assessed on the Head of Marine Operations role, demonstrated a practical, people-first leadership style and strong marine terminal experience.
“This process helped me reflect on the depth of responsibility the role carries,” Duru shared. “It was more than an interview, it was a deep dive into what it truly means to lead safely, efficiently, and ethically in a high-stakes marine environment.”
Dr Effiong Ekanem Attah, Manager of the Maritime Centre of Excellence & Training, concluded: “This assessment sets a benchmark for technical and leadership competence. We are pleased with the insights it provides, not only about individual readiness, but about how we can further tailor training and succession planning for our marine leaders.”
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NIPCO deepens commitment to CNG as Nigeria pushes for cleaner alternatives
NIPCO Plc has emerged as a key player in the Federal Government’s push for Compressed Natural Gas (CNG) adoption, positioning itself as a major force in reshaping the country’s energy future as Nigeria accelerates its transition to cleaner energy sources. At its 20th Annual General Meeting held in Abuja, the company’s leadership reaffirmed its dedication to deepening investments in gas infrastructure, aligning with national objectives to cut fuel costs, reduce carbon emissions, and diversify energy sources.
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Paul Anekwe, chairman of NIPCO Plc described CNG as “a cleaner alternative to conventional fossil fuels,” highlighting the company’s early recognition of its potential more than 15 years ago.
“Our company sought Federal Government approval to establish the gas infrastructure that allows motorists to switch to gas. That vision aligns perfectly with President Bola Ahmed Tinubu’s renewed drive to promote gas as a transition fuel,” Anekwe said.
The federal government’s current CNG drive under the Presidential Compressed Natural Gas Initiative (PCNGI) has gained momentum, with over 100,000 vehicles already converted to run on both gas and petrol. NIPCO’s subsidiary, NIPCO Gas Ltd, has played a pivotal role in enabling this transformation, providing infrastructure support, expanding gas dispensing stations, and advocating for the broader adoption of auto gas across Nigeria.
Suresh Kumar, managing director of NIPCO, echoed similar sentiments, emphasising that “the introduction of CNG as a fuel source aligns with the government’s energy diversification drive, which has received extensive support from consumers across the country.”
He added that NIPCO’s partnership with the federal government would be intensified in 2025 and beyond to ensure “more motorists and industrial users benefit from the economic and environmental advantages of gas utilisation.”
The PCNGI’s measures, including free CNG kits and the introduction of mobile refilling stations, have further accelerated the adoption rate, particularly among commercial transport operators seeking alternatives to expensive petrol and diesel.
Industry experts note that the push for CNG comes at a critical time. Nigeria, Africa’s largest crude oil producer, is grappling with high transportation costs following the complete removal of fuel subsidies in 2023. The price shock triggered nationwide discontent and renewed calls for sustainable, locally-sourced energy solutions. Natural gas, of which Nigeria holds the ninth-largest reserves globally, presents a strategic advantage.
For NIPCO, the pivot to gas is more than just a reaction to government policy—it is a reflection of its long-term strategy. “We believe that the administration’s reforms will unlock numerous benefits to Nigeria’s economy and open a new vista for motorists,” the Chairman said.
Beyond auto-gas, NIPCO is also expanding its investments in Liquefied Petroleum Gas (LPG), with newly constructed infrastructure to boost storage capacity and facilitate faster, more cost-effective loading operations. The company is targeting both domestic and industrial users as it looks to consolidate its leadership position in the gas sector.
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US: Bruce Mansfield Power Plant to Be Converted to Run on Gas
The decommissioned 2.7-gigawatt (GW) Bruce Mansfield Power Plant will be redeveloped from a coal-fired station into a natural gas-fired station, the Frontier Group of Companies (FGC) said Tuesday. The conversion project, Shippingport Power Station, will be “a significantly larger state-of-the-art natural gas generation plant with new incremental onsite generation”, FGC said in a press release with partners. “Additionally, FGC has secured a partner to build a collocated data center facility to support America’s demand for AI infrastructure”.
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The project is also expected to supply over one GW of excess capacity to the PJM interconnection region, which comprises all or parts of the District of Columbia and 13 states: the original core of Pennsylvania, New Jersey and Maryland, plus Delaware, Illinois, Indiana, Kentucky, Michigan, North Carolina, Ohio, Tennessee, Virginia and West Virginia.
FGC intends to award the gas supply contract to EQT Corp. “Shippingport Power Station is expected to utilize approximately 800 million cubic feet per day of natural gas produced by the Marcellus and Utica shales, located in Western Pennsylvania”, the announcement said.
A separate project in Indiana County to redevelop the site of the decommissioned coal-run Homer City Generating Station has also entered into an agreement in principle with EQT for gas supply from the Marcellus shale.
National Fuel Gas Co. meanwhile will serve as the transporter for a “significant portion” of the gas deliveries to the Shippingport Power Station.
“We look forward to supporting this significant investment in Western Pennsylvania, leveraging our interstate pipeline network to provide reliable deliveries of Appalachian Basin natural gas directly to the facility, with new transportation capacity expected to come online as early as Fall 2026”, said National Fuel Gas president and chief executive David P. Bauer.
“The redevelopment project is expected to benefit Pennsylvania with more than $6 billion of new economic activity, encompassing direct spending, indirect spending and induced economic output, as well as create more than 15,000 construction jobs and 340 new full-time jobs in the region”, the announcement said.
“It will also deliver approximately $139 million in annual recurring revenue for the state, including more than $13 million in tax revenue, $36 million in labor income and $6 million in local county tax revenue”.
FGC chief executive and founder David Franjoine said, “With the support of Governor Josh Shapiro and Senator Dave McCormick, we will transform this decommissioned coal facility into a modernized power facility that supports America’s goal of energy dominance and reinvigorates local communities with high-quality employment opportunities”.
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Vietnam: American LNG reels in Asian buyers amid Trump’s tariff pressure
HANOI, Vietnam — Asian countries are offering to buy more US liquefied natural gas (LNG) in negotiations with the Trump administration. This is as a way to alleviate tensions over US trade deficits and forestall higher tariffs. Analysts warn that strategy could undermine those countries’ long-term climate ambitions and energy security. Buying more US LNG has topped the list of concessions Asian countries have offered in talks with Washington over President Donald Trump’s sweeping tariffs on foreign goods. Vietnam’s Prime Minister underlined the need to buy more of the super-chilled fuel in a government meeting. The government signed a deal in May with an American company to develop a gas import hub.
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JERA, Japan’s largest power generator, signed new 20-year contracts last month. It will purchase up to 5.5 million metric tons of US gas annually starting around 2030.
US efforts to sell more LNG to Asia predate the Trump administration. But they’ve gained momentum with his intense push to win trade deals.
Liquefied natural gas, or LNG, is natural gas cooled to a liquid form for easy storage and transport. It is used as a fuel for transport, residential cooking and heating and industrial processes.
Trump discussed cooperation on a $44 billion Alaska LNG project with South Korea, prompting a visit by officials to the site in June.
The Philippines is also a potential importer of US LNG
The US president has promoted the project as a way to supply gas from Alaska’s vast North Slope to a liquefication plant at Nikiski in south-central Alaska. He has an eye largely on exports to Asian countries while bypassing the Panama Canal.
Thailand has offered to commit to a long-term deal for American fuel.
The Philippines is also considering importing gas from Alaska. India is mulling a plan to scrap import taxes on US energy shipments to help narrow its trade surplus with Washington.
“Trump has put pressure on a seeming plethora of Asian trading partners to buy more US LNG,” said Tim Daiss, at the APAC Energy Consultancy. Daiss pointed out that Japan had agreed to buy more despite being so “awash in the fuel” that it was being forced to cancel projects and contracts to offload the excess to Asia’s growing economies.
“Not good for Southeast Asia’s sustainability goals,” he said.
LNG deals could derail renewable ambitions
Experts say LNG purchasing agreements can slow adoption of renewable energy in Asia.
Locking into long-term deals could leave countries with outdated infrastructure. This, as the world shifts rapidly toward cleaner energy sources like solar or wind that offer faster, more affordable ways to meet growing power demand, said Indra Overland, head of the Center for Energy Research at the Norwegian Institute of International Affairs.
