NGS’ NG/LNG SNAPSHOT August 1-15, 2025
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City Gas Distribution & Auto LPG
99K TN households have got PNG connections
CHENNAI: Around 99,000 households in Tamil Nadu have been provided piped natural gas (PNG) connections. According to a statement made in Parliament by the union government, pipelines for supplying natural gas have been laid along 45% of the planned 37,374 km network intended to supply PNG to domestic consumers. As per the Minimum Work Programme (MWP) set by the Petroleum and Natural Gas Regulatory Board, the goal is to provide 2.32 crore domestic PNG connections and lay 37,374 km of pipelines by 2032.
CHENNAI: Around 99,000 households in Tamil Nadu have been provided piped natural gas (PNG) connections. According to a statement made in Parliament by the union government, pipelines for supplying natural gas have been laid along 45% of the planned 37,374 km network intended to supply PNG to domestic consumers. As per the Minimum Work Programme (MWP) set by the Petroleum and Natural Gas Regulatory Board, the goal is to provide 2.32 crore domestic PNG connections and lay 37,374 km of pipelines by 2032.
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This information was shared by Suresh Gopi, Minister of State for Petroleum and Natural Gas, in response to questions raised by DMK MPs CN Annadurai and G Selvam regarding the status of PNG infrastructure in Tamil Nadu.
The state has been divided into 18 geographical areas for the implementation of city gas distribution networks. Pipeline laying activities are being carried out by various authorised entities, including BPCL, Megha City Gas, IOCL, IRM Energy, Adani Total Gas, Think Gas (formerly AG\&P), and Torrent Gas. These companies were granted authorisation between 2018 and 2022.
As of May this year, Tamil Nadu has recorded 98,878 PNG connections. Coimbatore tops the list with 38,362 connections, followed by the Nilgiris with 18,882, and Salem district with 4,593 connections.
In terms of pipeline development, 3,063 km have been completed in Coimbatore, 2,433 km in Chennai and Tiruvallur districts, and 2,011 km in Kancheepuram.
Gopi said both the government and the PNGRB continuously monitor the progress of CGD projects through regular reports submitted by the entities. In cases of delays or shortfalls, the board steps in by advising corrective measures, which may include convening progress review meetings or holding statutory hearings to address challenges and assess updates related to their MWP targets.
Reply in parliament
TN has been divided into 18 geographical areas for city gas distribution networks
As of May this year, the state has recorded 98,878 PNG connections
Coimbatore tops the list with 38,362 connections, followed by the Nilgiris (18,882) and Salem (4,593)
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MTC ties up with Torrent Gas, THINK Gas to boost CNG infrastructure
CHENNAI: The Metropolitan Transport Corporation (MTC), Chennai, has signed a Memorandum of Understanding (MoU) with Torrent Gas Chennai and AG&P CGD India(now THINK Gas) to develop captive Compressed Natural Gas (CNG) filling stations at its bus depots.
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As part of this collaboration, CNG stations will be established at the existing Ambattur depot and the upcoming Varadharajapuram depot in Kanchipuram district. These facilities will support MTC’s transition to cleaner fuels through the deployment of CNG-fuelled buses.
The MoU was formalised on Thursday in the presence of Phanindra Reddy, Additional Chief Secretary, Transport Department, on the day of his retirement, Prabhushankar, Managing Director, MTC Chennai, and other senior officials.
As one of India’s leading gas distribution companies, THINK Gas has partnered with MTC to facilitate the rollout of CNG buses, beginning with the new Varadharajapuram depot. The company will supply CNG for MTC-operated buses and set up refuelling infrastructure within the depots.
Speaking on the occasion, Vinukumar S Balakrishnan, chief marketing officer and head – commercial, THINK Gas, said: “We’re committed to building robust and reliable CNG infrastructure to support clean and affordable urban mobility solutions. We are proud to be part of TN’s journey towards a cleaner, greener future and look forward to expanding this initiative to other MTC depots across the state in the coming months.”
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Piped natural gas is changing lives in Coimbatore
Coimbatore: Around 4,000 residents in the district are now free from the hassle of booking liquefied petroleum gas (LPG) cylinders and waiting for their delivery, thanks to Indian Oil Corporation Limited (IOCL), which has started providing them with piped natural gas (PNG).
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“Switching to piped natural gas has made our lives so much easier,” says K Malathi, of Vellalore, who has been using PNG for the past 10 months. “Earlier, my husband and I, both working, had to wait uncertainly for the delivery of LPG cylinders. We also had to depend on delivery boys to carry the cylinder to our apartment on the first floor. Now, we don’t face that hassle.”
For the same cost as an LPG cylinder that lasted about three months, the couple says their PNG supply comfortably lasts for four months. “It’s more convenient, and saves us time and effort,” says Malathi.
The IOCL has laid a network of underground steel pipelines for 103 kilometres in the district from the City Gas Station (CGS) at Pichanur near Madukkarai. It draws gas from Kochi to efficiently deliver natural gas to residential areas.
“Residents in areas such as Vellalore, Malumichampatti, Kaniyur and Arasur were provided connections within a year. In the next two months, supply is expected to begin at Cheran Ma Nagar, Kalapatti, Vilankurichi and Nehru Nagar. Next phase will cover Saravanampatti, Chinnavedampatti and Vellakinaru areas. Our plan is to provide at least three lakh connections across the district by the end of 2030,” said an IOCL official.
PNG consists of more than 90% methane and is a lighter fuel, he says. “In the event of a leakage, it evaporates into the air. For safety purposes, the pipeline is equipped with a safety valve every kilometre.”
IOCL offers three schemes for domestic customers, with billing based on meter readings every 60 days. Customers are not allowed to make cash payments either for new connections or regular billing. Only online payments are accepted through UPI, debit/credit cards, net banking and mobile wallets.
IOCL has also started supplying PNG to industries. A Jaganathan, manager of a firm at Malumichampatti that makes SAARC cases, military cases and roto-moulded protective cases, says the burner pressure in PNG is higher compared to LPG, which is an advantage for their operations.
“When we used LPG, the low pressure often led to production losses. In contrast, PNG provides high pressure along with an uninterrupted 24×7 supply. There is no need to maintain an inventory of LPG cylinders, and maintenance issues are significantly reduced. Gas consumption is also lower with PNG, making it at least 12% to 15% more cost-effective” he says.
According to the IOCL officer, three industries have already been provided connections. “Six industries at Arasur are expected to be connected in the coming days. PNG connections will also be extended to educational institutions, hotels and bakeries in a phased manner.”
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Bihar Transport Dept Hosts CNG Seminar to Propel Green Mobility and Reduce Pollution
Patna: In a concerted effort to combat vehicular pollution and promote sustainable transportation, the Bihar Transport Department, in collaboration with the Petroleum and Natural Gas Regulatory Board (PNGRB), hosted a one-day state-level CNG seminar at Hotel Maurya on Wednesday. The event brought together key stakeholders, including vehicle manufacturers, CNG infrastructure companies, oil companies, environmental experts, and transporters.
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Additional Chief Secretary of the Transport Department, Mihir Kumar Singh, inaugurated the seminar, emphasizing the government’s commitment to expanding CNG accessibility. He announced plans to establish CNG stations at Bihar State Road Transport Corporation (BSRTC) and other bus stands to ensure easy availability for public transport vehicles.
Singh also stressed the need for extensive awareness campaigns to promote the adoption of both piped natural gas (PNG) for domestic use and CNG for vehicles. He suggested leveraging the electricity department’s consumer database to make these campaigns more targeted and effective.
State Transport Commissioner Ashutosh Dwivedi highlighted that the seminar’s objective was to promote alternative, environment-friendly fuels, particularly Compressed Natural Gas (CNG), and to discuss related policies, challenges, and opportunities. “CNG is the fuel of the future,” he asserted, noting the state government’s proactive steps in promoting it.
A presentation by GAIL revealed significant progress: all 38 districts of Bihar are now connected to the CNG network. Currently, 197 CNG stations are operational, with an additional 55 new stations expected to commence operations within the next six months. To ensure safety and quality, cylinder testing units have also been activated. The state has already seen over 1.5 lakh autos and more than 1200 CNG buses transition to this cleaner fuel.
Additional Secretary of Urban Development and Housing Department, Vijay Prakash Meena, spoke about the state government’s efforts to transform waste management into a circular economy model, aiming to convert waste into resources, thereby conserving natural resources and saving energy.
The seminar also featured presentations on Bihar’s City Gas Distribution (CGD) policy, future plans for infrastructure development, and the technical benefits of CNG vehicles. Dignitaries present included Anjani Kumar Tiwari, Member, PNGRB; Dr. Neeraj Narayan, Member Secretary, Bihar State Pollution Control Board; and other senior officials from various departments.
https://patnapress.com/bihar-cng-seminar-green-mobility/
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ONGC Lines Up Rs 4,600 Crore War Chest To Boost Oil & Gas Production From Eastern Offshore Fields
New Delhi: Oil and Natural Gas Corporation (ONGC) plans to invest over Rs 4,600 crore to drill more wells to increase production from its discovered fields, lay an offshore pipeline, and set up a gas processing facility in the coastal Konaseema district of Andhra Pradesh. The public sector upstream oil giant sought the approval of the Ministry of Environment and Forests for the project and has been asked to carry out a biodiversity assessment to evaluate the impact of drilling activities and prepare an environmental restoration action plan to go ahead with the project, a senior official said.
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The ONGC field is located 35 kilometres off the coast of Andhra Pradesh in water depths ranging from 300-3,200 metres. The discoveries of oil and gas in the block are divided into three clusters— Clusters 1, 2, and 3 across an area of 697 sq km.
ONGC has recently increased production from its flagship deep-sea project in the Krishna Godavari basin off the Andhra Pradesh coast, which will help augment the production of crude oil and natural gas
The upstream oil company is focused on raising production in the second half of FY25 (2024-25) by reducing the turnaround time for opening wells, the official said.
“Three oil wells of A-field of deepwater block KG basin block KG-DWN-98/2 were opened on October 30, 2024, thereby enhancing total oil production to about 25,000 barrels of oil per day from eight flowing wells of cluster-II. The remaining five oil wells are planned to be opened shortly,” ONGC said in an exchange filing recently.
In a significant development, ONGC and Oil India Ltd (OIL) have also launched an ambitious exploration campaign in the Andaman ultra-deepwater region. For the first time, drilling operations are targeting depths of up to 5,000 metres. One such wildcat well, ANDW-7, drilled in a carbonate play in the East Andaman Back Arc region, has yielded encouraging geological insights. These include traces of light crude and condensate in cutting samples, heavy hydrocarbons like C-5 neo-pentane in trip gases, the government had said.
These findings establish, for the first time, the existence of an active thermogenic petroleum system in the region, comparable to those in Myanmar and North Sumatra. While commercial reserves remain to be established, this campaign has validated the presence of a working petroleum system and laid the foundation for focused exploration in the area, Minister of Petroleum and Natural Gas Hardeep Singh Puri has told Parliament.
ONGC has made hydrocarbon discoveries in 20 blocks, with an estimated reserve of 75 million metric tonnes of oil equivalent (MMTOE). Oil India Ltd., on its part, has made seven oil and gas discoveries over the past four years, with reserves estimated at 9.8 million barrels of oil and 2,706.3 million standard cubic meters of gas, the minister stated.
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Natural Gas/ Pipelines/ Company News
MNGL Commissions Second-Largest LNG-LCNG Facility in Malegaon, Nashik
Malegaon, Nashik: Maharashtra Natural Gas Limited (MNGL) has commissioned its second-largest LNG-LCNG facility at Zodge, Malegaon, along the Mumbai–Agra Highway, marking a major step in strengthening clean energy supply across the Nashik–Dhule region.
The Nashik–Dhule Geographical Area (GA), authorized by PNGRB, currently lacks pipeline connectivity. To address this gap, MNGL adopted a virtual LNG supply model, transporting LNG from terminals, re-gasifying it, and supplying it across CNG, industrial, commercial, and domestic segments.
The newly inaugurated Malegaon station is equipped with a storage capacity of 228 KL (2 × 114 KL) and a delivery capacity of over 1,50,000 SCMD, with more than 30,000 SCMD already being supplied to CNG and PNG consumers.
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Key Features of the Facility:
- Multi-stream operations: High pressure (250 bar-g) for retail and DBSs, medium pressure (19 bar-g) for large industries and CNG stations, low pressure (4 bar-g) for households and SMEs, and an auto LNG dispensing stream for heavy-duty vehicles.
- Dedicated LNG dispensing facilityto meet the growing demand from LNG-powered trucks and trailers.
- Large frontage, among the widest LNG-LCNG facilities in India, enabling smooth operations.
- Efficient boil-off gas (BOG) management, reducing losses and boosting efficiency.
The facility is expected to play a pivotal role in meeting the rising energy needs of Malegaon, Dhule, and adjoining areas, furthering MNGL’s mission to expand clean energy access in regions without pipeline infrastructure.
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Indian Oil, TNEB Mull Direct Gas Pipeline Link To Five Tamil Nadu Power Plants
Tamil Nadu Electricity Board (TNEB) and Indian Oil Corporation (IOC) officials met to explore direct pipeline links for supplying gas to five gas-based power plants across the state, The New Indian Express reported. The discussion, attended by TNEB chairman and managing director J Radhakrishnan, IOC general manager Suman Kumar Mishra, and other officials, focused on supplying Regasified Liquefied Natural Gas (RLNG) via direct pipelines to the Valuthur (187 MW), Basin Bridge (120 MW), Thirumakottai (108 MW), Kuttalam (101 MW), and Pillai Perumalnallur (330 MW) plants.
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Radhakrishnan told that in phase one, gas would be supplied to the Valuthur plant in Ramanathapuram via the existing IOC pipeline between Ennore and Thoothukudi ports.
He also urged IOC to submit a report on extending the pipeline to the Basin Bridge plant in Chennai to secure uninterrupted power supply during peak demand. Another meeting on the matter is planned.
Mishra noted that IOC operates a 440-km pipeline from Ennore to Thoothukudi and has already submitted a project plan for the Valuthur plant.
He added that IOC would now prepare a similar report for the Basin Bridge facility at TNEB’s request.
Mishra also said RLNG is currently priced at \$12 per Metric Million British Thermal Unit (MMBTU), with rates trending downward and expected to fall further.
At present, Gas Authority of India Limited (GAIL) supplies natural gas to these plants at $6.5 per MMBTU.
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Project Showcase: Durgapur-Haldia pipeline strengthens gas connectivity in the eastern region
Over the past decade, India has made remarkable progress in expanding its gas connectivity. Liquefied petroleum gas (LPG) has reached households across the country, earning international recognition for its scale and impact. The government’s “One Nation, One Gas Grid” vision – exemplified by the ambitious Pradhan Mantri Urja Ganga Yojana (PMUGY) – has been a game changer in bringing affordable, clean energy to millions. Launched to extend gas pipelines across six eastern states, including West Bengal, this initiative aims to supply affordable piped gas to industries and households alike. It also supports the wider adoption of compressed natural gas for vehicles and gas-based technologies for industries.
