Meanwhile, Nifty Energy index of which Petronet LNG Ltd is a constituent, has added around 1.44% in last one month and is currently quoting at 38252.2, up 0.05% on the day. The volume in the stock stood at 12.17 lakh shares today, compared to the daily average of 18.94 lakh shares in last one month.

The benchmark August futures contract for the stock is quoting at Rs 294.3, up 0.86% on the day. Petronet LNG Ltd is up 7.64% in last one year as compared to a 3.15% fall in NIFTY and a 10.95% fall in the Nifty Energy index.

The PE of the stock is 10.63 based on TTM earnings ending June 26.

https://www.business-standard.com/markets/capital-market-news/petronet-lng-ltd-gains-for-fifth-session-126082400473_1.html

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Sylvia Anjos, Petrobras’ head of exploration and production, told Reuters that the Ghana blocks are geologically similar to Brazil’s Equatorial Margin, which is considered the country’s most promising oil frontier.

The oil major plans to make Africa its main exploratory region outside of Brazil, Petrobras Chief Executive Magda Chambriard told Reuters last year.

Beyond Ghana, Petrobras has been looking in to several African countries for opportunities, including Sao Tome and Principe, Namibia, Ivory Coast and South Africa.

The move is aligned with Petrobras’ strategy of replenishing oil and gas reserves through exploration in new frontier areas in Brazil and abroad, the company said in a securities filing. It added that it is evaluating opportunities to diversify its exploration portfolio and support long-term growth.

https://www.reuters.com/business/energy/petrobras-enters-negotiations-four-offshore-blocks-ghanas-keta-basin-2026-08-21/

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The notice states that the proposed pipeline location was determined through a route selection process conducted in 2019 and is “generally parallel to the three existing Enbridge Gas pipelines, measuring approximately 10.2 km in length.” New permanent easements and temporary working space during construction will be required.

As part of the Environmental Study process, Enridge is planning consultation and engagement with Indigenous communities, landowners, government agencies and the local municipality, as well as other interested parties.

An in-person information session takes place Tuesday, Aug. 25 from 5 to 8 p.m. at Millgrove Community Centre. As well, a virtual information session is available until Aug. 31 at https://www.solutions.ca/Kirkwall-HamiltonES/.

Materials from the in-person Information Session will be available for on the Enbridge Gas project webpage, and a questionnaire will also be available as part of the Information Session, where participants can provide comments or ask questions about the project.

The deadline for input and comments about the project is Sept. 15, 2026.

According to the public notice, Stantec Consulting Ltd. has been retained to reaffirm the findings of the 2019 Kirkwall to Hamilton Environmental Report and prepare an Addendum that will fulfill Ontario Energy Board (OEB) requirements for the project.

The Addendum is expected to be completed in early 2027, after which Enbridge plans to apply to the OEB for approval to commence construction.

“If approved, construction is anticipated to begin in the spring of 2028,” states the notice.

https://www.flamboroughtoday.com/local-news/meeting-slated-for-aug-25-in-millgrove-to-discuss-pipeline-project-12692440

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Gas Infrastructure Europe brings together operators working in the fields of gas and liquefied natural gas (LNG) transportation and storage. The statistical database covers the operation of underground natural gas storage facilities since 2011 and LNG reception and regasification since 2012.

The shortage of storage capacity ahead of winter is keeping prices from falling. Wholesale gas prices in Europe have risen to their highest level since March amid reduced supplies and concerns among traders, who forecast further increases up to $800 per thousand cubic meters. The market is reacting to geopolitical risks and high demand for filling storage facilities.

https://logos-pres.md/en/news/gas-reserves-in-europe-have-risen-to-61-82/

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The signing ceremony was honoured by the presence of Dr Samia Suluhu Hassan, President of the United Republic of Tanzania, underscoring the project’s strategic importance to the energy security and industrial development plans of the Government of Tanzania, which is a shareholder of Africa50.

Also in attendance were Alain Ebobissé, CEO of Africa50; Pakinam Kafafi, CEO of TAQA Arabia; Karim Shaaban, Managing Director of Rosetta Energy Solutions; Adly Kafafi, VP Business Development at TAQA Arabia; Ali Abubakr, COO of Rosetta Energy Solutions; Amr Aboushadi, Country Manager Tanzania at TAQA Arabia; Kenneth Mutaonga, GM LNG Rosetta Energy Solutions; Nabil Saimi, Senior Investment Director at Africa50; and Reda Souini, Associate Investment Director at Africa50.