Building pipelines, terminals, and even household gas stoves creates systems that are expensive and difficult to replace. This makes it harder to switch to renewables later. “And you’re more likely then to get stuck for longer,” he said.
Energy companies that profit from gas or coal are powerful vested interests. They sway policy to favor their business models, he said.
LNG burns cleaner than coal, but it’s still a fossil fuel that emits greenhouse gases and contributes to climate change.
Many LNG contracts include “take-or-pay” clauses. These oblige governments to pay even if they don’t use the fuel. Christopher Doleman of the Institute for Energy Economics and Financial Analysis warns that if renewable energy grows fast, reducing the need for LNG, countries may still have to pay for gas they no longer need.
Pakistan is an example. Soaring LNG costs drove up electricity prices, pushing consumers to install rooftop solar panels. As demand for power drops and gas supply surges, the country is deferring LNG shipments and trying to resell excess fuel.
https://business.inquirer.net/536625/american-lng-reels-in-asian-buyers-amid-trumps-tariff-pressure
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Libya: NOC, AGOCO explore plans to utilize associated gas from Messla and Sarir fields
The National Oil Corporation’s General Gas Department met with the management committee of the Arabian Gulf Oil Company (AGOCO) to discuss the development of the Messla and Sarir oil fields and explore ways to utilize associated gas. The aim is to support and expand the gas transmission network to better meet domestic demand.
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Both sides stressed the importance of joint coordination to ensure the optimal use of gas resources, highlighting the role of associated gas utilization in reducing emissions and adding economic value by strengthening Libya’s oil and gas infrastructure, according to a statement posted on the company’s official Facebook page.
Associated gas is a form of natural gas found mixed with crude oil in underground reservoirs. It is produced during oil extraction and is commonly found in conventional oil fields.
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Indonesia : Conrad confirms reallocation of offshore Mako Field gas to Indonesian utility
Conrad Asia Energy has signed a gas sales agreement for the Mako Field in the Duyung PSC offshore western Indonesia with PT PLN Energi Primer Indonesia. Conrad Asia Energy has signed a gas sales agreement (GSA) for the Mako Field in the Duyung PSC offshore western Indonesia with PT PLN Energi Primer Indonesia (PLN EPI), a subsidiary of state-owned power utility PLN Persero.
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All volumes produced will be supplied to Indonesia’s domestic market. The binding agreement covers the current PSC period through January 2037 and allows for the sale of up to 111 billion Btu per day.
According to Conrad, PLN Persero operates more than 7,000 power plants supplying over 89 million customers and sells more than 288,000 GWh/year of electricity. The Mako gas price will be linked to the Indonesian crude price.
PLN EPI will finance and construct a new 5- to 7-km pipeline connecting the main West Natuna Gas line to Pemping Island with an onward link to Batam, at no cost to Conrad.
Previously negotiated GSAs to sell Mako gas to PT Perusahaan Gas Negara and Singapore-based Sembcorp Gas have been terminated.
The new agreement should support Conrad’s farm-out arrangements for the Duyung PSC and FID on the Mako development.
Conrad subsidiary West Natuna Exploration currently has a 76.5% operated interest in the PSC, situated in waters around Riau Islands Province in the West Natuna area. The location is 100 km north of Matak Island and 400 km northeast of Singapore.
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Global LNG Development
Italy : Adriatic LNG sets new record in 1H25
Wednesday, 16 July 2025 10:00 Natural gas consumption in Italy saw an increase in 1H25, and Adriatic LNG’s contribution to the national energy system continued to grow as well (+2.2%), marking a new record half-year for the company that operates Italy’s largest LNG regasification terminal, located in the Northern Adriatic Sea. In total, Adriatic LNG delivered 4.5 billion m3 of natural gas – equal to 14% of national gas demand – confirming its position as third most important gas entry point after pipelines from Algeria and Azerbaijan.
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“In an energy scenario increasingly affected by complex geopolitical developments, Adriatic LNG has maintained a leading role in ensuring flexibility and diversification of supply for Italy and Europe,” observed Alexandra Thomas, CEO of Adriatic LNG.
Specifically, the volumes regasified and delivered by Adriatic LNG in the first half of the year represented 44% of Italy’s LNG imports (about 10.3 billion m3, +35% compared to the same period of 2024). The terminal received 39 LNG carriers, mainly from Qatar and the US. Since the start of operations in 2009, Adriatic LNG has received more than 1170 LNG carriers from over 10 countries and delivering over 105 billion m3 of gas.
This record semester included a milestone in May, when Adriatic LNG achieved its best-ever monthly performance for regasified and delivered gas: 825 million m3 – equivalent to the annual gas consumption of the entire province of Padua or Treviso.
Alfredo Balena, Director of External Relations at Adriatic LNG, stated: “LNG is a key resource for our country, essential to ensuring the security of the energy system. Adriatic LNG once again confirms its leadership in the regasification sector and stands as a national and European benchmark, with operational performance that breaks new records year after year. This confirms both the reliability of our infrastructure and the professionalism of the people who work here every day with competence and dedication.”
As a matter of fact, the focus on human capital – combined with attention to safety, environmental protection, operational integrity, and community relations – lies at the heart of Adriatic LNG’s newly released 2024 ESG Report, the first based on European VSME standards.
“Our second Sustainability Report is not only a record of our environmental, social, and governance performance but a tangible expression of our commitment to a more sustainable, responsible, and inclusive future,” added Thomas.
On the environmental front, monitoring campaigns continue regularly with no exceedance of regulatory thresholds. The company remains committed to emission reductions, as shown by its voluntary participation in the Oil and Gas Methane Partnership (OGMP 2.0) – the United Nations Environment Programme (UNEP) leading reporting and mitigation programme for the oil and gas sector.
Employee well-being is a top priority. All employees are on permanent contracts and benefit from a comprehensive wellbeing programme designed to support their mental and physical health both on and off the job. Significant investment has also been made in training: over 1500 hours delivered in a single year, averaging more than 16 hours per person, underscoring the company’s focus on skills development.
In 2024, Adriatic LNG once again recorded no accidents, no environmental incidents, and no structural damage, achieving a 99.7% reliability rate thanks in part to its multi-year equipment maintenance and inspection plan.
https://www.lngindustry.com/regasification/16072025/adriatic-lng-sets-new-record-in-1h25/
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Louisiana: LNG production begins at second phase of Plaquemines plant, sources say
Venture Global has started producing liquefied natural gas from phase two of its Plaquemines export facility in Louisiana, according to two people familiar with its operations as well as LSEG ship tracking data and federal filings.
In the last six months, the United States’ second-largest LNG producer has exported LNG from phase one of its Louisiana facility, and has now begun producing the gas from phase two, allowing it to sell the LNG at higher spot market prices for the next two years, two people familiar with the project told Reuters.
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Plaquemines has two phases with different customers and timelines for delivery of LNG. The phase two customers include ExxonMobil , Chevron, EnBW, New Fortress Energy, China Gas, Petronas and Excelerate Energy. They are not expected to receive their LNG until the company completes its commissioning in the middle of 2027, Venture Global has previously said.
By producing LNG from phase two now, Venture Global should be able to export the gas for two years at higher liquefaction fees before it is required to provide its long-term customers with LNG at lower fees.
On Sunday, Plaquemines pulled a record 2.9 billion cubic feet of gas, according to preliminary data from financial firm LSEG.
Venture Global did not respond to a request for comment.
On Friday, the company asked federal regulators for permission to introduce natural gas into Block 14, according to a filing with the Federal Energy Regulatory Commission.
Block 14 is in phase two of the 27.2 million tonnes per annum Plaquemines export facility, with phase one consisting of 12 blocks, according to Venture Global’s website.
The entire Plaquemines facility is designed to have 18 blocks, with 12 in phase one and six in phase two. Each block has two liquefaction trains.
Venture Global has said its strategy is to have extended commissioning periods by completing construction of its plants years ahead of when it expects to make LNG available at lower costs to contracted customers, allowing it to earn higher revenue by selling its cargoes on the spot market.