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A significant milestone in this journey is the integration of Durgapur’s industrial region into the National Gas Grid, promising benefits for local industries and an estimated 3 million households in West Bengal. This expansion is expected to ease daily life for many while generating employment.
Project overview and background
A crucial element of India’s gas grid vision is the Durgapur-Haldia natural gas pipeline. Constructed at a cost of over Rs 11.9 billion and spanning 132 km, this pipeline forms an integral part of the broader Jagdishpur-Haldia-Bokaro-Dhamra pipeline (JHBDPL). The JHBDPL is an extensive 3,306 km network with a planned transmission capacity of up to 23 million standard cubic metres per day (mmscmd). At present, it transports about 12.26 million cubic feet per day, linking energy-deficient eastern states to cleaner fuel sources.
Originally slated for completion by 2020-21, the project’s overall timeline has been revised from June 2024 to March 2025, and now to December 2025, reflecting the realities of on-ground hurdles such as securing right of use (RoU) for land, forest clearances and local community concerns. That said, the path to widespread gas connectivity has not been easy. In fact, the repeated mention of project delays due to land acquisition and environmental clearances highlights a systemic and persistent challenge in executing large-scale infrastructure projects across the country. This suggests that while policy intent and financial commitment are strong, on-ground implementation faces significant friction due to regulatory hurdles and clearances, which can impact project timelines and costs, even for projects of national importance.
Key stakeholders
The Cabinet Committee on Economic Affairs (CCEA) has approved a 40 per cent capital grant of viability gap funding (VGF) to GAIL (India) Limited for the execution of the JHBDPL pipeline project. The overall funding for the project amounts to around Rs 51.76 billion. Any financial liability beyond this approved capital grant will be borne by GAIL from its internal accruals.
The project is being executed, developed, owned and operated by GAIL (India) Limited, with Engineers India Limited serving as the project management consultant. The project involves around 130 critical crossings implemented using the horizontal directional drilling (HDD) technique. One of the highlights is the crossing of the Roopnarayan river using the intersect method of HDD for a stretch of approximately 2.8 km – an engineering feat that underscores the technical expertise of EIL.
Notably, IL&FS Engineering and Construction Company Limited has been awarded the contract for laying significant stretches of the pipeline in Jharkhand and West Bengal.
Project features and specifications
The Durgapur-Kolkata section, a key part of the JHBDPL project, was officially inaugurated and put under commercial operation on July 18, 2025. The entire section has an authorised total length of 294 km. The construction work for the pipeline started in December 2021. Fast forward to present, as of April 2025, while the 132 km section up to Kolkata has been commercially operationalised, 103 km of the remaining 162 km section leading to Haldia is now under construction. The completion of the entire Durgapur-Haldia section has been postponed to December 2025 due to challenges pertaining to RoU availability.
The pipeline has been constructed as an underground natural gas pipeline, laid at a minimum depth of 1.2 metres below the natural ground level. The Kolkata-Haldia mainline specifically uses a 24-inch pipeline. However, the broader Urja Ganga pipeline network, which includes the Durgapur-Haldia segment, incorporates varying pipeline diameters of 30 inches, 24 inches, 18 inches and 12 inches. Now, with this addition, the Urja Ganga pipeline network – comprising the Dobhi-Durgapur, Durgapur-Haldia and Dhamra-Haldia pipelines – spans over 1,030 km. During its implementation phase, the pipeline provided direct and indirect employment. Going forward, it will provide natural gas to households, industries, and the transportation sector in the districts of West Bengal. Upon completion, the pipeline will also be instrumental in supplying natural gas to major industrial consumers such as Haldia Petrochemicals Limited and Mitsubishi.
For JHBDPL Phase II, which covers West Bengal, pipeline diameters of 36 inches, 30 inches, 24 inches, 18 inches, 12 inches, 8 inches and 4 inches. Additionally, it covers a wider array of districts in West Bengal, including Purulia, Bankura, Bardhaman, Nadia, Hooghly, Howrah, East Midnapore and North 24 Parganas. This extensive coverage ensures that natural gas reaches a broad spectrum of consumers across the state.
Further, India’s gas grid vision doesn’t stop at Haldia. Plans are currently under way to extend the pipeline from Barauni in Bihar to Guwahati in Assam, adding another 729 km to the network. This next phase will connect to the under-construction North East Gas Grid, underscoring the government’s sustained commitment to balanced regional development and clean energy access across the entire eastern and north-eastern regions.
Strategic importance
The expansion of the gas grid to the eastern states is strategically crucial for several reasons. It addresses and aims to correct historical regional imbalances in energy infrastructure, promoting more equitable development across the nation. The targeted expansion in states such as Uttar Pradesh, Bihar, Jharkhand, West Bengal, Odisha and Assam highlights a deliberate move to integrate these regions into the national energy grid, indicating a commitment to equitable growth where infrastructure development acts as a lever for socio-economic parity across diverse geographical areas. Furthermore, it actively encourages the adoption of cleaner energy sources, thereby reducing reliance on more polluting traditional fossil fuels such as coal and oil. This shift is vital for mitigating environmental impact, aligning directly with India’s commitments to global climate goals, including the Paris Agreement.
Despite facing significant delays and challenges, the continued investment and phased commissioning of the pipeline network demonstrate the government’s unwavering commitment to the “One Nation, One Gas Grid” vision. This indicates that the strategic importance of natural gas for India’s energy future outweighs the operational difficulties, indicating a resilient and determined approach to national energy security and transition.
In sum
The successful inauguration of key segments such as the Durgapur-Kolkata section represents a crucial step towards the full operationalisation of the entire JHBDPL network. This infrastructure development is not merely about gas supply; it is a strategic investment that is solidifying India’s trajectory towards a cleaner, more efficient, and equitably distributed energy future.
All in all, the construction of the Durgapur-Haldia pipeline has been a complex undertaking, reflecting a blend of advanced engineering and persistent efforts to overcome on-ground challenges, all aimed at integrating eastern India into the national gas grid. Now, this pipeline is poised to serve as a powerful engine for West Bengal’s progress and contribute significantly to the country’s development journey towards achieving the vision of Viksit Bharat by 2047.
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ABB, THINK Gas Partner to Digitise City Gas Operations
ABB India Ltd and THINK Gas Pvt. Ltd. have formed a strategic partnership to drive digital innovation in India’s city gas distribution (CGD) sector. As part of this collaboration, THINK Gas has deployed ABB’s cloud-based ABB Ability™ SCADAvantage platform to automate and manage its gas distribution network, which supplies Compressed Natural Gas (CNG) to over 500 fuel stations across the country.
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The SCADAvantage system enables THINK Gas to centralise operations and gain real-time visibility of its network from its Chennai control room. By automating price management, billing, pressure and flow control, gas planning and reconciliation, the solution has reportedly led to up to 60 per cent reduction in operational costs, particularly in operator manpower.
THINK Gas operates across 19 Geographical Areas in ten Indian states-including Andhra Pradesh, Bihar, Himachal Pradesh, Karnataka, Kerala, Madhya Pradesh, Punjab, Rajasthan, Uttar Pradesh and Tamil Nadu. Its network includes over 500 CNG stations, approximately 550,000 domestic piped natural gas connections, and around 17,000 inch-km of steel pipeline servicing industrial and commercial customers.
Chiradeep Datta, Chief Operating Officer of THINK Gas, stated, “Our focus is on adopting global best practices in safety, infrastructure, and digitalisation to ensure reliable natural gas supply to our customers. Partnering with ABB has enabled us to optimise operations, reduce costs, and make better, data-driven decisions.”
G Balaji, Senior Vice President of the Energy Industries division at ABB India, added, “As India expands its energy infrastructure to meet rising demand, ABB’s solutions like SCADAvantage are crucial in achieving operational excellence. We are proud to support 80 per cent of the country’s CGD networks with our automation technology.”
India has committed to increasing the share of natural gas in its energy mix to 15 per cent by 2030. The growing CGD network plays a key role in this vision, providing piped cooking gas to households and CNG for vehicles, while serving industrial and commercial sectors.
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GSPC set to merge with Gujarat Gas
Gandhinagar: Gujarat govt is set to discontinue the GSPC (Gujarat State Petroleum Corporation Ltd) PSU brand, established nearly five decades ago. Over the years, GSPC has experienced numerous highs and lows and is now scheduled to merge with Gujarat Gas Ltd (GGL), a company it acquired several years ago. The long-pending compliance process between GSPC group companies and Gujarat Gas is expected to be completed by Oct, following the approval of the amalgamation plan by various Govt of India authorities and the Gujarat govt.
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The govt of Gujarat provided an “in-principle” approval for a composite scheme of arrangement involving the GSPC group of companies at a meeting chaired by chief minister Bhupendra Patel on June 19, 2024. The final approval for the scheme was granted in May this year. According to the scheme, GSPC, GSPL (Gujarat State Petronet Ltd) and GSPC Energy Ltd (GEL) amalgamate with Gujarat Gas Limited. There will also be a demerger of the Gas Transmission Business Undertaking into GSPL Transmission Limited.
GSPC, India’s second largest natural gas trading company, has significantly contributed to establishing Gujarat as a “gas-based economy” by achieving a scale that fosters greater synergies with GGL. The central govt aims to increase the share of natural gas in India’s energy basket from 6% to 15%. Over the past five years, GSPC recorded cumulative revenues exceeding Rs 1 lakh crore and a PAT of over Rs 6,500 crore. Conversely, GSPL’s growth has not been fully reflected in its valuation due to the holding company discount. A senior official commented that after the merger, valuation is expected to rise significantly.
According to sources, the exchange ratio for the amalgamation is set as follows: 10 shares of GGL (FV Rs 2) for every 305 equity shares of GSPC (FV Re 1); for GSPL, 10 shares of GGL (FV Rs 2) for every 13 equity shares of GSPL (FV Rs 10); and for the demerger of the Gas Transmission Business undertaking, 1 equity share of GTL (FV Rs 10) for every 3 equity shares of GGL (FV Rs 2).
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Policy Matters/ Gas Pricing/ Others
PNGRB’s Inaugural National Consumer Conclave Empowers Consumers in Oil & Gas Sector
New Delhi: The Petroleum and Natural Gas Regulatory Board (PNGRB) recently held its first National Consumer Conclave at the Manekshaw Centre in New Delhi. This groundbreaking event aimed to empower consumers and enhance transparency, accountability, and responsiveness within the Oil & Gas sector. PNGRB, responsible for addressing consumer grievances in the Petroleum Sector, formed a committee headed by Shri. Ratan P. Watal, Ex-Secretary, Finance, GoI, to guide its functions as mandated by the PNGRB Act.
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The day-long conclave brought together government officials, industry leaders, consumer advocacy groups, RWAs, and regulatory experts to discuss establishing a consumer-centric energy ecosystem. Shri. Watal, Chairman of the High-Level Expert Committee (HLEC), inaugurated the event, offering valuable policy insights to bolster consumer protection.
Dr. Anil Kumar Jain, Chairperson of PNGRB, highlighted the Board’s commitment to transitioning from a supply-focused to a consumer-centric regulatory framework. He stressed the significance of trust, accountability, and service transparency as the core tenets of PNGRB’s consumer protection vision. The Chairperson outlined plans for enhancing digital grievance redressal mechanisms, integrating consumer feedback into regulatory processes, and fortifying institutional safeguards to protect consumer rights.
Key Sessions at the Conclave Included:
Presentation of the HLEC Report suggesting standardized grievance redressal mechanisms, ombudsman establishment, and adoption of international best practices.
Insights from Indian and global regulatory models advocating for legal alignment, cross-sector coordination, and transparent service standards.
Industry and Consumer Dialogues highlighting the importance of digital innovation, real-time grievance resolution, multilingual engagement, and consumer-centric initiatives like feedback-driven service enhancements.
Each session featured an interactive Q&A segment, enabling consumers and participants to engage directly with panelists, voice concerns, share experiences, and contribute to shaping the regulatory landscape. Discussions revolved around issues such as long waiting times for CNG consumers, addressing LPG consumer complaints, and enhancing consumer awareness about their rights.
In closing, Board Members stressed the necessity of ongoing stakeholder engagement to ensure that consumer perspectives influence the future trajectory of India’s natural gas sector.
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Govt makes use of major wind turbine components from RLMM mandatory
The government mandates using major wind turbine components from the Approved List of Models and Manufacturers (Wind), renamed from RLMM, to ensure quality and energy security. This amendment strengthens cybersecurity by requiring data centers within India. Exemptions are provided for existing projects and new manufacturers to promote innovation and domestic manufacturing in the wind sector.
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New Delhi, The government has made the use of major wind turbine components from the Approved List of Models and Manufacturers (Wind) mandatory, an official statement said on Thursday.The Ministry of New & Renewable Energy (MNRE) had earlier issued ‘Procedure to apply for inclusion of a Wind Turbine Model in the Revised List of Models and Manufacturers of Wind Turbines (RLMM).The RLMM was a mechanism to ensure the quality and reliability of wind turbines installed in the country, for protecting the consumer interests while ensuring larger energy security.The ministry said RLMM has been renamed as Approved List of Models and Manufacturers (Wind) — ALMM (Wind) — through an amendment.
“Further, it is now mandatory for the use of major wind turbine components, such as blade, tower, gearbox, generator and special bearings (Main, Pitch and Yaw Bearing) from the ALMM (wind turbine components) in the manufacturing of listed wind turbines,” MNRE said.
The ALMM (Wind Turbine Components) list will be issued by the ministry separately.
The amendment also includes mandatorily locating Wind Turbine R&D Centre, Data Centre and/or Servers within India to strengthen the cybersecurity ecosystem.
This amendment will not be applicable to the already bid wind projects and captive/open access/C&I (commercial and industrial)/third party sale projects to be commissioned within 18 months from the date of issuance of the amendment.In addition, new wind turbine manufacturers and/or new wind turbine models will be exempted from mandatory use of components listed in ALMM (wind turbine components) for a total capacity of 800 MW for a period of two years to promote the new technologies, having new innovation and performance efficiency not available indigenously.
This step will boost the existing quality control mechanism, including the cybersecurity aspects, along with boosting domestic manufacturing in the wind sector.
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India becomes 3rd largest solar energy generator: Minister Pralhad Joshi
New Delhi: India has outpaced Japan to become the third largest country to generate solar energy, Union Minister Pralhad Joshi said on Thursday. India has produced 1,08,494 GWh solar power compared to 96,459 GWh generated by Japan, the minister for new and renewable energy said citing data of International Renewable Energy Agency (IRENA).
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IRENA is a global agency for energy transformation that serves as a platform for international cooperation, supports countries in their energy transitions, and provides data and analyses on technology, innovation, policy, finance and investment.
India has outpaced Japan in solar energy generation producing 1,08,494 GWh compared to Japan’s 96,459 GWh and is now the world’s third-largest solar power producer, Joshi said in a post on X.
“Thanks to the visionary leadership of PM @narendramodi ji, India is leading the way in the global clean energy revolution,” the minister said.
The development assumes significance as India is working with a multi-dimensional approach to meet its ambitious target of 500 GW non-fossil fuel based electricity capacity by 2030. PTI
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Govt revokes uniform tariff mechanism for renewable energy projects, dissolves pricing pools
The power ministry on Wednesday said it has done away with a uniform tariff mechanism and dissolved central pricing pools for renewable energy purchase pacts amid concerns over uncertainty on power tariffs. The move is expected to ease price discovery between renewable energyproducers and users as well as deployment of renewable capacity in the country.In view of the substantial renewable energy capacity awaiting power sales agreement (PSA) signing and to expedite the deployment of RE, it has been decided to withdraw the order regarding the implementation of the Uniform Renewable Energy Tariff (URET) mechanism, the ministry said in a statement.Consequently, the Solar Power Central Pool and Solar-Wind Hybrid Central Pool shall stand dissolved, it said.
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Earlier, the ministry had ordered implementation of URET from February 15, 2024 for three years up to February 14, 2027.
The URET mechanism and the associated central pools were notified to address the potential impact on procurers in the context of declining bid-discovered prices.
However, Renewable Energy Implementing Agencies (RELAs) and RE developers have expressed concerns over procurers reluctance towards signing PSAs (power sale agreements) under URET on account of uncertainty of tariffs over a three-year period, the ministry said in its latest order.
A number of renewable energy projects have been stalled in the absence of advanced power purchase pacts which are required to fund these projects.
The ministry, however, said that the the bids received and letters of award issued under URET so far shall remain valid on a standalone basis and may beconsidered for the signing of power purchase agreements.
The REIAs may proceed to execute the PSAs/PPAs with the procurers/developers for these bids, it said.
India aims to have 500 GW of renewable energy by 2030. The country has 185 GW of renewable energy installed capacity as of June 30, 2025, which exclude around 50 GW of large hydro energy projects.
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Govt approves Rs 30,000-crore compensation to oil marketing companies for their losses on cooking gas sales
The Union Cabinet also approved the continuation of cooking gas subsidy for poor households under the Pradhan Mantri Ujjwala Yojana (PMUY) for 2025-26 at an expenditure of Rs 12,000 crore. The Union Cabinet on Friday approved a budgetary support of Rs 30,000 crore to public sector oil marketing companies (OMCs) to cover their losses on sale of cooking gas cylinders below market price in consumer interest.
The Cabinet also approved the continuation of targeted cooking gas subsidy for poor households under the Pradhan Mantri Ujjwala Yojana (PMUY) for 2025-26 at an expenditure of Rs 12,000 crore. Beneficiary households will continue to receive subsidy of Rs 300 per 14.2-kg cooking gas cylinder for up to nine refills per year.
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The distribution of the Rs 30,000-crore compensation among the three OMCs will be done by the Ministry of Petroleum and Natural Gas, and they will be paid in 12 tranches, the government said in a release.
The compensation to give relief to the OMCs—Indian Oil Corporation (IOC), Bharat Petroleum Corporation (BPCL), and Hindustan Petroleum Corporation (HPCL)—was in the works for a few months. It was expected to be from the additional mop-up from the hike in excise duty on petrol and diesel that took effect in April.
In July, The Indian Express had reported that the proposal was expected to be considered soon by the Union Cabinet.
“The international prices of LPG remained at high levels during 2024-25 and continue to remain high. However, to insulate consumers from fluctuations in international LPG prices, the increase in cost was not passed on to consumers of domestic LPG which led to significant losses for the three OMCs. Despite the losses, the Public Sector Oil Marketing Companies have ensured continuous supplies of domestic LPG in the country at affordable prices,” the official release said.
It added that this step also underlines the government’s commitment to protect consumers from volatility in global energy markets while maintaining the financial health of the OMCs.
It is estimated that the three OMCs incurred a cumulative loss of over Rs 41,000 crore on liquefied petroleum gas (LPG, or cooking gas) sales in 2024-25 (FY25) as they have been selling the household cooking fuel way below international prices. In April, Petroleum Secretary Pankaj Jain had said that he was hopeful that the OMCs will be compensated for their accumulated losses on LPG sales over a year or so through an appropriate mechanism by the government. Sources indicated that the Petroleum Ministry had sought support from the Finance Ministry to cover these losses. Support was also sought before the Budget for FY26, but no relief was provided at the time.
Annual petrol and diesel sales in the country stand at around 16,000 crore litres, which means that the Rs 2-per-litre increase in excise duty announced in April should lead to an additional revenue of around Rs 32,000 crore for the government on an annualised basis. The Petroleum Ministry and the OMCs expected this incremental revenue to flow back into the OMCs as government support to cover losses on LPG sales. Notably, in October 2022, the government had approved a one-time grant of Rs 22,000 crore for OMCs to partially cover their accumulated losses of around Rs 28,000 crore at the time from selling LPG at a loss in consumer interest.
According to the Petroleum Ministry’s estimates, the average Saudi CP—the international benchmark for LPG pricing—had shot up to to $629 per tonne in February 2025 from $385 in July 2023. This should have ideally translated into cooking gas being retailed at Rs 1,028.50 per 14.2-kg cylinder in Delhi. But at the time, it was being sold at Rs 803. As India depends on imports to meet a bulk of its LPG demand, cooking gas prices are linked to international LPG price benchmarks. In April, along with hike in excise duty on petrol and diesel, LPG prices were hiked by Rs 50 per cylinder, to provide some relief to the OMCs on cooking gas sales.
“This compensation will allow the OMCs to continue meeting their critical requirements such as crude and LPG procurement, servicing of debt, and sustaining their capital expenditure, thereby ensuring uninterrupted supply of LPG cylinders to households across the country,” the government said.
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LNG Use / LNG Development and Shipping
HPCL Signs Decade-long LNG Deal With Abu Dhabi’s ALNG
LNG to be delivered to Gujarat’s Chhara terminal, aiding HPCL’s energy transition and strengthening India–UAE ties. Hindustan Petroleum Corporation (HPCL) has signed a Heads of Agreement (HOA) with Abu Dhabi Gas Liquefaction Company (ALNG) for the long-term supply of Liquefied Natural Gas (LNG) over a 10-year period. ALNG, a subsidiary of ADNOC Gas, is a major integrated player across the global gas value chain.
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According to a regulatory filing by HPCL, the LNG will be delivered to the newly commissioned Chhara LNG Terminal in Gujarat. The supply is intended to support HPCL’s refineries, City Gas Distribution (CGD) network, and downstream customers, reinforcing the company’s commitment to clean energy transition.
“This agreement underscores the deepening economic relationship between India and the UAE,” the company noted, adding that the deal also marks a significant step towards improving India’s energy security.
The Chhara terminal will play a crucial role as a gateway for these imports, expanding HPCL’s LNG footprint in the domestic market and aligning with national objectives for cleaner fuel adoption.
The partnership is also a testament to India’s strategy of securing stable and long-term energy supplies as it navigates a broader transition away from carbon-intensive fuels.
The company secretary, Rakesh Kumar Singh, confirmed the development in an official communication to the stock exchanges, calling it a “significant milestone in HPCL’s clean energy journey.”
https://www.businessworld.in/article/hpcl-signs-decade-long-lng-deal-with-abu-dhabis-alng-565911
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India sources more LNG from UAE in pus for green energy
New Delhi: India has sourced more liquefied natural gas (LNG) from the United Arab Emirates with public sector oil giant Hindustan Petroleum Corporation Limited (HPCL), signing a 10-year supply agreement with state-owned ADNOC Gas as part of the deepening energy partnership between the two countries.
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Under the terms of the agreement, ADNOC Gas will supply 500,000 metric tonnes per annum (mtpa) of LNG to HPCL, starting in 2026. The LNG will be sourced from ADNOC Gas’ Das Island liquefaction facility, which has a production capacity of 6 mtpa and is one of the world’s longest-operating LNG plants, having shipped over 3,500 cargoes globally since its inception in 1977.
HPCL will receive LNG at the recently commissioned Chhara LNG Terminal, Gujarat, to meet the demand of its refineries, City Gas Distribution Network and for marketing to downstream customers. This initiative further enables HPCL to build a diverse portfolio encompassing long and short-term LNG contracts, and also to secure LNG and meet the growing energy demand in the Indian market. This agreement marks ADNOC Gas’ third LNG supply deal with an Indian energy company in the past 12 months, following contracts with Indian Oil Corporation (IOCL) and GAIL India. The IOCL deal, a 14-year Advt 8/9/25, 8:26 AM India Secures Long-term LNG Supply from UAE in Green Energy Initiative, ETEnergyworld https://energy.economictimes.indiatimes.com/news/oil-and-gas/india-secures-long-term-lng-supply-from-uae-in-green-energy-initiative/123184276 2/11 agreement valued between $7 billion and $9 billion, commits ADNOC Gas to supplying up to 1.2 mtpa of LNG, while the GAIL agreement involves 0.52 mtpa over 10 years, also starting in 2026.
Apart from economics, the UAE-India energy partnership reflects a geopolitical statement. The UAE has emerged as a reliable energy partner for India, particularly as global LNG competition intensifies following disruptions like the Russia-Ukraine conflict. India’s growing energy ties with the UAE provide a counterbalance to its reliance on other suppliers and help navigate challenges like potential US tariffs on Indian goods due to its oil imports from Russia. India, the world’s fourth-largest LNG importer, is aiming to increase the share of natural gas in its primary energy mix from 6.2 per cent to 15 per cent by 2030, driven by industrial expansion, oil refining, and the need for cleaner energy alternatives to coal.
The country’s natural gas consumption is projected to triple by 2050, fuelled by growth in sectors like fertilisers, steelmaking, and construction. However, domestic production cannot keep pace with this rising demand, making long-term import agreements like the one with ADNOC Gas critical for energy security. The deal with HPCL aligns with India’s broader energy strategy under Prime Minister Narendra Modi, who has emphasised diversifying away from coal to reduce carbon emissions. Additionally, the UAE-India Comprehensive Economic Partnership Agreement (CEPA), signed in 2022, facilitates such deals by eliminating a 2.5 per cent import tax on LNG, making UAE gas more competitive in the Indian market. Non-oil trade between the two nations reached $50.5 billion in the first year after CEPA’s implementation, with ambitions to hit $100 billion by 2030. For ADNOC Gas, this agreement is part of a broader strategy to capture a larger share of the global LNG market, which is expected to grow by 15 per cent over the next decade, driven by demand in Asia. The company, a subsidiary of the Abu Dhabi National Oil Company (ADNOC), supplies approximately 60 per cent of the UAE’s domestic gas needs and serves
The deal comes at a time when ADNOC is expanding its international presence, including in the US, where it has acquired stakes in LNG and green energy projects. This global push, coupled with domestic investments like the $13 billion planned for LNG capacity expansion by 2029, underscores ADNOC’s ambition to be a major player in the energy transition.
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Electric Mobility/ Hydrogen/Bio-Methane
First ‘Make in India’ 1MW green hydrogen plant commissioned at Kandla
Rajkot: Deendayal Port Authority (DPA) on Thursday commissioned the country’s first ‘Make in India’ one megawatt (MW) green hydrogen plant, at Kandla. This is the first phase of a planned 10MW facility and is the first such development at an Indian port. Union shipping minister Sarbananda Sonowal inaugurated the plant, calling it a “new benchmark” in the execution of green hydrogenprojects. “DPA has demonstrated a shining example of speed, scale and skill,” he said.
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The plant was set up in four months and is fully indigenous. The electrolyzer used to produce the hydrogen is made in India, and the entire project was led by Indian engineers. The green hydrogen generated will initially power 11 buses and street lighting within the port. Over time, DPA aims to use it to fuel all the resources of the port.
DPA chairman S K Singh told TOI, “Another 5MW will be added by the end of this fiscal year, with the full 10MW facility expected to be operational by the middle of the next fiscal year.”
“DPA becomes the first port in India to operationalize a Make-In-India green hydrogen facility of this scale, capable of producing approximately 140 metric tonnes of green hydrogen annually. This breakthrough marks a pivotal step in maritime decarbonization, enhancing India’s global leadership in sustainable port operations,” DPA said in a statement. Green hydrogen has many applications such asfuel for power plants, vehicles, tugs and vessels.
The foundation stone for the plant was laid by Prime Minister Narendra Modi on May 26 during his visit to Bhuj.
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NTPC Green Energy Ltd inks pact for setting up battery storage projects in Bihar
Government-owned NTPC Green Energy Ltd has inked an MoU with Bihar State Power Generation Company Limited (BSPGCL) to set up renewable energy and battery energy storage projects (BESS) in the state as part of the Centre’s policy to reduce the carbon footprint in the country.Government-owned NTPC Green Energy Ltd has inked an MoU with Bihar State Power Generation Company Limited (BSPGCL) to set up renewable energy and battery energy storage projects (BESS) in the state as part of the Centre’s policy to reduce the carbon footprint in the country.
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The agreement was signed between Sarit Maheswari, CEO (NGEL), and Abdesh Kumar Singh, Director Technical (BSPGCL), in the presence of Minister of Energy, Planning and Development, Bihar, Bijendra Prasad Yadav and other senior officials from the state government.The MoU comes close on the heels of NTPC Green Energy Ltd winning a 1,000 MW capacity solar PV power project auction of Uttar Pradesh Power Corporation Limited last month. The company signed a Power Purchase Agreement (PPA) at a discovered tariff of Rs 2.56 per kWh.
The Cabinet Committee on Economic Affairs, earlier this month, enhanced the financial powers of NTPC Limited from Rs 7,500 crore to Rs 20,000 crore for Renewable Energy capacity addition.
As India’s leading power utility, NTPC aims to add 60 GW of Renewable Energy Capacity by 2032, which will help the country move towards its larger aim of having ‘Net Zero’ emissions by 2070.
The enhanced financial powers given to NTPC and NGEL will facilitate the accelerated development of renewable projects in the country. This move will also play a vital role in strengthening power infrastructure and ensuring investment in providing reliable, round-the-clock electricity access across the nation, according to an official statement.
Renewable Energy projects will also generate direct and indirect employment opportunities for the local people at the construction stage, as well as during the Operations and Maintenance Stage. This shall provide a boost to local suppliers, local enterprises/ MSMEs and shall encourage the entrepreneurship opportunities within the country, besides promoting employment and socio-economic development of the country, the statement said.
India has achieved a landmark in its energy transition journey by reaching 50 per cent of its installed electricity capacity from non-fossil fuel sources – five years ahead of the target set under its Nationally Determined Contributions to the Paris Agreement. The country is aiming to reach 500 GW of non-fossil energy capacity by 2030.