Last week it revealed that in the second quarter of 2025 it made $7.09 per million British thermal units (mmBtu) in liquefaction fees from spot market sales of LNG from Plaquemines phase one. That is more than double the fees it received from selling LNG to its long-term customers from its Calcasieu Pass facility, which averaged $2.66 per mmBtu.
Venture Global’s stock price has climbed almost 18 per cent in the last week, trading this morning at just under $18, up more than 150 per cent from a low of $7 on April 7.
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South Korea: Hanwha Philly Shipyard wins 1st export-bound US LNG carrier order in 50 yrs
The contract aligns with the US government’s efforts to revitalize the domestic shipbuilding industry. Hanwha Philly Shipyard has secured a 348 billion won ($250 million) order to build a liquified natural gas (LNG) carrier for Hanwha Shipping LLC, marking the first order by a US shipyard for an export-bound LNG vessel in nearly 50 years.
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The deal also marks Hanwha Philly’s first order since it was acquired by South Korea’s Hanwha Group in December.
The Philadelphia-based shipyard signed the LNG tanker construction order with the affiliated company, alongside an option for a second vessel, according to a regulatory filing by Hanwha Ocean Co. on Tuesday.
The vessel will be built in collaboration with Hanwha Ocean in South Korea, in line with upcoming US regulations requiring goods shipped between two US ports to be transported on vessels that are US-owned, operated and built, a policy set to take effect from 2029.
“This contract aligns with the US strategy to revive the US shipbuilding and shipping industries and to strengthen energy security,” Hanwha Group said.
It is also expected to pave the way for closer shipbuilding cooperation between South Korea and the US, the group added.
A significant portion of the vessel’s construction will take place at Hanwha Ocean’s shipyard in Geoje, South Korea.
Hanwha Ocean will gradually transfer high-value shipbuilding technology to Philly Shipyard to transform the US arm into a mid-to-large-sized shipbuilder capable of constructing LNG tankers.
Hanwha Group acquired Philly Shipyard for $100 million in December to make inroads into the world’s largest economy.
https://www.kedglobal.com/shipping-shipbuilding/newsView/ked202507220003
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UAE: ADNOC Gas secures three-year LNG supply deal with Germany’s SEFE
ADNOC Gas has signed a three-year liquefied natural gas supply agreement with Germany’s SEFE Securing Energy for Europe, worth approximately $400 million, strengthening energy ties between the UAE and Germany.
The deal covers the delivery of 0.7 million tonnes of LNG commencing this year, with supplies originating from ADNOC Gas’ Das Island liquefaction facility in Abu Dhabi. The facility, which has been operational since 1977, boasts a production capacity of 6 million tonnes per annum and has shipped over 3,500 LNG cargoes worldwide.
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“This agreement marks a significant step in strengthening our long-standing partnership with SEFE and reinforces ADNOC Gas’ role as a reliable and responsible global energy provider, committed to supporting Germany’s energy security,” said Fatema Al Nuaimi, Chief Executive Officer of ADNOC Gas.
The agreement builds upon existing strategic collaboration between the UAE and Germany, including the 2022 Energy Security and Industry Accelerator (ESIA) pact and the 2024 Joint Declaration with Baden-Württemberg, both focused on fostering energy security and sustainable fuel development.
SEFE’s Chief Commercial Officer, Frédéric Barnaud, highlighted the value of the two-decade partnership with ADNOC, describing the UAE firm as a “reputable and reliable supplier”. He noted that this medium-term contract complements the long-term supply agreement signed last year, adding “another flexible source of LNG to our portfolio”.
The deal underscores ADNOC Gas’ continued expansion into global markets as part of ADNOC’s broader strategy to enhance natural gas production capacity and expand LNG exports. Natural gas serves as a crucial transitional fuel, offering lower carbon emissions compared to other fossil fuels whilst providing essential raw materials for industrial value chains.
SEFE, committed to ensuring energy security across Germany and Europe, continues expanding its international portfolio through partnerships with leading LNG and natural gas producers globally, ensuring diversified and reliable energy sources for European markets.
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Italy: Venture Global signs 20-year contract to supply LNG to Italy’s Eni
MILAN, July 16 (Reuters) – Venture Global (VG.N), opens new tab will supply 2 million metric tons a year of liquefied natural gas to Italian state-controlled energy group Eni (ENI.MI), opens new tab, the two companies said on Wednesday. The deal is Eni’s first long-term contract for LNG coming from the United States after Italian prime minister Giorgia Meloni told President Donald Trump in April that Rome would increase imports of U.S. LNG as a way to improve trade relations with North America.
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Last month Venture Global said it would supply an additional 0.75 million metric tons per annum of LNG to Germany-based distributor SEFE Energy GmbH, in another deal with a European offtaker.
The European Union is currently in negotiations with Washington over 30% trade tariffs on its exports towards North America.
“We do not comment on the ongoing negotiations between the EU and the U.S. administration on tariffs,” an Eni spokesperson told Reuters, calling Wednesday’s agreement “highly advantageous” for both the company and its American partner, which would become an important supplier for the group.
Eni said the gas would come from Venture Global’s Calcasieu Pass 2 project, under development in Louisiana, starting from the end of the decade.
Part of the volume will contribute to the diversification of Europe’s gas supplies, the energy giant added.
Eni said the deal would support the group’s ambitions to grow its LNG portfolio to approximately 20 million tons per annum of contracted volumes by 2030, and to expand its trading business.
Italian utility Edison also buys LNG from the United States.
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Ukraine : Snam signs memorandum of co-operation with GTSOU
Snam, one of Europe’s leading gas infrastructure companies, and Gas Transmission System Operator of Ukraine (GTSOU), operator of Ukraine’s gas transmission system transporting natural gas to consumers in Ukraine and in countries of the EU, have signed a memorandum of co-operation aimed at strengthening the collaboration between the Ukrainian and Italian gas markets, in view of enhancing energy security, regional integration, and long-term sustainability.
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The memorandum of co-operation was signed in Rome by Agostino Scornajenchi, Snam CEO, and Vladyslav Medvediev, acting CEO of GTSOU, at the sidelines of the fourth Ukraine Recovery Conference dedicated to the swift recovery and long-term reconstruction of Ukraine.
The main areas of co-operation focus on the analysis of the prospects for LNG and pipeline gas transportation between the two countries, including the potential utilisation of Ukrainian gas storage facilities, the establishment of a platform for cooperation in network maintenance, and the creation of a research platform for the transportation of renewable gases.
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Cameron : Cameron LNG reaches new milestone
Cameron LNG has announced the production and export of its 1000th cargo of LNG, marking a significant milestone achieved just six years after its first commissioning cargo departed the facility on 31 May 2019. “This 1000th cargo represents the skill, determination and commitment of the Cameron LNG team,” said Art Klein, President of Cameron LNG. “Achieving this milestone safely and reliably speaks to the strength of our core values of safety and results-based success.”
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The 1000th cargo departed aboard the Maran Gas Kimolos on 17 July 2025, from the Cameron LNG liquefaction facility located near Hackberry, Louisiana, along the Calcasieu Ship Channel.
“On behalf of the Board and all of our partners, I congratulate the Cameron employees on this achievement. Reaching this milestone in just six years is a remarkable accomplishment that reflects the expertise and tireless dedication of the entire team,” said Martin Hupka, President of LNG at Sempra Infrastructure and Chairman of the Cameron LNG Board. “It’s also a powerful demonstration of Cameron LNG’s role as a world-class operator helping to meet growing global demand for secure, reliable and sustainable natural gas.”
The Cameron LNG facility includes three liquefaction trains capable of exporting up to 14.95 million tpy, or approximately 772 billion ft3/y of natural gas. The facility began commercial operations with Train 1 in August 2019, followed by Train 2 in March 2020 and Train 3 in August 2020. Strategically located to access both Atlantic and Pacific markets, Cameron LNG has delivered US LNG to 37 countries worldwide.
Cameron LNG is jointly owned by affiliates of Sempra Infrastructure, TotalEnergies, Mitsui & Co., Ltd, and Japan LNG Investment LLC, a joint venture between Mitsubishi Corp. and Nippon Yusen Kabushiki Kaisha (NYK).
https://www.lngindustry.com/lng-shipping/18072025/cameron-lng-reaches-new-milestone/
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Norway : BASF, Equinor Confirm Strategic Partnership for Natural Gas
Equinor will supply up to 23 terawatt hours of natural gas annually to BASF. BASF and Equinor have signed a long-term strategic agreement for the annual delivery of up to 23 terawatt hours (around 2bcm) of natural gas over a ten-year period. The contract secures a substantial share of BASF’s natural gas needs in Europe. Deliveries will start on Oct. 1, 2025.
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“This agreement further strengthens our partnership with BASF. Natural gas not only provides energy security to Europe but also critical feedstock to European industries. I am very happy that our gas also supports BASF’s efforts to reduce their carbon footprint. Gas from Norway comes with the lowest emissions from production and transportation”, says Anders Opedal, president and CEO, Equinor.
BASF uses natural gas both as an energy source and as a raw material in the production of key basic chemicals. This agreement supports the company’s strategy to diversify its energy and raw materials portfolio. The gas is sold on market terms.
“We are very happy to enter into this long-term partnership with Equinor for the reliable supply of natural gas for BASF’s operations in Europe,” said Dirk Elvermann, CFO and chief digital officer, BASF SE. “Equinor is a trusted and valued partner. The supply agreement not only comes with competitive terms but also supports our sustainability targets.”
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Germany: MT Group secures contract for Brunsbüttel FSRU LNG terminal
MT Group, a leading European EPC contractor specialising in strategic energy and industrial infrastructure, has been awarded a major contract for the execution of all topside and onshore-based infrastructure at the new jetty in Brunsbüttel FSRU LNG terminal in Germany. The agreement marks a pivotal milestone in strengthening the company’s establishment in Western Europe’s most critical energy transformation efforts.
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The contract was awarded by Worley, acting as the project’s engineering lead, on behalf of Deutsche Energy Terminal GmbH (DET) – Germany’s state-owned operator of FSRUs. Under this agreement, MT Group will execute a full package of all topside and onshore-based infrastructure, including mechanical, piping, electrical, instrumentation, civil installation, and tie-in works into the existing grid system as part of Phase 2 of the terminal’s development, supporting the permanent relocation and integration of the FSRU at its final jetty location.
The Brunsbüttel FSRU terminal is a flagship component of Germany’s national energy security and diversification plan. In response to the stop of Russian pipeline gas following the Ukraine crisis, Germany fast-tracked the deployment of multiple FSRUs to ensure continuous, flexible access to global LNG supplies. The Brunsbüttel facility has been in operation since 2023 and is one of three DET’s operational terminals in Germany. In phase 2, the FSRU will be relocated to a newly constructed jetty.
This is MT Group’s second major contract in Brunsbüttel. In October 2024, the company signed a deal with Gasfin to construct a 50?MW heater facility – a project currently in advanced construction stages.
“This contract marks an extraordinary moment for our company,” said Mindaugas Zakaras, CEO of MT Group. “Being selected to contribute to such a strategically important infrastructure project in Germany is not only a testament to our technical capabilities, but a recognition of the trust we have built across the European energy market. Together with Worley and Deutsche Energy Terminal, we are fully committed to delivering the highest standards of safety, quality, and execution excellence. This project will be a reference of historic importance for MT Group.”
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South Korea: Yang Ming orders 15,000 TEU LNG dual-fuel boxship fleet
Taiwanese shipping company Yang Ming Marine Transport Corporation has unveiled the order of seven 15,000 TEU liquefied natural gas (LNG) dual-fuel containerships at South Korea’s shipyard Hanwha Ocean. On July 17, 2025, the company held its 404th board meeting and approved the order as part of its fleet optimization plan. Following the completion of contract procedures, these vessels are scheduled for delivery between 2028 and 2029, the company said.
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As explained, the newbuildings will replace aging vessels and are expected to advance Yang Ming’s strategic development. With the new order, the Taiwanese shipping player is diversfying energy sources, enhancing fleet competitiveness and aligning with global greenhouse gas (GHG) reduction goals.
“The adoption of dual-fuel solutions for the 15,000 TEU vessels, alongside the five LNG dual-fuel containerships scheduled for delivery beginning in 2026, will ensure stable service on East-West routes while achieving a 20% reduction in GHG emissions compared to traditional fuel,” Yang Ming highlighted.
“These efforts reflect the company’s commitment to year-on-year carbon intensity reduction. Moreover, the alternative fuel initiatives align with stricter international environmental regulations.”
The company further said that it would be well-positioned to navigate supply chain restructuring and market uncertainties following the latest ship order.
In December 2024, Yang Ming unveiled the intention to order up to thirteen environmentally-friendly 8,000 TEU to 15,000 TEU boxships.
At its 400th board meeting in late 2024, the company introduced its fleet optimization plan to replace its over-20-year-old 5,500 TEU to 6,500 TEU class boxships.
The container shipping company recently purchased three 8,000 TEU methanol dual-fuel-ready containerships from Japanese ship leasing company Shoei Kisen Kaisha. These vessels, being built by Imabari Shipbuilding, are scheduled for delivery between 2028 and 2029.
The acquisition of the three 8,000 TEU vessels marks the first phase of the plan and the most recent order is the second phase. The new vessels will be equipped with energy-efficient main engines, ensuring immediate energy savings while maintaining flexibility for the future adoption of alternative fuels.
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China: China’s Sinopec signs contract to explore Algerian gas block
SINGAPORE, July 24 (Reuters) – China’s state oil and gas major Sinopec Group said it has signed a contract to explore a natural gas block in Algeria that potentially holds large shale gas resource. The contract was signed earlier this week between Sinopec International Petroleum Exploration & Production Corporation (SIPC) and state-run Algerian oil and gas company Sonatrach. The North African country last month awarded Sinopec via an international tender to explore and develop block Guern El Guessa II, or GEG, which has an area of 36,000 square kilometers, located in the Gourara-Timimoun Basin in southwestern Algeria.
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Sinopec, formerly known as China Petrochemical Corp, said in June that the GEG block has proven conventional gas resource but potentially also holds sizeable shale gas resource.
Before bidding, Sinopec conducted multiple rounds of evaluations of the target block by “fully leveraging on company’s expertise and integration” in developing unconventional oil and gas resource, Sinopec said in its in-house newspaper in June.
Sinopec is one of China’s earliest shale gas developers, operating flagship Fuling field in China’s southwest that is the country’s single-largest shale gas project.
The GEG contract follows an earlier $850 million deal in February in which Sinopec and Sonatrach agreed to jointly explore and develop Hassi Berkane-North field.
Independent Chinese firm Zhongman Petroleum and Natural Gas Company also signed a contract this week to explore and develop Zerafa II natural gas block in Algeria, following a tender award last month, ZPEC said on its official WeChat platform.
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US: PHMSA Picks Louisiana for 20-Year LNG Safety Center Lease
(P&GJ) — The U.S. Department of Transportation’s Pipeline and Hazardous Materials Safety Administration (PHMSA) has signed a 20-year lease with McNeese State University in Lake Charles, Louisiana, for its National Center of Excellence for Liquefied Natural Gas (LNG) Safety. The center will serve as a hub for research, training, and regulatory coordination on LNG safety and is designed to foster collaboration between federal agencies and industry stakeholders. McNeese was selected as the site earlier this year.
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“Louisiana is at the heart of America’s growing LNG revolution,” said U.S. Transportation Secretary Sean P. Duffy. “There is no better place to locate our Center of Excellence to ensure we safely transport this critical energy source.”
PHMSA Acting Administrator Ben Kochman called the lease “another important milestone” in building the center. Senator John Kennedy (R-LA) said the project will strengthen national energy security and support innovation in LNG operations.
McNeese President Dr. Wade Rousse said the project reflects years of planning and collaboration. “We believe having PHMSA right here in Lake Charles—working alongside us—will serve as a powerful catalyst for securing the future of our region’s vital industries,” he said.