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Gujarat Gas & Waaree Energy sign deal in boost for India’s lithium-ion battery drive
Gujarat Gas Limited (GGL) signed a gas sales agreement with Waaree Energy to supply 50,000 scmd of piped natural cas (PNG) for its upcoming lithium-ion cell manufacturing unit in Valsad, Gujarat. India currently imports the bulk of its lithium-ion batteries, but as per CareEdge, this reliance is projected to drop to 20% by FY26-27. Gujarat Gas Limited (GGL) has signed a gas sales agreement with Waaree Energy on Thursday (July 31) to supply 50,000 scmd of piped natural cas (PNG) for its upcoming lithium-ion cell manufacturing unit in Valsad, Gujarat.
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The plant is expected to be commissioned in Q4 of FY25-26 and represents a key stride toward sustainable energy adoption and a reduced carbon footprint.
India currently imports the bulk of its lithium-ion batteries, but as per CareEdge, this reliance is projected to drop to 20% by FY26-27.
The cells are vital components in electric vehicles, portable electronics, and battery energy storage systems (BESS), a sector playing a pivotal role in grid stability and renewable energy integration.
The partnership is positioned to significantly boost India’s clean energy ecosystem. Waaree Energies Ltd, the country’s largest solar PV module manufacturer with 13.3 GW installed capacity (CRISIL report), is diversifying into lithium-ion, hydrogen cells, and solar wafer production.
GGL is India’s top city gas distribution firm, supplying fuel to over 22.67 lakh households, 4,000+ industries, and managing 828+ CNG stations across seven regions.
Waaree Energies Q1 results
Waaree Energies delivered a robust April–June quarter, posting a 20.3% jump in consolidated net profit to ₹745 crore, up from ₹619 crore in Q4FY25. Operational efficiency and cost control drove a sharp rise in EBITDA to ₹997 crore — a 73.4% increase quarter-on-quarter, boosting the EBITDA margin to 22.5% from 14.3%.
The company’s revenue also climbed 10.5% sequentially to ₹4,425 crore, reflecting improved realisations and strengthening business momentum.
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VOC Port becomes the first Indian port to produce green hydrogen and surpass 1 MW solar power
- O. Chidambaranar (VOC) Port in Thoothukudi has become the first Indian port to successfully produce green hydrogen and achieve over 1 MW of rooftop power generation, said Susanta Kumar Purohit, IRSEE, Chairperson of VOC Port, while addressing the media here on Friday.
The media briefing was a part of the one-day conference on Green Ports and Shipping-Chartering Sustainable Maritime Future, organised under NAVIC Cell-3 (Green Initiatives and Pollution Control) under the Ministry of Ports, Shipping and Waterways.The conference was organised as a part of a nationwide series of thematic workshops and roadshows being conducted ahead of the India Maritime Week 2025, to be held in October in Mumbai. The event has been planned to showcase India’s maritime excellence, policy direction and innovation.
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- O. Chidambaranar (VOC) Port in Thoothukudi has become the first Indian port to successfully produce green hydrogen and achieve over 1 MW of rooftop power generation, said Susanta Kumar Purohit, IRSEE, Chairperson of VOC Port, while addressing the media here on Friday.
The media briefing was a part of the one-day conference on Green Ports and Shipping-Chartering Sustainable Maritime Future, organised under NAVIC Cell-3 (Green Initiatives and Pollution Control) under the Ministry of Ports, Shipping and Waterways.
The conference was organised as a part of a nationwide series of thematic workshops and roadshows being conducted ahead of the India Maritime Week 2025, to be held in October in Mumbai. The event has been planned to showcase India’s maritime excellence, policy direction and innovation.
Addressing the media, Mr. Purohit said that the primary objective of the conference fosters a unified and actionable dialogue to drive India’s ports and shipping industry towards net zero emissions. He added that the NAVIC Cell-3 has already begun substantial results, with several major ports including VOC Port Authority transitioning their internal system to energy-energy efficient alternatives.
“We are also in the process of establishing a 750 cubic metre green methanol pilot bunkering facility and initiated a 25 tonnes per day municipal solid waste based on green methanol production project,” said Mr. Purohit.
The conference featured two sessions focusing on topics Decarbonisation in the Maritime Sector and Green Financing and Policy Frameworks. The inaugural session of the conference included a keynote address by Vijay Kumar, Chairman, Inland Waterways Authority of India.
During his address, Mr. Vijay Kumar emphasised the need for sustainability in India’s maritime sector. He further added that to realise India’s 2070 net-zero emission target required coordinated efforts. The NAVIC Cell of the ministry was coordinating various efforts to create environmentally friendly inland waterways across India comprehensively. He also noted that the department was working on multiple fronts, including transitioning towards renewable energy, adopting energy-efficient equipment, promoting green fuels such as LNG, ammonia, hydrogen and upgrading ports equipment.
Dignitaries including Abhay Bakre, IRSEE, Mission Director NGHM, Vibha Dhawan, Director General, TERI, Malini Shankar, Vice Chancellor, IMU, Rajesh Soundararajan, Deputy Chairperson, VOC Port Authority and other officials were present at the conference.
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Goa drafts policy to promote bioenergy, reduce fossil fuel dependence
Panaji: The draft Goa bioenergy policy focuses on adopting biofuels and bioenergy products across the state, reducing emissions caused by fossil fuels, and, in turn, becoming a leader in bioenergy and biofuel production. This contributes to national energy security goals.
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The policy intends to cover all aspects related to bioenergy, including biofuel production, distribution, utilisation of technologies in the sector, and the availability of resources to produce bioenergy-related products.
The objective of the policy is to promote the adoption of bioenergy products in Goa, to reduce dependence on fossil fuel consumption and increase the use of biofuel as alternatives. It aims to encourage the sustainable use of agricultural residues, cooking oil, non-food biomass, and municipal solid waste for bioenergy production. The policy also focuses on developing an integrated supply chain and infrastructure to collect, store, and transport these as raw materials for bioenergy production. It seeks to develop clusters across the state in a decentralised manner, involving communities and panchayats in the adoption of bioenergy in the state.
Additionally, it aims to develop an aggregator model that creates a supply chain for the sale and purchase of bioenergy products and their raw materials.
Through the policy, govt intends to provide opportunities in skilling, employment, and entrepreneurship, support research, development, and innovation in biofuel technology, and set up a biomass digital market through the GEDA for the aggregation of biomass, transport of biomass, and other biomass-related activities.
Under the policy, govt will provide incentives for biofuel manufacturing units and biomass supply chain units. Biomass briquette/pellet manufacturing plants, biomass-based steam generation plants, biomass supply chain companies, and the conversion of existing sewage treatment plants are eligible under the scheme. Existing plants may expand or diversify, but they are eligible for incentives only for the additional capacity being added through the scheme.
A senior govt officer said that Goa is developing into a state that is seeing increasing interest from various corporations to set up their offices and facilities. Apart from this, Goa has been the go-to destination for tourism in the country. All these aspects indicate an increase in energy consumption and waste generation, which needs to be addressed. Goa also has very high emissions through transportation, which need to be addressed through adopting various biofuels and bioenergy technologies.
“The state acknowledges the pivotal role of biofuels in enhancing energy security by reducing dependence on imported fuels, lowering greenhouse gas emissions, and fostering employment opportunities in rural areas. This scheme presents a holistic framework aimed at establishing a resilient and sustainable biofuel ecosystem within the state,” the officer said.
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1st-ever green hydrogen ferry all set for Varanasi ‘voyage’
KOCHI: The ‘future fuel’ is here! The first-ever green hydrogen ferry in the country, built by the Cochin Shipyard Ltd, has received the Indian Register of Shipping (IRS) approval, paving the way for the deployment of the 50-passenger capacity vessel that boasts of zero pollution, in Varanasi in Uttar Pradesh. It has completed the six-month trial runs in Varanasi.
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The news is significant as the Kochi Water Metro, which currently uses electric-hybrid passenger ferries manufactured by the CSL, has ambitious plans to shift to the zero-emission green hydrogen fuel in future.
“The shift to green hydrogen vessels is now under active consideration and discussions are progressing with the Cochin Shipyard. While we decided against hydrogen ferries initially due to their huge operating cost and difficulty in sourcing, discussions have now been revived, with ANERT (Agency for New and Renewable Energy Research and Technology) extending a subsidy scheme as well,” said a source with Kochi Metro Rail Ltd.
When the green hydrogen proposal was first made two years ago, the cost of the ‘future fuel’, considered a potential replacement for fossil-based ones, was `960/kg. Industry sources said this has now more than halved. “Reliance has commissioned a pilot hydrogen refuelling station (HRS) in Jamnagar. The cost of hydrogen comes to Rs 360/kg,” a source said.
Another positive development is the availability of hydrogen fuel in Kochi, as a green hydrogen plant and fuelling station, the first in south India, is coming up near Kochi airport at Nedumbassery. It is jointly developed by Bharat Petroleum Corporation Ltd (BPCL) and Cochin International Airport Ltd (CIAL). While BPCL is entrusted with the building and operation of the 1,000-kW plant, CIAL contributes land, water and green energy resources. The plant will have a capacity to produce 80 kg of green hydrogen daily.
Water, heat by-products
With the indigenous vessel receiving IRS clearance, it is set to start operations in the Kashi-Prayagraj section. The ferry, utilising a hydrogen fuel cell powered battery system, runs on Low-Temperature Proton Exchange Membrane Technology (LT-PEM).
“By implementing the technology, the only by-products will be water and heat. The vessel can operate at a speed of 6.5 knots. Its operation is silent and, since there are no moving parts, maintenance requirement is low. The use of hydrogen as a fuel source eliminates greenhouse gas emissions, making the vessel a model for green and sustainable maritime transportation,” a CSL official said.
The vessel has five hydrogen cylinders carrying 40 kg of hydrogen, supporting eight hours of operation. Prime Minister Narendra Modi had flagged it off on February 28, 2024. “The hydrogen boat has the same design as that of the water metro ferries. We lowered the battery capacity and installed a hydrogen fuel cell to generate electricity,” the official added.
CSL is also constructing two Sea Shuttle Feeder Container Vessels running on green hydrogen. In zero emission mode, each vessel is expected to achieve around 25,000 tons of CO2 reduction per year.
50-passenger capacity
The 50-passenger capacity vessel is set to start operations in the Kashi-Prayagraj section
Utilising a hydrogen fuel cell powered battery system, it runs on Low-Temperature Proton Exchange Membrane Technology (LT-PEM)
The vessel has five hydrogen cylinders carrying 40 kg of hydrogen, supporting eight hours of operation
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After 1-year hiatus, GMDA revives plan for Gurgaon’s first bio-CNG facility
Gurgaon: GMDA has renewed efforts to construct the city’s first compressed biogas (CBG) plant. The move is part of a major sewage infrastructure upgrade at Dhanwapur more than a year after GMDA’s initial tendering attempt failed to secure a competent agency for the project. The Rs 166-crore project includes the construction of a 100 million litres per day (MLD) sewage treatment plant (STP) based on sequencing batch reactor (SBR) technology, a 100 MLD main pumping station (MPS), and an integrated CBG unit.
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GMDA has already floated a fresh tender for the project and if the authority has its way, the facility is expected to be ready by the month of Dec in 2027.
The broader strategy is to prevent untreated sewage discharge into the Najafgarh drain.
The authority floated the tender in Feb last year, but after 13 extensions and no eligible bidders despite participation from eight agencies, the authority finally cancelled the process in Dec 2024.
The plan is now back on track with GMDA officials pushing for timely implementation.
Officials said the earlier plan included a 200 MLD MPS, but the scope was revised after 100 MLD capacity was separately accommodated under the ongoing augmentation of the MPS in Sector 9A.
“The revised scope has now been floated for bidding. We aim to complete the project by Dec 2027,” a senior GMDA official said.
The new facility will increase the capacity of the Dhanwapur STP from 218 MLD to 318 MLD, addressing the growing sewage load from sectors 1–23, 33–37 and nearby villages such as Dundahera, Mullahera and Carterpuri.
Currently, the plant is running near capacity, treating about 215 MLD of sewage daily.
The advanced SBR-based plant will ensure high-quality treated water, compliant with National Green Tribunal (NGT) norms.
The treated water will be reused for horticulture and other non-potable purposes, contributing to environmental sustainability.
Additionally, the integrated CBG plant will convert bio-sludge into renewable fuel, with the capacity to generate up to 5,000 cubic metres of biogas per day.
This gas can be supplied to city gas distribution networks, promoting a circular waste-to-energy model, the official added.
The new 100 MLD STP plant at Dhanwapur, once operational, will also treat sewage from new sectors, including 81 to 104, helping reduce pollution in the drainage network and downstream water bodies.
“This project integrates modern sewage treatment with clean energy generation and is part of GMDA’s push for sustainable urban infrastructure,” the official added.
In addition to this expansion, GMDA is also upgrading the existing 100 MLD STP at Dhanwapur into a tertiary treatment plant to ensure compliance with wastewater discharge norms.
The govt approved this upgrade in July last year and the work was allotted to the agency in July last month.
The Rs 51.3 crore project will take at least two years to complete.
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India Builds First Ships Powered By Indigenous Green Hydrogen Technology
India has embarked on a landmark project to construct its first indigenous green hydrogen-powered ships, marking a decisive step towards a cleaner and more sustainable maritime future. The initiative, being implemented at two of the nation’s leading shipyards, aims to showcase the potential of hydrogen fuel in reducing pollution across busy sea routes.
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According to senior officials, each ship will be powered entirely by hydrogen fuel cells developed using indigenous technology. The move comes as part of the country’s broader ambition to transition away from fossil fuels in the shipping sector, one of the most significant contributors to marine pollution.
The government has allocated ₹115 crore under the National Green Hydrogen Mission for the current phase of the project, which runs until 2025–26. These funds will be directed towards vessel design, technology trials, port infrastructure upgrades, and pilot deployments. The plan is structured in two phases — the first focusing on retrofitting existing vessels to run on hydrogen, and the second on developing full-fledged hydrogen refuelling facilities at key ports. In line with this vision, major ports such as Deendayal, Paradip, and Tuticorin are being prepared as hydrogen hubs. One of these ports has already advanced plans for a 750-cubic-metre green methanol bunkering facility, laying the groundwork for future production and export capabilities. Officials emphasise that developing such hubs will not only meet domestic demand but also position India as a supplier in the emerging global hydrogen market.
Experts in the maritime sector believe that these pioneering vessels will significantly reduce greenhouse gas emissions and set a precedent for the region. By adopting indigenous hydrogen technology, the project also aims to build local expertise, cut import reliance, and generate high-value jobs in engineering and shipbuilding. Authorities highlight that the maritime shift to green hydrogen is central to meeting India’s climate commitments. Shipping accounts for a notable share of carbon emissions, and fuel innovations are vital to align with net zero goals. The green hydrogen approach offers a double advantage — its only by-product during operation is water, and it can be generated from renewable energy sources such as solar and wind.