The facility was mandated by the PIPES Act of 2020, which directed PHMSA to enhance federal expertise in LNG facility operations, serve as a repository of best practices, and facilitate stakeholder collaboration.
https://pgjonline.com/news/2025/july/phmsa-picks-louisiana-for-20-year-lng-safety-center-lease
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LNG as a Marine Fuel/Shipping
Qatar: Govt approves purchase of additional LNG cargo from spot market
The approval came during the 27th meeting of the Advisory Committee on Public Procurement held today (15 July) at the Cabinet Division. The government has approved the purchase of another cargo of liquefied natural gas (LNG) from the spot market, bringing the total number of spot purchases for 2025 to 33. The approval came during the 27th meeting of the Advisory Committee on Public Procurement held today (15 July) at the Cabinet Division.
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Finance Adviser Salehuddin Ahmed presided over the meeting, according to a press release issued by the Finance Division.
The Energy and Mineral Resources Division presented the proposal, which was approved by the committee.
As per the decision, QatarEnergy Trading LLC will supply the approved LNG cargo between 4 and 5 August. The price of each MMBtu (million British thermal units) has been fixed at $13.24, with the total cost amounting to Tk556.76 crore.
This purchase follows a previous approval on 8 July, where the committee cleared the procurement of another LNG cargo from the spot market for delivery on 28 or 29 July.
That shipment, to be supplied by Vitol Asia Pte Ltd of Singapore, was priced at $12.62 per MMBtu, with a total cost of Tk531.55 crore.
As a result, the government will spend around Tk25 crore more on the newly approved cargo, despite officials stating that LNG prices have not risen on the global market in the intervening period.
The committee also approved two additional procurement proposals from the Public Works Department during the same meeting.
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Japan urgently secures LNG cargoes amid critically low reserves
Japan has urgently secured several additional cargoes of liquefied natural gas from the United States to avert an imminent electricity supply shortage caused by rapidly declining national reserves expected at the end of July. Japan is stepping up efforts to secure liquefied natural gas (LNG) cargoes in response to a rapid and concerning decline in its energy reserves. A cargo initially destined for South Korea was recently diverted to a Japanese terminal, highlighting the exceptional nature of this situation. Originating from a terminal located in Texas, this additional shipment underscores current tensions around Japan’s energy supplies. Japan’s heavy reliance on imported LNG is especially evident during the summer months, when electricity demand peaks.
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Critical threshold approaching for reserves
According to official Japanese forecasts, national LNG reserves will reach a critical low around July 27, potentially falling to approximately 10.393 terawatt-hours (TWh), equivalent to about four days of average national electricity consumption. This decline is primarily attributed to unusually high summer demand, intensified by extreme temperatures placing significant strain on Japan’s energy infrastructure. Authorities are concerned this situation may result in localized power outages and temporary instability within certain regions’ electrical grids.
Strategic exchanges between regional stakeholders
In response to this risk, several Japanese companies have activated existing regional agreements to swiftly ensure additional LNG shipments. Cargo swaps between Japan and South Korea have been initiated, allowing both countries improved management of their respective inventories during this crisis period. These swap agreements, involving direct exchanges of cargoes between energy operators from the two countries, offer crucial flexibility amid market volatility in the region. This shared strategy is currently regarded as a pragmatic solution to the immediate energy challenges faced by these two major economies.
Immediate actions to stabilize electricity supply
Alongside securing additional LNG cargoes, Japan’s electricity grid operator has implemented extraordinary measures to reallocate electricity between regions. The Kansai and Chubu regional power grids are particularly affected by these exceptional measures, designed to prevent service interruptions during peak hours. The volume transferred could reach up to 1.49 gigawatts (GW) during the afternoon, followed by a smaller additional transfer in the early evening. Authorities have emphasized that these emergency measures will be temporary, underscoring their exceptional nature in response to the critical conditions facing Japan’s energy market.
These unprecedented initiatives highlight Japan’s current vulnerability regarding energy imports and the challenges of managing reserves during periods of heightened demand. Such a situation could prompt energy sector professionals to reassess long-term strategies for securing supplies and managing risk.
https://energynews.pro/en/japan-urgently-secures-lng-cargoes-amid-critically-low-reserves/
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Japan Conducts First Ship-to-Ship LNG Bunkering For Cruise Ship
Japan completed its first-ever LNG bunkering operation for a cruise ship on July 14, when KEYS Azalea supplied LNG fuel to ASUKA III at Chuo Wharf in Hakata Port using the ship-to-ship method. The LNG bunkering vessel KEYS Azalea is owned and operated by KEYS Bunkering West Japan Ltd., a company based in Kitakyushu City. Until now, the vessel had only carried out LNG fuel supply for car carriers and bulk carriers transporting iron ore and coal.
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This is the first time KEYS Azalea has refueled a cruise ship, and it is also the first ship-to-ship LNG bunkering operation for a cruise ship in Japan.
The ASUKA III, operated by NYK Line, is a cruise vessel fitted with engines that can run on three different types of fuel, including LNG.
The ship-to-ship technique used for bunkering involved directly connecting a hose from the LNG bunkering vessel to the cruise ship, enabling a safe and efficient fuel transfer.
KEYS Bunkering West Japan Ltd. said it will continue to deliver LNG bunkering services in a safe and stable manner. The company aims to support the expansion of LNG fuel usage and help build a carbon-neutral society in Japan.
The ownership of KEYS Bunkering West Japan Ltd. is shared by Kyushu Electric Power Co., Inc. (40%), NYK Line (40%), ITOCHU ENEX CO., LTD. (15%), and Saibu Gas Co., Ltd. (5%). The company is engaged in the sales of LNG fuel and is the owner of the LNG bunkering vessel.
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Japan: ‘K’ Line receives LNG-fuelled car carrier
A car carrier with a capacity of 6900 vehicles has been delivered to Kawasaki Kisen Kaisha, Ltd (‘K’ LINE). The vessel is mainly fuelled by LNG and had been constructed by SHIN KURUSHIMA TOYOHASHI SHIPBUILDING CO., LTD. A naming ceremony was held on the day of the delivery, and the vessel was named TETHYS HIGHWAY after a sea goddess from the Greek mythology by Tsuguo Fukumura, Senior Executive Officer of Motors Limited.
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Using LNG as fuel is expected to reduce emissions of carbon dioxide, a greenhouse gas, by 25% to 30% and emissions of sulfur oxides, which cause air pollution, by almost 100% in comparison with conventional vessels using heavy fuel oil.
https://www.lngindustry.com/small-scale-lng/18072025/k-line-receives-lng-fuelled-car-carrier/
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France: TotalEnergies to Form LNG Bunkering JV with CMA CGM
TotalEnergies SE and CMA CGM Group on Wednesday announced an agreement to form a 50-50 venture to supply liquefied natural gas (LNG) fuel at the Port of Rotterdam, the Netherlands. The French companies “will offer a complete logistics service, from reload access at Gate terminal facilities to LNG bunker delivery to a wide range of vessels operating in the Amsterdam-Rotterdam-Antwerp (ARA) region, including those of CMA CGM as well as other shipping operators”, a joint statement said.
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“The joint venture will capitalize on TotalEnergies’ established logistics infrastructure in the ARA region, where the 18,600-cubic-meter LNG bunker vessel Gas Agility has been in operation since 2020. By integrating the JV’s future LNG bunker vessel with Gas Agility, the partnership aims to create synergies that enhance delivery flexibility and boost operational efficiency across the region”.
The joint venture targets to deploy a new 20,000-cubic-meter (706,293.33 cubic feet) LNG bunker vessel by 2028.
The creation of the joint venture needs regulatory approvals.
TotalEnergies also agreed to supply Marseille-based CMA CGM with up to 360,000 metric tons of LNG annually from 2028 to 2040. The supply will support CMA CGM’s expansion of its LNG-powered fleet to 123 vessels by 2029, the statement said.
That new deal is on top of two previous supply agreements. In 2017 TotalEnergies agreed to deliver 300,000 metric tons of LNG a year to CMA CGM in Rotterdam for 10 years. In 2019 another 10-year agreement was penned for TotalEnergies to supply 250,000 metric tons per annum to CMA CGM at Marseille Fos.
CMA CGM chair and chief executive Rodolphe Saade said, “For the first time, a shipping company and an energy provider will jointly operate an LNG bunkering vessel, based in the port of Rotterdam”.
TotalEnergies counterpart Patrick Pouyanne commented, “We are proud to further contribute, alongside a partner like CMA CGM, to the development of an LNG bunkering supply chain in one of Europe’s leading port hubs”.
Earlier this year TotalEnergies and Oman’s state-owned OQ Exploration and Production SAOG (OQEP) started building a liquefaction plant with a capacity of one million metric tons per annum (MMtpa) to serve the Gulf’s marine fuel market.
As part of the $1.6-billion project, called Marsa LNG, the partners signed a charter for a new LNG bunkering vessel, which will be dispatched in Sohar from 2028 to supply LNG to container ships, tankers and cruise ships.
“Ideally located at the entrance to the Gulf, the Marsa LNG site has been selected to establish the first LNG bunkering hub in the Middle East”, TotalEnergies and OQEP said in a joint statement May 1.
TotalEnergies says it holds an integrated position in the LNG value chain from production, transportation, access to over 20 MMtpa of regasification capacity across Europe, trading and LNG refueling.
TotalEnergies aims to increase the share of natural gas in its sales mix to nearly 50 percent by 2030.
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Bangladesh to buy 3 more spot LNG cargoes in Aug & Sept
The government is eyeing to import three liquefied natural gas (LNG) cargoes from spot market in late August and September. State-run Rupantarita Prakritik Gas Company Ltd (RPGCL) floated a tender to these spot LNG cargoes for August 30-31, September 10-11, and September 21-22 delivery windows expecting reasonable price quotes, a senior RPGCL official said. The bid submission deadline is July 27, he said.
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The volume of the spot LNG cargo is around 3.36 million Brithish thermal unit (MMBtu).
The cargoes are to be delivered to Moheshkhali Island, with an option to discharge it at either of the country’s two floating storage re-gasification units located on the island.
Bangladesh already bought four spot LNG cargoes for delivery in August, and if the tender turns out successful, the country’s spot LNG cargo purchase for August deliveries would be five.
Bangladesh has procured five spot LNG cargoes for July delivery.
The South Asian country has been purchasing increased volume of spot LNG cargoes over the past several months under a plan to boost natural gas supplies to industries, said the RPGCL official.
Bangladesh awarded its latest spot LNG cargo tender to Vitol Asia Pte Ltd for August 28-29 delivery window at US$12.43 per MMBtu, the RPGCL official said.
The RPGCL is a part of Petrobangla and looks after LNG trading in Bangladesh.
In addition to spot LNG cargoes, Bangladesh has been importing LNG from its two existing long-term suppliers — QatarEnergy LNG (formerly Qatargas) and OQ Trading International — for regasification at its two operational floating, storage and re-gasification units (FSRUs).
Bangladesh has been rationing gas supply to industries, power plants and other gas-guzzling consumers to cope with the mounting natural gas demand.
The country’s overall natural gas output — local gas and imported LNG combined — was around 2.832 million cubic feet per day (mmcfd) including 1,022 mmcfd of re-gasified LNG, against the demand for over 4,000 mmcfd, according to official data as on July 23, 2025
https://thefinancialexpress.com.bd/trade/bangladesh-to-buy-3-more-spot-lng-cargoes-in-aug-sept
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Technological Development for Cleaner and Greener Environment Hydrogen & Bio-Methane
China’s Envision Energy Launches World’s Largest Green Hydrogen and Ammonia Plant
China’s Envision Energy has launched the world’s largest green hydrogen and ammonia plant in Chifeng, Inner Mongolia. The plant sits in the Net-Zero Industrial Park. It runs completely on off-grid renewable sources like wind, solar, and battery storage. Artificial intelligence manages its operations. The facility will start with a capacity of 320,000 tonnes of green ammonia each year. It plans to begin exports in the fourth quarter of 2025. This milestone is key for large-scale decarbonization. It puts China in a leading role in the global hydrogen economy.
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Off-Grid & On Point: The World’s Smartest Hydrogen Plant
Envision’s Chifeng plant stands out as it operates fully off-grid, unlike many hydrogen facilities that still rely on fossil fuel-powered grids. This means it uses only renewable sources for electrolysis and ammonia synthesis. Thus, there are no carbon emissions from energy input. AI is key in managing these operations. It helps keep energy supply and demand balanced in real time.
A particularly innovative feature is the use of surplus renewable energy to produce and store liquid nitrogen. This helps stabilize the system when the wind or sun is low, providing a steady, reliable energy supply.
With this system, AI, clean power, and storage tech help solve a big problem in green hydrogen production: the unpredictability of renewable energy.
From Mongolia to the World: Scaling Up Clean Ammonia
Envision’s ammonia output is already the largest in the world at 320,000 tonnes per year. But they plan to grow this capacity to 1.5 million tonnes each year by 2028. This nearly fivefold expansion signals the company’s long-term commitment to clean fuels and global exports.
In line with these goals, Envision has secured a major offtake agreement with Marubeni Corporation of Japan. The deal will supply green ammonia to sectors like fertilizers, chemicals, and shipping. These markets are looking for low-carbon options.
Ammonia is key as a hydrogen carrier. It makes storage and transport easier than pure hydrogen gas. This makes it especially attractive for industries such as global shipping and heavy manufacturing, which require scalable clean fuels.
By enabling ammonia production using green hydrogen from renewable energy, Envision’s plant supports both climate targets and energy security. China is pushing hard on clean energy. This project highlights the country’s growing role in global decarbonization.
The country ramped up its clean power output to a record-breaking 951 TWh in the first quarter of 2025, up 19% from Q1 2024. Renewables account for nearly 39% of its total electricity mix. Wind (307 TWh) and solar (254 TWh) led the surge, with solar generation growing by 48%, marking the first time these sources combined surpassed hydropower in China’s power mix.
The Global Hydrogen Market: Strong Growth Ahead
The launch of Envision’s hydrogen facility aligns with accelerating global trends in green hydrogen. Market analysts project explosive growth over the next decade:
The green hydrogen market, valued at around $8 billion in 2024, is forecasted to reach around $300 billion by 2035.
Hydrogen could supply up to 24% of global energy demand by 2050.
Such projections are driven by falling costs and stronger policy support. Electrolyzer technologies are becoming more efficient and affordable, and renewable energy is now the cheapest source of new electricity in many regions. As such, green hydrogen is becoming more competitive with fossil-based hydrogen. This is especially true in tough-to-decarbonize sectors.
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Australia’s Energys gets green light for hydrogen plant in Victoria
Australia’s hydrogen company Energys has received planning approval for its green hydrogen production facility in Hastings, Victoria, following what the company described as 18 months of engagement with the Victorian planning system. As informed, the project is a commercially focused green hydrogen B2B industrial supply initiative aimed at displacing grey hydrogen produced from natural gas.
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It is understood that at the core of the facility will be a 1 MW proton exchange membrane (PEM) electrolyzer, reportedly powered by grid electricity during periods of surplus renewable generation and low wholesale energy prices.
Under a strategic agreement, Australia’s hydrogen producer Coregas will operate the site and manage all downstream logistics, including compression, liquefaction, cylinder and trailer filling, as well as distribution to end users, Energys revealed, adding that the hydrogen produced will be marketed and sold under commercial terms through Coregas.
To note, hydrogen supplied from Hastings is expected to reduce emissions in the stationary power, along with road and marine transport markets, through the displacement of diesel.
Roger Knight, CEO of Energys, commented: “This project positions Victoria at the forefront of green hydrogen innovation. By displacing emissions-intensive grey hydrogen with a zero-carbon alternative, we are making a tangible contribution to decarbonising key sectors such as industrial gas, transport and stationary energy.”
https://www.offshore-energy.biz/australias-energys-gets-green-light-for-hydrogen-plant-in-victoria/
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Hydrogen Integration Into Existing Natural Gas Infrastructure: Opportunities, Challenges, and Industry Pathways
This article explores the integration of hydrogen into existing natural gas infrastructure and introduces practical solutions, including the application of machine learning models, to support decision-making and infrastructure adaptation in the energy transition. The global energy sector is navigating a critical transition, with decarbonization and energy security emerging as top priorities. Both natural gas and hydrogen play essential roles in this process. Natural gas continues to serve as a reliable, high-energy-density fuel for power generation, heating, and industrial operations. At the same time, hydrogen offers a clean, flexible energy carrier that can significantly reduce greenhouse gas emissions when produced from low-carbon or renewable sources.