Industry insiders note that while the transition will require sustained investment and rigorous safety standards, the long-term payoff in environmental benefits and energy independence is substantial. They stress that successful execution of these pilot ships could pave the way for larger fleets and potentially inspire similar moves in neighbouring countries. The project is being closely monitored as a benchmark for India’s technological readiness in the clean fuel space. If successful, it could anchor the country’s reputation as a leader in sustainable maritime innovation, setting the stage for greener trade corridors in the years ahead.
https://urbanacres.in/india-builds-first-ships-powered-by-indigenous-green/
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Rs 8,146 crore green energy project cleared for Arunachal’s Shi Yomi district
A major push for renewable power generation is set to take shape in Arunachal Pradesh, with the Cabinet Committee on Economic Affairs approving an investment of Rs 8,146.21 crore for the 700 MW Tato-II Hydro Electric Project in Shi Yomi district. A major push for renewable power generation is set to take shape in Arunachal Pradesh, with the Cabinet Committee on Economic Affairs approving an investment of Rs 8,146.21 crore for the 700 MW Tato-II Hydro Electric Project in Shi Yomi district.
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The decision, taken under the chairmanship of Prime Minister Narendra Modi, marks one of the largest recent hydropower investments in the Northeast.
The project, to be executed as a joint venture between North Eastern Electric Power Corporation Ltd. (NEEPCO) and the Arunachal Pradesh government, is expected to be completed in 72 months. Once operational, it will generate over 2,738 million units of electricity annually, strengthening the state’s energy supply and contributing to national grid stability.
Arunachal Pradesh will receive 12 per cent of the power free of cost, along with an additional 1 per cent earmarked for the Local Area Development Fund.
Officials said the project will not only advance the Aatmanirbhar Bharat agenda but also drive job creation, enhance local infrastructure, and improve social services. Planned development includes nearly 33 km of new roads, bridges, and upgrades to hospitals and schools in the region.
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GNIDA invites bids for second biogas plant at Pauvari Gaushala
Noida: The Greater Noida Industrial Development Authority (GNIDA) has issued a request for proposals to set up a second biogas plant, this time at the Pauvari Gaushala. The move comes just a week after the foundation was laid for a similar facility at the Jalpura village cowshed, reports The Times of India.
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The proposed plant will process 50 tonnes per day of cow dung and will be built under a public-private partnership (PPP) model within 12 months. The estimated cost of the project is Rs 17 crore.
Once operational, the plant will produce compressed natural gas (CNG) that can be used to fuel vehicles and kitchens. Using anaerobic digestion, the facility will convert cow dung into eco-friendly fuel, generating revenue for the upkeep of the cowshed while also improving waste management.
An official said the selected agency will be responsible for building the bio-CNG project using cow dung and other biodegradable waste. “The bidder can choose the technology, but it must be based on bio-methanation and produce CNG that meets the latest standards for vehicle fuel, especially for city buses,” the official said. Any future upgrades will also be the contractor’s responsibility.
GNIDA clarified that it will not guarantee a daily supply of 50 tonnes of cow dung. In case of shortfalls, the contractor will be allowed to use alternatives such as agricultural residue, agro-industrial waste, or horticultural waste to run the plant at full capacity.
For the project, GNIDA will lease 2 to 4 acres of land at a nominal rent of Rs 1 per square metre.
https://bioenergytimes.com/gnida-invites-bids-for-second-biogas-plant-at-pauvari-gaushala/
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INTERNATIONAL NEWS
Natural Gas / Transnational Pipelines/ Others
Oman : Oman’s Integrated Gas Company Approves $273 Million Gas Pipeline
(Reuters) — Oman’s state-owned Integrated Gas Company approved a new gas pipeline worth 105 million Omani riyals ($272.73 million), state news agency ONA said on Aug. 2. The pipeline will contribute to a 4.5% increase in the national gas network’s length, ONA said. The pipeline will extend from the city of Ibri to Sohar, with an additional connection serving Ibri’s industrial area.
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MORe – https://pgjonline.com/news/2025/august/oman-s-integrated-gas-company-approves-273-million-gas-pipeline
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Russia: Russian pipeline gas exports to Europe rose 37% m/m in July, data shows
MOSCOW, Aug 1 (Reuters) – Russian energy giant Gazprom’s (GAZP.MM),average daily natural gas supplies to Europe increased by 37% in July from a month earlier when maintenance work reduced them, Reuters calculations showed on Friday. Turkey and the TurkStream undersea pipeline is the only transit route left for Russian gas to Europe after Ukraine chose not to extend a five-year transit deal with Moscow when it expired on January 1.
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Calculations based on data from European gas transmission group Entsog showed that Russian gas exports via the TurkStream pipeline rose to 51.5 million cubic metres (mcm) per day in July from 37.6 mcm per day in June.
That was 4.7% more than July 2024 when they stood at 49.2 mcm.
Total Russian gas supplies to Europe via TurkStream stood at around 9.93 billion cubic metres (bcm) in the first six months of this year, compared to 9.3 bcm during the same period a year earlier, according to Reuters calculations.
Gazprom’s exports to Europe in January-July last year amounted to 18.3 bcm, a figure which included volumes transited through Ukraine.
The company, which has not published its own monthly statistics since the start of 2023, did not respond to a request for comment.
Russia supplied about 63.8 bcm of gas to Europe by various routes in 2022, Gazprom data and Reuters calculations show.
That plummeted by 55.6% to 28.3 bcm in 2024, but increased to around 32 bcm in 2024.
At their peak in 2018-2019, annual gas flows to Europe reached between 175 and 180 bcm.
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Turkey to begin supplying Azeri gas to Syria from Saturday (August 2, 2025)
Turkey will start exporting natural gas from Azerbaijan to Syria this Saturday, the energy minister announced, as Damascus said the imports would go toward electricity production. Syria’s authorities, who toppled Bashar al-Assad in December, are seeking to rebuild the country’s infrastructure and economy after almost 14 years of civil war. The conflict badly damaged Syria’s power infrastructure, leading to cuts that can last for more than 20 hours a day.
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“We will start exporting natural gas from Azerbaijan to Aleppo via Kilis”, a province in southernmost Turkey near the Syrian border, Energy Minister Alparslan Bayraktar said Wednesday.
According to Syrian state news agency SANA, Energy Minister Mohammad al-Bashir confirmed that “from August 2, Syria will begin to receive 3.4 million cubic metres of gas from Azerbaijan” via Turkey.
The gas “will allow the production of around 900 megawatts of electricity, as part of joint cooperation aiming to support the Syrian energy sector”, SANA reported.
Earlier this month, Baku said Azerbaijan would send its gas to Syria as President Ilham Aliyev hosted Damascus’s new leader Ahmed al-Sharaa.
In May, Bashir said Damascus and Ankara had reached a deal for Turkey to supply natural gas to the war-torn country via a pipeline in the north.
Gas-rich Azerbaijan is a historically of Turkey which maintains close ties with the Syrian transitional government.
https://www.newarab.com/news/turkey-begin-supplying-azeri-gas-syria-saturday
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China: CNOOC Achieves New Gas Startup in South China Sea
CNOOC Ltd. has begun production at the Dongfang 1-1 Gas Field 13-3 Block Development Project in the South China Sea, its ninth announced startup offshore China in 2025. “The project is the first high-temperature, high-pressure, low-permeability natural gas project offshore China”, CNOOC Ltd., majority owned by China National Offshore Oil Corp., said in a press release. The project is in the Yinggehai Basin, in waters with an average depth of about 67 meters (219.82 feet), the company said.
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CNOOC Ltd. expects the project to reach its capacity of around 35 million cubic feet a day next year. CNOOC Ltd., the sole owner, plans to develop six wells. The project uses existing facilities of the Dongfang gas fields and a new unmanned wellhead platform.
“The existing facilities are used to connect the Dongfang 1-1 gas field and Dongfang 13-2 gas field. CNOOC Limited has thereby successfully established an integrated offshore gas production network in the Yinggehai Basin”, the company said.
“It will facilitate the stable and reliable supply of natural gas in the region, providing strong support for the economic and social development of Guangdong, Hong Kong and Hainan”.
Just last week CNOOC Ltd. announced the startup of phase I of the Kenli 10-2 Oilfields Development Project, which it called “the largest shallow lithological oilfield offshore China”.
The project is in the Bohai Sea, part of the Yellow Sea. The project has an average water depth of approximately 20 meters, according to CNOOC Ltd.
The 100 percent owner expects the project to achieve its peak rate of 19,400 barrels of oil equivalent a day in 2026. CNOOC Ltd. plans 79 wells: 33 cold recovery wells, 24 thermal recovery wells, 21 water injection wells and one water source well.
“Kenli 10-2 Oilfield is the first lithological oilfield with proved in-place volume of 100 million tons discovered in the shallow depression zone of the Bohai Bay Basin”, the company said.
“CNOOC Ltd. has adopted an innovative combined development approach of ‘conventional water injection + steam huff and puff + steam flooding’, providing strong technical support for the efficient utilization of oil reserves”, it added. “The project’s platform integrates both conventional cold production and thermal recovery systems, and is equipped with over 240 sets of key equipment.
“It is one of the most complex production platforms in the Bohai region and the first large-scale thermal recovery platform for heavy oil in southern Bohai Sea”.
Previously in 2025 CNOOC Ltd. announced three startups in the Bohai Sea and four in the South China Sea. The Bohai Sea projects are the Caofeidian 6-4 field adjustment, phase II of the Luda 5-2 North field and the Bozhong 26-6 field. The South China Sea projects are Wenchang 19-1 field phase II, the Dongfang 29-1 field, the Panyu 11-12/10-1/10-2 Oilfield Adjustment Joint Development Project and the Weizhou 5-3 field.
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Turkey: Kilis-Aleppo natural gas pipeline opened: Gas flow from Turkey to Syria started
Turkish Minister of Energy and Natural Resources Alparslan Bayraktar called on European countries to support infrastructure projects for the return of Syrians in Europe. Turkey, Qatar, Azerbaijan and Syria are supporting a project that will provide electricity to 5 million households in Aleppo. The export of natural gas from Azerbaijan to Syria via Turkey began on Saturday with the opening of the Turkey-Syria natural gas pipeline.
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The inauguration ceremony was held in the Turkish city of Kilis only seven kilometres from the Syrian border. It was attended by Turkish Minister for Energy and Natural Resources Alparslan Bakyraktar, Qatar Development Fund President Fahad Hamad Al-Sulaiti, Syrian Energy Minister Mohammed Al-Bashir and Azberbaijani Economic Minister Mikayıl Jabbarov.
In his opening speech, Bayraktar said that the new pipeline means the electricity supply in Syria will be increased from between three and four hours a day to ten hours a day.
Electricity will now be exported from Turkey to Syria from eight different points, Bayraktar said, with the export capacity expected to increase in the coming years.
“With the new connections, the capacity will reach 860 megawatts,” he said.
Speaking to Euronews, Bayraktar said that European countries expecting Syrians to return home “need to put concrete projects in place to turn expectations into reality.”
He said that “Turkey has been an important host” to Syrians who fled their country due to war. While many of these people want to return to their home country, he said the conditions need to be provided for them to do so.
“Many countries, especially European countries, refuse our Syrian brothers and sisters and do not accept them, Turkey has been and continues to be a very important host in this sense.”
“Syria has many needs, infrastructure needs and other needs. Therefore, it is important for the European Union countries, European countries, Western countries to support, embrace and contribute to these projects that are necessary for the normalisation of life there in this sense,” he said.
The minister had previously announced that Turkey would cooperate with Azerbaijan and Qatar in natural gas exports to Syria. He said that a significant increase in energy production would help with “accelerating the return” of Syrians in Turkey.
Bayraktar also announced the signing of an agreement with Azerbaijani state-owned oil and gas company SOCAR for natural gas.
Energy cooperation
Immediately after the EU and the US lifted sanctions on Syria, it was announced in May that a $7 billion (€6.04 billion) strategic cooperation agreement was signed between Kalyon Holding and Cengiz Holding from Turkey, UCC from Qatar, Power International from the US and the Syrian Ministry of Energy.
Within the scope of the agreement, the groups intended to build natural gas cycle power plants across Syria within the next three years. A solar power plant is also expected to be built in around two years.
The consortium aims to ensure Syria’s energy supply security, environmental sustainability and regional development.
Energy supply during the civil war
Syrians have been struggling with serious energy shortages since the start of the civil war.
The years-long war paralysed more than 50 percent of the country’s electricity grid, reducing electricity generation capacity from 8,500 megawatts to 3,500 megawatts.
It is stated that the main reason for this is the serious damage to power plants in the regions of Mkharde, Aleppo and Zayzoun.
Before the civil war in 2011, Syria was producing and exporting 400 thousand barrels of oil per day. However, now it can only produce 20 thousand barrels and is dependent on imports. The natural gas sector, which was just developing in 2011, is almost non-existent today.
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Iraq’s PM launches gas power plant
Iraqi Prime Minister Mohammed S. Al-Sudani launched on Saturday the construction works for the first phase of the Second Beiji Gas Power Plant in Salah al-Din Province, with a total capacity of 1,014 megawatts. The Iraqi News Agency (INA) quoted a statement from the Media Office of the Prime Minister, in which Al-Sudani commended the efforts made to prepare for the launch of this vital project, affirming that the energy sector is a cornerstone of any comprehensive development plan. He explained that the government has allocated the necessary financial resources to develop all sectors of electricity—generation, transmission, and distribution—in order to improve energy production across all regions of the country.
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The project will be implemented by a consortium of Siemens Energy (Germany) and CSCEC (China). The contract includes the rehabilitation of six Siemens gas generation units, each with a capacity of 169 megawatts, for a total capacity of 1,014 megawatts.
It also includes the establishment of a load dispatching network consisting of seven circuits at 400 kilovolts, which will feed six lines into the national grid, as well as the construction of a new 132-kilovolt network comprising 16 lines to serve Salah al-Din Province. The first two units are scheduled to be operational within 27 months, followed by the remaining units at a rate of one unit every two months.
In April, Mohammed Al-Sudani laid the foundation stone for a giant power plant in the southern Iraqi province of Dhi Qar.
With a planned capacity of around 921 megawatts, the new power plant will run on natural gas, with the potential to eventually implement hydrogen mixing technology.
The project, which is being carried out by German-based Siemens next to the Nasiriyah Thermal Power Station, is a significant project that will raise the standard of energy supply in Iraq’s national grid.
https://www.gulftoday.ae/business/2025/08/02/iraqs-pm-launches-gas-power-plant
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Natural Gas / LNG Utilization / Bio-LNG
Chile: Natural Gas Replacing Coal on Chile Power Grid in Decarbonization Push
Natural gas is making an unexpected comeback in Chile’s power matrix as the nation phases out coal power and ramps up solar and wind generation. Chile has basically no hydrocarbons and must import natural gas. Two decades ago, Argentina’s economic crisis meant it stopped sending natural gas to Chile along the seven cross-border pipelines that traverse the Andes Mountains. In response, Chile backed away from natural gas in its power matrix and instead turned to coal.