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Rather than viewing these fuels as competing options, the energy industry is increasingly adopting a combined approach that leverages the strengths of both. Blending hydrogen with natural gas provides a practical, near-term solution to lower emissions without sacrificing energy reliability. Crucially, this strategy takes advantage of the extensive natural gas infrastructure already in place, including pipelines, storage facilities, and compressor stations. Using existing infrastructure avoids the significant costs and time required to build dedicated hydrogen transport networks (Huang et al., 2025). It allows for early hydrogen adoption at scale, providing a realistic, phased approach to decarbonization while preserving system flexibility and energy security. Countries and companies worldwide are pursuing hydrogen/natural gas blending to meet emissions targets, optimize infrastructure investment, and prepare for a low-carbon energy future.
This article focuses on exploring the opportunities, challenges, and industry pathways for integrating hydrogen into existing natural gas infrastructure. It highlights the global shift toward hydrogen/natural gas blending, examines key technical barriers such as hydrogen embrittlement in pipeline materials, and presents ongoing research efforts aimed at ensuring the safe and reliable operation of blended gas systems. The article also introduces practical solutions, including the application of machine learning models, to support decision-making and infrastructure adaptation in the energy transition.
In Europe, the NaturalHy project investigated the technical, economic, and safety aspects of hydrogen injection into gas pipelines. The UK has seen similar efforts, including the HyDeploy and H21 Leeds CityGate projects, aimed at assessing the safe delivery of hydrogen/natural gas blends to consumers. China launched its first comprehensive experimental platform in 2024, designed to evaluate hydrogen blending into municipal gas systems (Mahajan et al., 2022). These efforts demonstrate that introducing controlled amounts of hydrogen into existing pipelines can significantly lower hydrogen transport costs, reduce carbon footprint, maximize the use of current infrastructure, and accelerate the development of hydrogen as a mainstream energy solution.
A study by Huang et al. demonstrated that hydrogen-blended natural gas (HBNG ) usage for power generation significantly reduces carbon emissions, primarily because of hydrogen’s high calorific value and its zero carbon emissions at the point of use. This reduction in emissions yields measurable economic benefits through participation in carbon markets. As illustrated in Fig. 1, the study further revealed that, when the hydrogen blending ratio (HBR) reaches 20%, the HBNG consumption decreases from 0.105 to 0.080 kg/kWh, accompanied by a reduction in carbon intensity from 0.468 to 0.374 kg/kWh. Additionally, the carbon-related economic benefit increases with higher blending ratios, reaching 0.0333 CNY/kg at 20% HBR, underscoring both environmental and economic advantages of hydrogen integration.
Although hydrogen blending offers notable environmental and economic benefits, it also introduces several technical and operational challenges for existing natural gas pipelines. One of the more critical issues is the risk of material degradation caused by hydrogen embrittlement. Hydrogen embrittlement occurs when hydrogen atoms penetrate metallic structures, especially high-strength steels, leading to a reduction in both ductility and resistance to crack growth. This phenomenon can significantly increase the likelihood of premature cracking or failure in pressurized pipeline systems.
Common pipeline materials such as API 5L X52, X60, and X70 steel grades, extensively used for natural gas transmission, have shown susceptibility to this form of degradation under specific conditions. The presence of welds, microstructural heterogeneities, and operational stresses further complicate the assessment of pipeline integrity in hydrogen-blended environments. These challenges demand a comprehensive understanding of how hydrogen behaves within the existing infrastructure and how materials and systems respond over time.
Recognizing the technical challenge, numerous studies have examined hydrogen’s effects on pipeline steels and material reliability. However, most existing research focuses on pressure vessels or structural materials, leaving typical pipeline operating conditions underrepresented. This is particularly important as hydrogen saturation in carbon steel and the associated risk of embrittlement occurs between 0.1 and 7 MPa, with the embrittlement effect stabilizing around 6.5 MPa, according to a recent study (Ahmed et al., 2024). Additionally, many studies rely on electrochemical hydrogen charging, which does not fully reflect real pipeline conditions where pressure, temperature, and gas composition continuously vary (Giarola et al., 2022; Hoyos et al., 2019). Addressing these gaps requires targeted research under realistic service conditions to better understand how hydrogen affects fracture toughness and ensure pipeline integrity.
In response to this gap, our ongoing research (Gyaabeng et al., 2025) funded by the US Department of Transportation (DOT-PHMSA), focuses on evaluating the fracture toughness of commonly used pipeline steels, including API 5L X52, X60, and X70 grades, in hydrogen environments. The study involves exposing steel specimens to high-pressure hydrogen at varying temperatures, followed by fracture toughness testing and detailed microstructural analysis.
By correlating material composition, microstructural features, and mechanical performance, this research aims to quantify degradation mechanisms associated with hydrogen embrittlement and generate practical data to guide material selection and ensure the integrity of pipelines intended for hydrogen-natural gas blending. Engineers can define an operational window to minimize crack propagation and early failure by precisely measuring and predicting fracture toughness in hydrogen-exposed pipelines.
In addition, Gyaabeng et al. have also developed machine learning models aimed at predicting hydrogen embrittlement in pipeline steels. These models use experimental data, steel composition, and microstructural characteristics to forecast material performance under varying hydrogen concentrations and service conditions.
This approach offers a powerful, nondestructive tool for assessing material suitability and integrity before failures occur. While the application of machine learning enhances predictive capabilities, it also highlights areas of uncertainty, particularly regarding the influence of extreme conditions or rare material defects that may limit the accuracy of purely data-driven models. As such, the combined use of experimental testing and machine learning provides a more comprehensive understanding of material behavior, supporting the safe integration of hydrogen into existing pipeline infrastructure.
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German Regulator Sets Hydrogen Pipeline Tariff, Aims for Investment & Affordability
Germany’s pipeline regulator has finalised a uniform tariff for the nation’s burgeoning hydrogen pipeline “core network” to spur investment while keeping costs manageable for early adopters. The Federal Network Agency (BNetzA) confirmed a fee of €25 ($29.23) per kilowatt-hour of energy per hour, a rate operators can charge customers for using the infrastructure. The BNetzA calculated the tariff, expressed as “€25/kWh/h/a” to signify a user’s right to transport a set amount of hydrogen hourly throughout a year, to be high enough to recoup significant investment costs, yet affordable for initial users.
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Expected to be completed by 2032, the ambitious 9,000-kilometre (approximately 5,600-mile) core network carries an estimated combined investment of €18.9 billion (roughly $21.9 billion).
The German government has already established a €24 billion (27.8 billion) “amortisation account” to help pipeline operators undertake the massive project and repay this fund as their revenues grow, aiming to settle the balance by 2055.
Should a shortfall occur, operators will be responsible for 24% of the deficit, with the German government covering the remainder.
While the BNetzA intends for the fee to remain constant until 2055, it will conduct triennial reviews to ensure the tariff remains sufficient for operators to rebalance the amortisation account.
“We are creating planning security for all market participants and enabling access to the hydrogen core network at a reasonable price,” Klaus Müller, president of BNetzA stated on Monday, July 14.
Initial sections of this critical hydrogen pipeline are already nearing completion and are being filled with hydrogen this year.
Such projects include the Nowega’s 55-kilometre (34-mile) pipeline for the GET H2 network and Ontas’ 25-kilometre (15.5-mile) link connecting the Bad Lauchstädt Energy Park with TotalEnergies’ Leuna refinery.
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New green hydrogen method turns wastewater and crop residue into clean fuel
Using metals in dirty water, researchers created a device that makes green hydrogen with no need for purified water. Green hydrogen has emerged as a key clean fuel for the future, promising zero emissions when produced with renewable energy. But the process usually demands large volumes of purified freshwater, which is a costly challenge in water-scarce regions. On the other hand, over 80% of global wastewater is released untreated into the environment, causing serious ecological harm.
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Now, a team led by RMIT University has found a way to solve both problems with one invention.
Their experimental technology turns wastewater’s contaminant load into a catalyst for producing green hydrogen, offering a path toward sustainable fuel production without the need for freshwater.
The research, conducted with the University of Melbourne, Australian Synchrotron, and the University of New South Wales, aims to transform a global environmental liability into a productive asset.
Metal-rich waste becomes resource
The team’s breakthrough uses metals already present in wastewater, such as platinum, chromium, and nickel, to enhance the hydrogen production process. Instead of filtering out these metals, the system captures and uses them.
“The advantage of our innovation over others to produce green hydrogen is that it harnesses wastewater’s inherent materials rather than requiring purified water or additional steps,” said Associate Professor Nasir Mahmood from RMIT’s School of Science.
The team created special electrodes with an absorbent carbon surface that pulls metals from the wastewater. These metals then form stable catalysts that help conduct electricity and accelerate the water-splitting process. “The metals interact with other elements in the wastewater to boost the electrochemical reactions needed for splitting water into oxygen and hydrogen,” Mahmood said.
The carbon material used for these electrodes is made from agricultural waste, adding another layer of sustainability and cost efficiency to the system.
Green fuel, cleaner water
In lab tests, the researchers placed two electrodes into a container of partially treated wastewater and applied renewable energy.
At the cathode, water molecules gained electrons and released hydrogen gas. At the anode, they lost electrons and produced oxygen.
“The produced oxygen can be reintegrated into wastewater treatment plants to enhance their efficiency by reducing organic content,” said Mahmood.
The system ran continuously for 18 days with minimal decline in performance.
The wastewater used had been pre-treated to remove solids, organic matter, and nutrients, making it representative of real-world applications.
RMIT’s innovation is part of a broader platform of catalytic systems aimed at using difficult water sources like wastewater and seawater for clean hydrogen production.
“Our innovation addresses both pollution reduction and water scarcity, benefiting the energy and water sectors,” said Professor Nicky Eshtiaghi of RMIT’s School of Engineering. “By using wastewater, the process helps reduce pollution and makes use of materials considered to be waste.”
https://interestingengineering.com/energy/clean-hydrogen-from-contaminated-water
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Stellantis Drops Plans to Launch Hydrogen-Powered Vehicles
Chrysler, Dodge, Jeep, and Citroen parent Stellantis announced that it has decided to discontinue its hydrogen fuel cell technology development program due to a lack of progress in the hydrogen market. As part of its decision, Stellantis said that it has dropped its plans to launch a new range of hydrogen-powered vehicles this year.
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The expansion of hydrogen fuel cell technology was a component of Stellantis’ strategic plan, Dare Forward 2030, launched by the company in 2022, including plans to reach production capacity of hydrogen-powered vans of more than 10,000 units per year by 2025. In 2023, Stellantis acquired a 33% stake in hydrogen fuel cell systems company Symbio, taking an equal share in the company with joint venture partners Michelin and automotive technology provider Faurecia. In 2024, Stellantis announced plans to start industrial scale production of “Pro One” hydrogen fuel cell vans at its plants in Hordain, France and Gliwice, Poland.
In its update, however, the company said that it will no longer launch the new hydrogen fuel cell vans, and that it has initiated discussions with the Symbio shareholders “to evaluate the current market consequences” of its decision. Stellantis accounts for most of Symbio’s business volume.
According to Stellantis, the decision was made due to a series of factors, including the limited availability of hydrogen refueling infrastructure, as well as high capital requirements, and the need for stronger consumer purchasing incentives, with the company adding that it “does not anticipate the adoption of hydrogen-powered light commercial vehicles before the end of the decade.”
https://www.esgtoday.com/stellantis-drops-plans-to-launch-hydrogen-powered-vehicles/
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Saudi Arabia signs agreements for green hydrogen, power exports to Europe
RIYADH, 20th July, 2025 (WAM) — Saudi Arabia’s ACWA Power signed today in Riyadh agreements and memoranda of understanding (MoUs) with several international partners, aimed at creating a green hydrogen and renewable energy export value chain between Saudi Arabia and Europe.
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The signing of these agreements and MoUs comes as part of the Kingdom’s pioneering role in enhancing global logistics connectivity and its leadership in the India-Middle East-Europe Economic Corridor (IMEC) project, driven by its strategic geographical location that connects East and West.
The agreements and MoUs were signed during the Renewable Energy and Green Hydrogen Export Workshop, led by ACWA Power under the supervision of the Ministry of Energy. The event brought together high-level government representatives from Saudi Arabia, Greece, France, and Germany, alongside executives from global specialised companies and leading national institutions.
The workshop showcased the Kingdom’s progress in diversifying its energy mix and promoting regional and international integration in clean energy-reinforcing its position as a reliable global supplier of energy and a key leader in the economic corridor connecting East and West.
Moreover, a joint development agreement was concluded for collaboration on the first phase of the Yanbu Green Hydrogen Hub, which is planned to be ready for commercial operations by 2030.
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France: BarMar company launched to develop H2med hydrogen pipeline
The BarMar company has been launched to develop the BarMar renewable hydrogen pipeline that will connect Barcelona in Spain to Marseille in France. The initiative to form the new company, a joint venture between the Spanish gas TSO Enagás through its affiliate Enagás Infraestructuras de Hidrogeno (EIH) and the two French gas TSOs NaTran and Teréga, is considered to mark a significant milestone in the H2med project.
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H2med is aimed to transmit up to 2Mt of green hydrogen annually produced in Portugal and Spain from renewable energy sources into Germany and elsewhere in northern and central Europe, with BarMar the main component.
BarMar is a 450km submarine pipeline connecting the two countries with a capacity of 2Mt per year. This will then connect from the hydrogen base in France to the hydrogen infrastructure under development in Germany and the rest of northwest Europe.
The second component is the CelZa 248km pipeline with a capacity of 0.75Mt per year between Celorico da Beira in Portugal and Zamora in Spain – the two main hydrogen backbones under development in the two countries.
H2med, named a project of common interest and due to come online in 2027, is expected to transport around 10% of Europe’s estimated hydrogen consumption in 2030, providing the region with decarbonised hydrogen produced at competitive cost.
It also should accelerate Europe’s decarbonisation roadmap and support the flexibility of the energy grid through access to underground hydrogen storage capacities.
The new company, which will be based in the south of France, in the Provence-Alpes-Côte d’Azur region, defines the governance structure of the project.
Francisco de la Flor García, Director of Enagás, has been appointed as the CEO.
Bringing more than 35 years of experience in the energy and natural gas sectors, he also currently chairs the UNECE Gas Expert Group and is a member of the IGU Executive Committee and Council.
Arturo Gonzalo, CEO of Enagás, said the creation of this JV embodies a collective commitment and determination to deliver this vital energy infrastructure for Europe.
“This marks the beginning of a new operational phase that will allow us to address the technical and regulatory challenges with an integrated team and a common goal: to make H2med a reality.”
Sandrine Meunier, CEO of NaTran said the JV provides the necessary framework for the long-term development of the BarMar hydrogen pipeline.
“It also gives concrete form to cross-border cooperation in the development of strategic energy infrastructure to decarbonise our industries. Based in France, BarMar is now a place where all the partners’ expertise in hydrogen transport will converge to promote a new phase of energy in Europe.”
Carolle Foissaud, CEO of Teréga, added that the announcement places H2med at the heart of Europe’s energy sovereignty and allows it to achieve the goals of carbon neutrality.
“Together with its partners, Teréga is fully mobilised to make this European clean hydrogen corridor a success for the decarbonisation of our industries and regions.”
This BarMar company announcement follows the reconfirmation of European support for the project and the recent signing of grant agreements with the European Executive Agency for Climate, Infrastructure and Environment (CINEA) for the two pipelines.
The guaranteed funding represents 100% of the funds requested under the Connecting Europe Facility (CEF) and covers 50% of the development costs, enabling the launching of the engineering studies, maritime reconnaissance surveys and environmental impact assessments required for the permitting process.
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