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Now, natural gas is once again flowing across the mountains from Argentina’s Vaca Muerta Shale deposit. Meanwhile, Chile has built two LNG import terminals, one in the north that mostly serves miners, and one in the center of the country at Quintero that feeds the capital Santiago.
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Mexico: ONEOK Approves $365 Million Natural Gas Plant in Delaware Basin
(Reuters) — Midstream company ONEOK said on Aug. 5 it has made a final investment decision to build a new natural gas processing plant in the Delaware Basin, expanding its footprint in the top U.S. shale field as gas volumes surge. Over the past two years, the company has been ramping up its presence in the Permian Basin — which consists of the Delaware Basin — through strategic moves such as acquiring NGP XI Midstream Holdings’ stake in their Delaware Basin JV, purchasing a Gulf Coast NGL pipeline system and taking over Medallion Midstream and EnLink Midstream.
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“The Permian Basin continues to be a key area of strategic growth for us and we will continue to be actively engaged in assessing opportunities to expand and enhance our integrated operations within the basin,” Chief Commercial Officer Sheridan Swords said on a post-earnings call.
The new Bighorn plant will have a capacity to process 300 million cubic feet per day (MMcf/d) of natural gas and treat high-carbon dioxide gas, the company said.
The facility and associated treater are expected to cost about $365 million and begin service in mid-2027.
The plant is expected to increase ONEOK’s processing capacity in the Delaware Basin, which lies between Texas and New Mexico, to 1.1 billion cubic feet per day, from roughly 700 MMcf/d currently, Swords said.
The company on Aug. 4 reported a core profit of $1.98 billion, missing analysts’ expectations of $2.01 billion, according to data compiled by LSEG.
It also forecast 2026 adjusted core profit to be down 2% and expects mid to upper single-digit growth in EBITDA, compared with its prior forecast of 10% growth.
Shares of the company, which transports natural gas, natural gas liquids, refined products and crude oil, were down more than 5% in afternoon trading.
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Egypt agrees deal with Eni, BP for oil and gas exploration in the Mediterranean
CAIRO, July 31 (Reuters) – Egypt signed an agreement with oil giants Eni (ENI.MI), and BP (BP.L), to start exploration activities in the Mediterranean Sea, the petroleum ministry said on Thursday The agreement also includes drilling in the coming months an exploration well for natural gas in the Lake Timsah area, which lies in a basin developed along a fault extending from the Mediterranean Sea to the Gulf of Suez through the Bitter Lakes region.
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Read more -https://www.reuters.com/business/energy/egypt-agrees-deal-with-eni-bp-oil-gas-exploration-mediterranean-2025-07-31/
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German: Uniper and Tourmaline sign long-term natural gas supply agreement
German energy company Uniper and Tourmaline Oil Corp., Canada’s largest producer of natural gas, have finalized an eight-year physical gas agreement for 80,000 Metric Million British Thermal Units (MMBtu) per day beginning in November 2028. The estimated lifetime total volume of the transaction is 234 billion cubic feet (bcf) [which equals approx. 6.6 billion cubic meters (bcm)].
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Under the LNG Netback Supply Agreement, Tourmaline will deliver gas to the ANR SE trading hub in southeast Louisiana, USA. The contract is based on TTF (Dutch Title Transfer Facility) pricing, providing Tourmaline with international price exposure.
The agreement comes just a few months after Uniper signed a separate LNG sale-and-purchase agreement for up to 2.0 million tonnes per annum (MMtpa) with Woodside Energy. That transaction included LNG supply commitments for 1.0 MMtpa from Woodside’s U.S.-based Louisiana LNG production and export terminal, which is currently under development.
Carsten Poppinga, Chief Commercial Officer, Uniper SE said the innovative agreement with Tourmaline leverages Uniper’s global energy trading capabilities and expertise in LNG markets to the benefit of both parties. He said it also represents an important expansion of Uniper’s supply sourcing capacity in North America.
We are extremely pleased to close this deal with one of Canada’s most respected gas producers,” said Carsten Poppinga, CCO Uniper. “It showcases our ability to offer important international pricing exposure to a valued North America supplier and further diversifies Uniper’s LNG supply sourcing portfolio, an important aspect of our European security of supply objectives.
“This long-term supply agreement with Uniper supports the continued execution of our market diversification strategy,” added Mike Rose, Tourmaline’s President and CEO. “We’re proud to be supplying Canadian natural gas to meet rising demand in international markets and to enhance European energy security.”
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Canada: Construction costs rise at Canada’s Woodfibre LNG project
CALGARY, Aug 1 (Reuters) – Construction costs at Canada’s Woodfibre LNG project have increased, driving up capital costs for all partners involved, Canadian pipeline company Enbridge (ENB.TO),reported on Friday. The Woodfibre LNG project is a 2.1-million tonne liquefied natural gas export facility under construction near Squamish, British Columbia. The project is one of several new LNG facilities planned for Canada’s Pacific coast, and is expected to be complete in 2027.
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The project’s capital cost was initially estimated at US$5.1 billion. But Enbridge, which owns a 30% stake in the project, said Friday on a conference call that costs have recently increased due to permit delays, building code changes, a second floating hotel to accommodate workers, and challenging on-site conditions.
“Our share of the project costs have increased from US$1.5 billion to US$2.9 billion, and our partners’ proportionate share has increased similarly,” an Enbridge spokesperson said in an email.
The 70% remaining stake in the Woodfibre project is owned by Pacific Energy Corp Ltd, which is part of the Singapore-based RGE Group of companies. Woodfibre LNG did not immediately respond to a request for comment Friday.
Enbridge said Friday it is still expecting low double-digit returns from the project, relatively consistent with what it had initially expected. The company remains excited about the project and the LNG market, Enbridge’s spokesperson said.
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Argentina doubles gas liquefaction capacity with FID on second FLNG
The vessel, MKII, will be deployed off the coast of Río Negro, Argentina, by late 2028 and will operate alongside Hilli Episeyo, which is scheduled to begin operations fourth-quarter 2027. Southern Energy SA (SESA), the consortium formed by Pan American Energy Corp., YPF SA, Pampa Energía SA, Harbour Energy PLC, and Golar LNG Ltd., has confirmed final investment decision (FID) to install a second floating LNG (FLNG) plant in Argentina. The vessel, designated MKII, will be deployed off the coast of Río Negro, Argentina, by late 2028 and will operate alongside Hilli Episeyo, which is scheduled to begin operations fourth-quarter 2027.
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With both vessels online, the Argentina LNG 1 project will double its production capacity to 6 million tonnes/year (tpy), equivalent to about 27 million cu m/day of natural gas, for export.
Staggered investment structure
Total investment across floating infrastructure, logistics, operations, and support is estimated at more than $15 billion over the 20-year lifespan of the project. The first phase (2024–31) will require roughly $3.2 billion, while the second phase (2032–35) will account for an additional $2.8 billion.
Both FLNG will be operated by Southern Energy, enabling process integration, operational synergies, and optimization of LNG loading, storage, and export logistics. The consortium projects cumulative exports exceeding $20 billion between 2027 and 2035.
FLNG plants
Hilli Episeyo was converted by Golar LNG in 2017 from a hull originally built in 1975. It currently operates offshore Cameroon. It has a nominal capacity of 2.4 million tpy. It will be moored in Golfo San Matías. MKII, originally built in 2004 as an LNG carrier, is undergoing conversion at CIMC Raffles shipyard in China. It will have liquefaction capacity of 3.5 million tpy.
Both floating units will be supplied with gas from Neuquén basin—primarily from the Vaca Muerta formation—via infrastructure that will allow year-round operations. Initially, Hilli Episeyo will receive gas through the San Martín pipeline, transporting gas from Austral basin through a swap mechanism until dedicated infrastructure is completed to handle shale gas processing from the Neuquén formation.
Strategic global play
The project marks a milestone for Argentina, which is positioning itself as a structural supplier in the global LNG market amid rising international competition, supply diversification, and energy transition.The floating model offers strategic advantages over onshore liquefaction plants, including lower initial capital expenditure, faster implementation timelines, and greater operational flexibility. It also circumvents regulatory and environmental bottlenecks typically associated with land-based plants.
Regional LNG markets are consolidating, with countries like Brazil and Chile expanding import capacity and diversifying supply sources. Argentina’s ability to supply LNG to Asia and Europe strengthens its goal of monetizing surplus production from Vaca Muerta and reducing energy trade imbalances.
The project operates within a regulatory framework that, while still requiring adjustments to incentivize long-term exports, has begun to show signs of stability in contracts, transportation, and foreign currency regulations. The involvement of YPF and major international players improves the project’s overall risk profile.
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UAE: ADNOC Gas secures LNG supply deal with third Indian energy company
Dubai: ADNOC Gas has secured a 10-year deal to supply LNG to India’s Hindustan Petroleum Corporation Limited. The contract sees the UAE energy company committing to sending out 0.5 million metric tonnes annually of the liquified natural gas (LNG). This is the third supply deal for ADNOC Gas with a leading Indian energy company in the past 12 months.
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“The agreement underscores ADNOC Gas’ expanded global footprint, particularly across the high-demand Asian LNG market,” said a statement.
ADNOC Gas already supplies to Indian Oil Corporation and GAIL India, thus supporting ‘India’s energy security’.
Fatema Al Nuaimi, Chief Executive Officer of ADNOC Gas, said: “This milestone underscores ADNOC Gas’ ability to reliably meet rising global demand for LNG and support India’s ambition to increase natural gas to 15% of its primary energy mix by 2030.”
The LNG will be supplied from ADNOC Gas’ Das Island liquefaction facility, which has a current production capacity of 6 mmtpa.
“As the world’s third longest-operating LNG plant, Das Island has shipped over 3,500 LNG cargoes worldwide since starting operations,” said a statement.
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Canada: Fluor and JGC design expansion of LNG Canada plant
The LNG Canada plant has a 40-year export license and can already process up to 14 million tons per year. The joint venture formed by Fluor Corporation and JGC Corporation has been selected to upgrade the Front End Engineering and Design (FEED) project for the second phase of the LNG Canada plant, located in Kitimat, British Columbia. This phase seeks to evaluate the feasibility of expanding one of Canada’s energy facilities in North America. North America’s most important energy facility.
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Following the successful start-up of the first phase and the dispatch of the first cargo of liquefied natural gas liquefied natural gas, the consortiumThe consortium takes on a central role by assuming the initial technical design for a possible expansion of the plant. The plant, operated by LNG CanadaThe plant, operated by LNG Canada, already has an installed capacity to process up to 14 million tons per year and has a 40-year export license.
The LNG Canada plant and its role in the global marketplace
The LNG Canada plant plant benefits from an ice-free port and access to natural gas. abundant natural gas abundant natural gas, which positions it as a strategic link for export to Asian and European markets. Should Phase 2 materialize, it would expand infrastructure for storage, processing and transportation, cementing Canada as a key supplier of low-carbon energy. low-carbon energy.
The awarded contract has no disclosed value, but represents a critical technical step prior to a final investment decision by the project partners. These include Shell, Petronas, PetroChina, Mitsubishi Corporation and KOGAS, who continue to evaluate scenarios for scaling up production.
Technical commitment to the energy transition
Fluor, with more than 75 years of presence in Canada, brings its expertise in engineering and construction of complex energy projects. The award reaffirms its participation in the transition to less carbon-intensive sources through technical solutions that strengthen the liquefied natural gas value chain.
With this assignment, the Fluor-JGC JV, in addition to upgrading designs, also sustains the momentum of the first major LNG export hub. LNG export hub export hub in the country, boosting Canada’s competitiveness in the global clean energy market.
https://inspenet.com/en/noticias/fluor-and-jgc-design-expansion-of-lng-canada-plant
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US: Commonwealth LNG selects Technip Energies for US LNG project
Aug 4 (Reuters) – U.S.-based Commonwealth LNG on Monday said it has chosen France-based Technip Energies (TE.PA), to provide engineering, procurement, and construction (EPC) services for its 9.5 million tonnes per annum (mtpa) LNG facility in Cameron Parish, Louisiana. The United States is the world’s largest exporter of LNG. Based on projects under construction and those expected to receive financial approval this year, the country could triple its export capacity by 2030.
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The Cameron Parish project is expected to reach a final investment decision in the second half of 2025, with LNG production slated to begin in 2029.
Commonwealth LNG is working to build what it says will be the United States’ first integrated LNG export facility, enabling its majority shareholder, Kimmeridge, to sell gas from its Eagle Ford shale operations directly to the plant.
Last month, Reuters had reported that oil giant Saudi Aramco (2222.SE),is in talks, with Commonwealth LNG to buy liquefied natural gas from the the proposed facility, as the energy giant seeks to strengthen its position in the global market for the supercooled fuel.
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Brazil: BW LNG supports Brazil’s energy transition
BW LNG has participated in the inauguration of the Gás Natural Açu’s (GNA) II Thermoelectric Power Plant at the Port of Açu, Brazil – one of the largest LNG-to-power projects in Latin America. The ceremony was attended by President Luiz Inácio Lula da Silva, the First Lady Janja da Silva, Minister of Mines and Energy, Alexandre Silveira, and Minister of Transport, Renan Filho. This marks the second time a president has flown over the FSRU BW Magna, following President Jair Bolsonaro’s attendance at the GNA I inauguration.
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Since 1 July 2025, BW Magna has been delivering regasified LNG to support GNA II’s baseload commitment to the Brazilian power grid. Purpose-built for Latin America’s largest LNG-to-power development, BW Magna is operating under a 23-year charter with GNA. Together, GNA II and its sister project GNA I form the largest thermoelectric power complex in the region, with the combined capacity to supply more reliable energy to approximately 14 million homes.
At the ceremony, President Lula highlighted the importance of natural gas to grow the use of renewable energy around the world in a safe and secure manner.
https://www.lngindustry.com/floating-lng/04082025/bw-lng-supports-brazils-energy-transition/
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Global LNG Development
Japan: Sempra, Japan’s JERA enter into 20-year LNG supply deal
Sempra Infrastructure, a unit of U.S. energy company Sempra (SRE.N), opens new tab, will supply 1.5 million tonnes of liquefied natural gas (LNG) per year to Japan’s biggest power generator JERA in a 20-year deal, it said on Thursday. The LNG would be supplied from Sempra’s Port Arthur LNG Phase 2 development project in Texas, it added.
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The United States is the world’s largest exporter of LNG, shipping 11.9 billion cubic feet per day of the supercooled fuel in 2024, and has gained further momentum following President Donald Trump’s lifting of a moratorium on new export permits in January.
Sempra Infrastructure CEO Justin Bird said the company remains focused on advancing its Port Arthur LNG Phase 2 development project to a final investment decision.
The project has received all its key permits and is expected to include two liquefaction trains capable of producing about 13 Mtpa of LNG, the companies said in a statement.
In May, Sempra’s Port Arthur Phase 2 project in Texas had won U.S. approval to export liquefied natural gas to markets in Europe and Asia.
Trump has pushed allies like Japan, which is the world’s second-largest LNG buyer, and South Korea to buy U.S. oil and gas while threatening tariffs on their exports.
The Port Arthur LNG Phase 1 project, which is currently under construction, is expected to achieve commercial operation in 2027 and 2028 for trains 1 and 2, respectively.
U.S. liquefied natural gas producer NextDecade (NEXT.O), opens new tab had also signed a 20-year deal in late May to supply JERA with 2 million tonnes per annum of LNG from its Rio Grande project’s fifth liquefaction facility.
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Canada: Tourmaline Signs LNG Supply Deal to Export Canadian Gas to Europe
Tourmaline Oil will deliver 234 Bcf to Germany’s Uniper over an 8-year LNG supply agreement, linking Tourmaline’s Canadian gas with premium international pricing. Tourmaline Oil signed a long-term LNG supply contract with German firm Uniper, linking its Canadian gas with European demand. Calgary-based Tourmaline will supply 80,000 MMBtu/d, or approximately 80 MMcf/d, of Canadian gas into the U.S. Gulf Coast for an 8-year contract beginning November 2028. The estimated lifetime total volume of the transaction is approximately 234 Bcf, according to a Tourmaline spokesperson.
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Under an LNG netback supply agreement, Tourmaline will deliver Alberta and British Columbia (B.C.) gas to the ANR SE trading hub in southeast Louisiana. The contract terms are based on Dutch Title Transfer Facility (TTF) prices, which generally command a premium over North American benchmarks.
Tourmaline has secured long-term transportation to the Gulf Coast along TC Energy’s midstream system. Firm pipeline transport begins in November 2025, giving Tourmaline the flexibility to sell locally into Gulf Coast markets or pursue a shorter-term contract before the Uniper deal starts up.
“This long-term supply agreement with Uniper supports the continued execution of our market diversification strategy,” said Tourmaline President and CEO Mike Rose in a statement. “We’re proud to be supplying Canadian natural gas to meet rising demand in international markets and to enhance European energy security.”
Demand is expected to rise for Western Canadian gas to feed Asian and European LNG demand. Tourmaline anticipates natural gas prices to improve over the current strip in the back half of 2025 with the full startup of the new LNG Canada facility.
LNG Canada, located in Kitimat, B.C. on Canada’s West Coast, shipped its first cargo bound for South Korea this summer.
Shell owns a 40% stake in LNG Canada. Other partners in the joint venture (JV) are Malaysia’s Petronas (25%), PetroChina (15%), Mitsubishi (15%) and Korea Gas (5%).
LNG Canada is expected to produce about 14 million tonnes per annum (mtpa) at full capacity.
The agreement with Tourmaline Oil comes a few months after Uniper signed a separate LNG sale and purchase agreement with Woodside Energy for up to 2 mtpa.
The Woodside transaction includes LNG supply commitments for 1 mtpa from Woodside’s Louisiana LNG export terminal, which is currently under development on the Gulf Coast. Up to 1 mtpa will be sourced from Woodside’s global LNG portfolio, delivered directly to Europe.
“[The Tourmaline deal] showcases our ability to offer important international pricing exposure to a valued North America supplier and further diversifies Uniper’s LNG supply sourcing portfolio, an important aspect of our European security of supply objectives,” said Uniper COO Carsten Poppinga.
Marketing diversification and smart hedging are also benefiting Tourmaline’s bottom line. The company realized an average gas price of CA$3.34/Mcf in the second quarter, 90% higher than the AECO 5A benchmark price of CA$1.72/Mcf over the same period.
Power in B.C., Alberta
Tourmaline Oil is one of the top liquids and gas producers in the B.C. Montney play and Alberta’s Deep Basin.
Tourmaline produced 620,757 boe/d during the second quarter, including 2.88 Bcf/d of gas and 141,138 bbl/d of crude, condensate and NGL.
Last year, Tourmaline added about 30,000 boe/d, including 130 MMcf/d of gas output, through a US$950 million (CA$1.3 billion) acquisition of Montney assets from Crew Energy.
Tourmaline plans to drill a total of 365 wells this year. The company’s full drilling fleet has been operating since the beginning of the third quarter after lower activity during the spring.
Tourmaline highlighted impressive well results from its Groundbirch–Sunrise Montney SQ2 development zone. A recent test well, 1-24-80-16W6, had an IP180 of 2.53 MMcf/d and 256 bbl/d of condensate and NGL.
Total EURs from the well are estimated at 3.1 Bcf of gas and 204 MMbbl of liquids. Tourmaline estimates 128 incremental Montney locations in the area.
Tourmaline is deferring some B.C. completion activities into the fourth quarter given lower local gas prices so far this quarter. The company also released one drilling rig in the Alberta Deep Basin for the rest of the year.
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US: Cheniere and JERA sign long-term LNG SPA
Cheniere Energy, Inc. and JERA Co., Inc. have announced that Cheniere Marketing, LLC and JERA have entered into a long-term LNG sale and purchase agreement (SPA). Under the SPA, JERA has agreed to purchase approximately 1 million tpy of LNG from Cheniere Marketing on a free-on-board basis from 2029 through 2050. The purchase price for LNG under the SPA is indexed to the Henry Hub price, plus a fixed liquefaction fee.
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“We are pleased to enter into this multi-decade agreement with JERA, the larg-est power producer in Japan and one of the largest buyers of LNG in the world,” said Jack Fusco, Cheniere’s President and CEO. “This SPA fortifies our longstanding relationship with JERA, which is based upon years of cooperation and mutually beneficial LNG trade. We look forward to providing our flexible, reliable and cleaner burning LNG to JERA through 2050 under this new long-term agreement.”
Yukio Kani, Global CEO and Chair of JERA, added: “JERA and Cheniere have built a trusted relationship over many years, and we are pleased to extend this relationship further. This long-term agreement with Cheniere – a global leader in LNG – supports JERA’s strategy to diversify and strengthen our LNG procurement portfolio, reinforcing our role as a long-term energy partner in the US and deepening our commitment to securing reliable energy supplies. Together, we will continue to contribute to the energy security, stability, and sustainability of Japan and the broader region for decades to come.”
https://www.lngindustry.com/liquid-natural-gas/08082025/cheniere-and-jera-sign-long-term-lng-spa
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Thailand: Richest Thai sees US$10 billion hydro, LNG projects driving growth
[BANGKOK] Thailand’s richest person, Sarath Ratanavadi, expects US$10 billion investments in hydropower projects in neighbouring Laos and a new domestic liquefied natural gas (LNG) terminal to drive his business empire’s growth. Sarath’s flagship company, Gulf Development, and partners are working with banks on a roughly US$9 billion funding plan for three hydro plants with a total generating capacity of 3,100 megawatts, he said. Construction on a US$1 billion LNG import terminal project, Thailand’s third, will start later this year before commercial operations are scheduled in 2029.
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“We are turning our focus more on projects in Thailand and the region because of their lower risk relative to most other overseas projects,” Sarath said on Wednesday (Jul 30). “Our strength and profile have offered better leverage.”
Gulf Development, created earlier this year by combining Sarath’s operations in sectors including power, seaports, tollways and telecommunications, has accelerated its expansion in renewables and data centres to meet rising demand for clean energy and artificial intelligence. The company is also expanding into digital banking after being granted a license in June.
The investments in hydro and LNG will be in addition to US$1.75 billion announced in March for data centres. The hydro projects will start from 2031 to 2033.
The conglomerate seeks to boost total power generating capacity by 34 per cent over the next decade from about 9,000 megawatts currently, Sarath said. Most of that will be solar, wind and hydro in a bid to increase green energy capacity to 40 per cent of the total from around 13 per cent now.
The tycoon this week reclaimed his position as the nation’s richest person, with a net worth of about US$13 billion, as Gulf Development’s stock has gained more than 20 per cent since sinking to a record low in June. BLOOMBERG
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LNG as a Marine Fuel/Shipping
Turkey starts first shipments of natural gas from Azerbaijan to Syria
Turkey has started the first shipments of natural gas from Azerbaijan to Syria through the Turkish province of Kilis on Saturday, as Damascus seeks to rebuild war-battered infrastructure and boost power supply. The initiative will help bolster Syria’s energy security, Syrian Energy Minister Mohammad Al Bashir told Syria’s state news agency Sana. The ceremony to mark the start of the gas flow on Saturday was also attended by Azerbaijan’s Economy Minister Mikayil Jabbarov, Turkey’s Energy Minister Alparslan Bayraktar and official representatives from Qatar.
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“The inauguration of the regional gas transmission line linking Syria to Azerbaijan, passing through Turkish territory, is a strategic step on the path to enhancing energy security in Syria, and contributes directly to improving the electrical supply and increasing operating hours in generating stations, which reflects positively on the economic reality and living conditions, and supports the efforts of the displaced to return to their areas,” Mr Al Bashir told Sana.
In the first phase of the project, Syria will begin receiving 3.4 million cubic metres of gas daily, which will enable the country to increase energy production by 750 megawatts, he added.
Ankara, which supported rebel forces in neighbouring Syria throughout the 13-year civil war that ended in December with the ousting of former president Bashar Al Assad, has now become one of the current Syrian government’s main foreign allies while positioning itself as a major player in Syria’s reconstruction.
Syria is suffering from severe power shortages, with state-supplied electricity available for only for a few hours a day in most areas. Damascus used to receive the bulk of its oil for power generation from Iran before Hayat Tahrir Al Sham took power in December.
Gas that will come from Azerbaijan will be exported to Aleppo via Kilis. Qatar will finance part of the project.
Mr Bayraktar told the state-owned Anadolu news agency on Saturday that up to 2 billion cubic meters of natural gas can be exported annually to Syria, generating electricity to power five million households.
Electricity exports to Syria currently flow through eight different points, with capacity set to increase by 25 per cent initially and then more than double, the Turkish energy minister said.
Addressing the event, Mr Jabbarov said that the export of Azerbaijani gas from Turkey to Syria was launched in a short period of time based on the agreements reached during the meetings between Azerbaijani President Ilham Aliyev and Syrian Transitional President Ahmed Al-Sharaa on April 11 in Antalya and July 12 in Baku, the Azerbaijan state news agency Azertac reported on Saturday.
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Germany: 100th LNG carrier arrives at Wilhelmshaven LNG terminal
The 100th LNG carrier arrived at the Wilhelmshaven LNG terminal 01 at Voslapper Groden with the second high tide of the day. The arrival of the Venture Gator marks another significant milestone since the commissioning of Germany’s first floating LNG terminal at the end of 2022. The total cargo delivered by all 100 LNG tankers corresponds to approximately 100 TWh or 8.6 billion m3 of natural gas after regasification. In purely mathematical terms, the terminal has continuously supplied around 1.6 million households (with an annual consumption of 2000 cubic meters) to date. These figures underline Wilhelmshaven’s central role in the nation’s energy supply.
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The delivered LNG is transferred via a ship-to-ship process from the LNG carrier to the FSRU within roughly 24 hours, at a maximum rate of 9000 m3/h. Each delivery typically involves around 160 000 m3 of LNG. Since operations began at the end of 2022, Wilhelmshaven01 has established itself as a stable and secure hub for LNG imports.
Breakdown of LNG deliveries:
- 2023: 45 LNG carriers with a total of 6.9 million m3 of LNG.
- 2024: 39 LNG carriers with 5.9 million m3 of LNG.
- 1H25: 16 LNG carriers with 2.3 million m3 of LNG.
- Planned for 2H25: 17 additional deliveries.
The terminal is fully booked until the end of the year. Additionally, the market has taken up all regasification capacities for Wilhelmshaven 01 offered by Deutsche Energy Terminal GmbH (DET) in the associated marketing round at the beginning of July for 2026. Since operations began in December 2022, there have been no unplanned shutdowns or unavailability of the facility, aside from two scheduled five-day maintenance windows each year. Moreover, there have been no reportable workplace accidents.
Dr Peter Röttgen, Managing Director of DET, said: “The 100th delivery is not only a logistical milestone, but also a key event in energy policy. Our terminal in Wilhelmshaven has proven to be a reliable site for securing energy supply during the crisis and continues to help prevent future shortages. I would like to thank all our partner companies, stakeholders, and of course our customers, who value the high standards of quality and safety at our terminals. At the same time, we are already looking ahead to how we can contribute our local expertise to the transition toward renewable energy sources.”
Dr Nadine Menning, Head of Energy Assets Northwest and Managing Director of LNG Terminal Wilhelmshaven GmbH (LTeW), added: “The arrival of the 100th LNG carrier is a clear sign of the stable, safe, and efficient operations at LNG Terminal 01 in Wilhelmshaven. The volumes delivered to date highlight the importance of this location. Together with all partners, we have created a reliable new pillar for Germany’s gas supply.”
Vegard Hellekleir, Chief Operating Officer, Höegh Evi, concluded: “The arrival of the 100th LNG carrier at Wilhelmshaven marks a significant operational and strategic milestone. As owner and technical operator of the FSRU, we are proud of the role that Höegh Esperanza and our colleagues on board play in strengthening Germany’s energy security, and we look forward to continuing our close collaboration with DET and other terminal partners to ensure safe and reliable operations.”
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South Korea: Hanwha Shipping orders LNG carrier from Hanwha Philly Shipyard
Hanwha Shipping, a US subsidiary of Hanwha Ocean, has ordered an LNG carrier from its affiliate, Hanwha Philly Shipyard. The vessel will be constructed with advanced technology and propulsion systems, and will be the first US-ordered, export-market-viable LNG carrier in almost 50 years, dating back to the late 1970s.
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With this contract for one LNG carrier and an option for a second vessel, Hanwha is bringing its LNG shipbuilding and operational expertise from Korea to the US through capability and technology transfers that support the growth of the US maritime industrial base. This initiative aims to meet the growing demand for US LNG carriers that are crewed by US mariners and comply with rigorous U.S. Coast Guard standards. These vessels represent a resurgence in US shipbuilding capabilities, buoyed by recent US trade policies that require a growing percentage of LNG exports to be transported on US vessels.
“We’re excited to leverage Hanwha’s world-class shipbuilding prowess to equip American industrial partners with the skills to construct next-generation LNG carriers for the first time in nearly five decades,” said Ryan Lynch, President and CEO of Houston-based Hanwha Shipping. “Hanwha Ocean – Philly Shipyard’s Korean shipbuilding affiliate – became the world’s first shipbuilder to produce and deliver its 200th LNG carrier earlier this year. This amazing milestone reinforces Hanwha’s global leadership position in LNG carrier construction, which we are eager to replicate in the US.”
Under the structure of this project, Hanwha Philly Shipyard, as the US-based shipyard, signs the primary shipbuilding contract with Hanwha Shipping – a Hanwha Ocean affiliate and the project’s owner – and then executes the contract as part of a joint-build model with Hanwha Ocean.
With this order, Hanwha is positioned to secure a leading technological edge and supply capability in the North American LNG carrier market. As the only company in the world with shipbuilding operations in both Korea and the US, Hanwha plans to enhance its capability to build LNG carriers in the US through a cooperative model with Hanwha Philly Shipyard.
While a significant portion of the construction will be carried out at Hanwha Ocean’s Geoje shipyard in Korea, the project will be executed as a joint-build model. Hanwha Philly Shipyard will be responsible for US regulatory compliance and safety certifications, laying the foundation for a collaborative production framework. Through this model, Hanwha plans to gradually transfer its advanced shipbuilding technologies to Hanwha Philly Shipyard, enabling the latter to expand into high-value shipbuilding. This LNG carrier order marks a significant milestone in contributing to the revitalisation of the US shipbuilding and maritime sectors.
Hanwha Shipping plans to utilise the ordered vessels as a strategic platform to support US energy security and global energy reliability. In addition to fulfilling internal group transport requirements, the vessels will play a key role in establishing the US-flagged LNG fleet, reinforcing American leadership in global energy logistics, and accelerating the reindustrialisation of the American maritime sector. By leveraging US-sourced LNG and modern shipbuilding capacity, Hanwha aims to offer a reliable, cost-effective solution to rising global demand – particularly amid heightened geopolitical tensions and increasing pressure on energy supply chains.
Last December, Hanwha – a global conglomerate with a world-class shipbuilding arm – acquired Philly Shipyard for US$100 million. The historic shipyard has delivered more than half of the US’s large commercial vessels under the Jones Act since 2000.
With the acquisition, Hanwha is focused on revitalising Hanwha Philly Shipyard as part of its wider goal of increasing US maritime capacity and the US maritime industrial base. Drawing on its decades of shipbuilding expertise and know-how, Hanwha is making significant investments in expanding Philly shipyard’s capabilities with technological advancements, workforce training, and smart systems – creating significantly more onboarding capacity and thousands of new skilled manufacturing jobs in the US.
Link: https://www.lngindustry.com/lng-shipping/23072025/hanwha-shipping-orders-lng-carrier-from-hanwha-philly-shipyard/
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Technological Development for Cleaner and Greener Environment Hydrogen & Bio-Methane
National Gas appoints WSP to design hydrogen transmission network
The project aims to repurpose sections of the existing 8,000km National Transmission System (NTS) gas pipelines to carry 100% hydrogen. Initially, the focus will be on developing local transmission links between key hydrogen production and storage facilities and industrial hubs in the Humber and Teesside regions. These local networks will be integrated over time to form a 2,400km hydrogen pipeline spanning the East Coast of Great Britain, with potential to expand further.
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WSP, supported by Kent and backed by specialists including Murphy, Aecom, Premzero and National Gas Services, has been appointed as the Front-End Engineering Design (FEED) Integrator for the two-year design and environmental assessment phase. Their role includes securing necessary consents and managing public consultation efforts.
Project Union East Coast is part of the broader East Coast Hydrogen initiative, a collaborative effort between National Gas, Cadent and Northern Gas Networks. The wider programme seeks to establish a hydrogen distribution network across the Northeast, Humber, Yorkshire and East Midlands regions, supplying hydrogen to power stations, industries and storage locations.
This wave of hydrogen infrastructure development follows recent backing from Ofgem, which confirmed £96M in funding (adjusted to 2025/26 prices) for the East Coast Hydrogen programme, reinforcing the UK’s strategy to decarbonise its energy system and enhance energy security. By facilitating the transport of low-carbon hydrogen, the project aims to support the country’s industrial clusters in reducing carbon emissions and securing jobs as the hydrogen economy scales up.
Hydrogen is increasingly seen as a key element in the UK’s pathway to net-zero emissions, particularly in sectors that are hard to electrify, such as heavy industry and power generation. However, creating the necessary hydrogen infrastructure involves significant technical and regulatory challenges, including pipeline conversion, safety considerations, and broad stakeholder engagement.
The appointment of WSP and its consortium signals a critical step in moving the project from concept to reality, as the UK government and industry seek to accelerate low-carbon energy solutions amid growing climate commitments and energy security concerns.
National Gas chief commercial officer Ian Radley said: “This is a key milestone for National Gas and our work in delivering the UK’s hydrogen future. The start of FEED for Project Union East Coast marks the transition toward delivery for this pioneering project.
“We’re not just planning pipelines – we’re building a cleaner, more resilient energy system that will protect skilled jobs and power our future economy, servicing industries that can’t electrify and providing clean dispatchable power to compliment renewables.
“We look forward to WSP working with our brilliant internal team of experts to achieve this ambition.”
WSP project director Ben Clarke said: “Project Union represents a vital step toward the UK’s low-carbon future, and we’re proud to be supporting National Gas in bringing this transformative vision to life.
“Delivering the FEED for the East Coast phase means shaping a future hydrogen network, and that calls for early collaboration, technical excellence, and deep-rooted partnerships.
“Through our role as integrator, we will help align delivery across this complex programme, ensuring the right infrastructure is in place to connect industry, communities and clean energy at scale.”
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Thai utility EGAT to start using hydrogen fuel as early as 2030
BANGKOK — Thailand’s state-owned utility, the Electricity Generating Authority of Thailand (EGAT), is working toward using some hydrogen fuel at its natural-gas-fired power plants to reduce its carbon emissions, starting as early as 2030. Roughly 70% of the power EGAT generates comes from burning natural gas, which will remain an essential energy source going forward, given the large amount of power that can be produced from each generator. The utility plans to start by replacing 5% of the natural gas fuel used in its power generation with hydrogen around 2030 and then continue to ramp that proportion up incrementally.
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This type of undertaking is still rare for Southeast Asia, but Thailand is looking for ways to decarbonize while still meeting the growing demand for power through thermal generation.
EGAT Deputy Gov. Narin Phoawanich spoke with Nikkei, saying, “for the time being, gas thermal will remain the primary energy source for Thailand, but at the same time we must look for ways to cut carbon emissions,” including incorporating hydrogen fuel.
Hydrogen does not produce carbon dioxide when burned, meaning that when mixed in with gas, CO2 emissions are reduced. Its introduction into industrial and automotive applications as an alternative fuel has been making advances. Such efforts have also made progress toward practical applications in Japan, with Kansai Electric Power succeeding in trials to replace 30% of gas with hydrogen in power generation, for example.
Power generation facilities require retrofitting with specialized generators and lines to use hydrogen as a fuel. EGAT has been working with Mitsubishi Heavy Industries since last year to investigate the types of hydrogen equipment and infrastructure it will need, and will narrow down options for which facilities in which it will incorporate hydrogen based on the results. Phoawanich said EGAT is considering “several candidates, including near Bangkok and in the northeast” in areas where energy demands are high.
Preparations for hydrogen sourcing are also underway. EGAT is looking into “green hydrogen” — hydrogen fuel that does not create carbon emissions in its production — with Laotian state-owned utility Electricite du Laos, which already supplies some hydro power to Thailand.
Demand for energy continues to grow in Thailand. The Thai government’s long-term power generation plan estimates that domestic energy demand will grow about 50% by 2037. Under this plan, gas thermal generation will still account for roughly 40% of the total mix in 2037, continuing to supplement solar and other means that are subject to the effects of weather.
Meanwhile, the need for decarbonization here is great, with power generation and manufacturing plants accounting for the largest proportion of carbon emissions in the country at nearly 40%. Yotaro Akamine, a partner at Deloitte Touche Tohmatsu, said, “In Europe, there is a trend toward placing what amount to tariffs on goods imported from countries with less strict environmental regulations, which means that reducing Southeast Asia’s energy carbon footprint could make companies there more competitive.”
The challenge lies in the cost, which is more than double that of fossil fuels. Because fuel costs account for the majority of power production costs, higher fuel prices will have a direct impact on power generation costs. Cost-cutting efforts in Japan have included supplying hydrogen to manufacturers near power-generation facilities, bringing down the price through contracts for larger volumes. EGAT plans to cooperate with nearby companies on building out infrastructure as well.
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Iraq begins study on green hydrogen and expands solar energy efforts
Baghdad: Iraq has started a study to assess the possibility of producing green hydrogen as part of its plan to adopt cleaner energy sources, reports Iraqi News.
The study is being carried out by the Ministry of Industry and Minerals in coordination with the Ministry of Electricity, the Ministry of Oil, and the National Investment Commission. Private companies are also involved in the initiative.
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Alongside this, the government is also looking at how to set up cement factories that release fewer emissions. Both moves are part of Iraq’s national energy strategy, which aims to reduce pollution, make better use of energy, and increase the use of renewable power, especially solar energy, in industrial projects.
The Ministry of Industry and Minerals said several of its companies are ready to take on solar power projects. The government plans to generate 12,000 megawatts of electricity from solar energy by 2030.
As part of that effort, a large solar power plant is under construction in the central desert region. The plant will eventually produce 300 megawatts of electricity using 500,000 solar panels. So far, 39,000 panels have been installed.
The project is expected to help ease Iraq’s ongoing electricity shortages, which have worsened due to reduced gas supplies from neighboring Iran.
https://bioenergytimes.com/iraq-begins-study-on-green-hydrogen-and-expands-solar-energy-efforts/
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Mitsubishi Power Achieves First 100% Hydrogen Boiler Conversion in Egypt
Alexandria, Egypt — Mitsubishi Power, a power solutions brand of Mitsubishi Heavy Industries, Ltd. (MHI), announced today the successful completion and handover of a pioneering hydrogen fuel conversion project at the Alexandria National Refining and Petrochemicals Company (ANRPC) refinery in Egypt. This project is considered the first industrial application of hydrogen use as fuel in industrial boiler in Egypt and the MENA region.
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Under the terms of the full turnkey contract, announced in 2022, Mitsubishi Power undertook the design, engineering, supply and installation of the solutions, equipment, and control systems to rehabilitate and upgrade a 100-ton-per-hour main boiler, converting it from heavy fuel oil and natural gas to a 100% hydrogen fuel. The project also contributed to the utilization of 14,000 tons per year of hydrogen-rich gases available in the production units, reducing natural gas consumption by approximately 24,000 tons and contributing to a reduction of carbon emissions by approximately 65,000 tons per year.
This project marks a significant step forward in Egypt’s ambitious energy transition journey towards decarbonizing its energy sector and fulfilling its sustainable development goals, which reinforces its leadership in clean energy innovation. It also highlights the Japanese global leader’s commitment to advancing carbon neutral power generation solutions and jointly reflects hydrogen’s enormous potential as a clean energy source in Egypt’s industrial sector.
Mitsubishi Power’s expertise in providing cutting-edge hydrogen technology solutions, coupled with ANRPC’s operational leadership, contributed to the project’s success, reinforcing its importance as a proven model for integrating hydrogen into Egypt’s energy system and a replicable model that can catalyze further hydrogen adoption across Egypt and the MENA region.
Mr. Sayed Al-Rawi, Chairman and Managing Director of ANRPC, said: “We are proud to be part of Egypt’s journey towards a clean energy future and to contribute to achieving Egypt Vision 2030 with this pioneering milestone to using hydrogen as a fuel. This project represents an unprecedented achievement for ANRPC, Egypt, and the entire region. By integrating hydrogen into refining processes, we are contributing to reduce Egypt’s carbon footprint and set a new standard for the country’s industrial sector. We are proud of our partnership with Mitsubishi Power on this project, which is a true example of how international partnerships and advanced technology can bring about fundamental change toward a sustainable energy future. We are thrilled about the positive environmental impact of this project in reducing emissions, and we look forward to continuing our role in supporting Egypt’s transition to clean energy. Together, we can help meet current energy needs and participate in shaping a sustainable energy future in Egypt and the region.”
The collaboration between Mitsubishi Power and ANRPC underscores a fundamental pillar of Egypt’s clean energy strategy and contributes to consolidating the nation’s growing role as a leader in the global hydrogen economy.
Commenting on this recent milestone, Mr. Javier Cavada, President and CEO, Europe, Middle East and Africa at Mitsubishi Power, said: “The success of this first-of-a-kind hydrogen conversion project marks a milestone in Egypt’s transition to clean energy and reflects Mitsubishi Power’s global leadership in developing advanced, low-carbon power generation technologies. We are honored to partner with ANRPC and support Egypt’s ambitious vision for a clean energy transition, providing our expertise to transition existing infrastructure to low-carbon commercially viable systems. This project will lay down the foundation to a commercial path for decarbonizing Egypt’s industrial facilities with minimal downtime, in addition to demonstrating the tangible and positive impact of hydrogen in reducing emissions and developing sustainable energy solutions. Mitsubishi Power is committed to supporting Egypt’s journey towards a cleaner and more sustainable energy future, and we look forward to strengthening our collaboration with ANRPC and other stakeholders to drive the transition to hydrogen across the region.”
The successful completion of this project heralds a new chapter in Egypt’s energy transition, further strengthening its growing leadership in the region’s low-carbon future. Building on a successful heritage that spans decades, Mitsubishi Power remains committed to supporting Egypt’s ambitious energy goals and its efforts to drive the adoption of hydrogen and renewable energy technologies throughout the Middle East and North Africa.
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Sungrow Hydrogen and UES Sign MoU for Green Hydrogen Plant in Oman
United Engineering Services (UES) has signed a Memorandum of Understanding with China’s Sungrow Hydrogen Sci & Tech Co to set up a manufacturing facility in Oman dedicated to producing equipment essential for the nation’s emerging green hydrogen industry. The agreement represents UES’s first move into hydrogen and is seen as a major step toward establishing Oman as a regional hub for advanced hydrogen technology.
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Muscat-based UES, part of MB Holding Group, specializes in high-tech engineering services for the oil & gas, marine, and defence sectors. “This partnership is a strategic step in expanding our renewable energy footprint and positioning Oman as a regional hub for advanced hydrogen technologies,” said UES CEO Dr Salim al Harthy. The plant will produce and assemble electrolysers, gas separation and purification systems, and supporting infrastructure for local and export markets.
Xiaowei Duan, Head of the AMEA Region and Key Account Director at Sungrow Hydrogen, stated: “We are proud to join forces with a respected Omani industrial leader. Together, we aim to bring cutting-edge hydrogen solutions to Oman.” Sungrow Hydrogen, a major global supplier of hydrogen equipment, operates China’s first automated ALK electrolyser assembly line with a 3 GW annual capacity and designs ALK and PEM electrolysers, gas-liquid separators, and purification systems.
Earlier this year, Sungrow Hydrogen secured a contract to supply water electrolysis equipment for Oman’s first green ammonia project at Duqm. The 100,000 tpa green ammonia plant, developed by Green Hydrogen and Chemicals Company SAOC, a subsidiary of India’s ACME Group, is planned to expand to 900,000 tpa over multiple phases. Sungrow announced it had won the “biggest share” of a 320 MW equipment contract for the project, which includes multiple 1,000 Nm³/h alkaline hydrogen units scheduled for delivery in 2025.
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