Through EALNG, the partners intend to invest in, develop, and operate the facility for Tanzania’s domestic market, serving industrial, residential, and trans-portation customers, including users beyond the existing gas pipeline network. TPDC will be both gas supplier and an equity partner.

The GSA is a key commercial milestone towards final investment decision (FID), with commercial operations targeted to begin in 2027:

Shaaban said: “This GSA is an important step towards FID and a key milestone in our scalable LNG growth strategy in Tanzania. We intend to grow capacity as we enable and develop the market, reflecting TAQA Arabia Group’s long-term commitment to Tanzania and its energy future.”

Saimi added: “Africa has significant gas resources, but unlocking their economic value requires the infrastructure to connect those resources to where energy is needed most. Through our new dedicated midstream gas platform, Africa50 intends to help build that missing link across the continent. This project in Tanzania is an important first step, expanding the productive use of domestic gas while laying the foundation for larger investments that can support industrial growth and economic development.”

The facility will liquefy domestic natural gas for distribution by specialised vehicles, extending the reach of locally produced gas and helping replace more costly and carbon-intensive fuels.

The partners will now advance the technical, commercial, environmental, regulatory, and financing work required to reach FID and begin construction.

This article has been tagged under the following:

https://www.lngindustry.com/small-scale-lng/21082026/tpdc-taqa-arabia-and-africa50-sign-gas-sales-agreement/amp/

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There are competitors like Australia and Qatar, so where the rapidly evolving Texas LNG industry will be in three to five years is an intriguing question.

The Texas Oil & Gas and Texas Independent Producers & Royalty Owners associations say the state’s burgeoning production give it an advantage.

TXOGA President Todd Staples says Texas continues to be the U.S. leader in natural gas production, which is on pace to set a record this year at 122.5 billion cubic feet per day.

“Most of this growth is led by the Permian Basin and the Haynesville Shale in northwestern Louisiana, eastern Texas and southwestern Arkansas,” Staples said. “As a direct result of the industry’s robust production pipeline, processing and port infrastructure the Texas Gulf Coast is a global gateway for American energy and new export capacity continues to come online.

“When the world asks for more energy, Texas answers.”

He said global competition to energy production is always an element to be watchful of and it is the reason the industry must ensure that Texas delivers a predictable, stable and robust regulatory environment based on sound science and transparency.

“American energy strength and security led by Texas continues to be the steadying force that delivers for national security,” Staples said. “Continued infrastructure expansion including pipelines, processing, transmission and generation strengthens West Texas. “When West Texas is strong, America is stronger.”

The current wholesale price of natural gas in Europe is $19.36 per thousand cubic feet.

TIPRO President Ed Longanecker said the world is in the early stages of the largest LNG build out in the industry’s history and Texas sits at the center of it. “Global LNG supply is projected to grow by more than 7 percent or roughly 40 billion cubic meters in 2026, the largest annual increase since 2019 as new liquefaction projects enter service in the United States, Canada and Qatar,” Longanecker said. “Between 2025 and 2030 around 345 billion cubic meters per year of new LNG export capacity is expected to come online from projects either announced or already under construction — the largest wave of capacity additions in the history of the LNG market.

“The U.S. has accounted for nearly 60 percent of all new LNG capacity sanctioned worldwide since 2019 and more than 90 percent of global final investment decisions in 2025 — a record year with more than 83 billion cubic meters per year of new U.S. capacity approved.” As of August, he said, every project reaching a final investment decision so far in 2026 has also been American.

 “U.S. LNG exports reached 16.2 billion cubic feet per day in May 2026 for the highest volume on record for that month and 15.5 percent above the daily rate in May 2025,” Longanecker said. “For the full year exports are forecast to average 17.4 billion cubic feet per day with further growth to 18.6 billion cubic feet per day expected in 2027.

“That trajectory would sustain the United States as the largest single LNG exporter in the world, ahead of Qatar and Australia combined.”

He said Qatar remains the most significant direct competitor with its North Field East and North Field South expansions under construction and slated to add more than 65 billion cubic meters per year of capacity.

“Qatar’s near-term growth has been complicated by military attacks on its Ras Laffan facility in March 2026, which damaged two of its 14 liquefaction trains and knocked out roughly 17 billion cubic meters per year of capacity, which is expected to take three to five years to repair,” Longanecker said. “The North Field East expansion, previously targeted for late 2026, is now expected to be delayed by more than a year.

“Australia’s position is comparatively static with its major projects operating near full capacity and with limited incremental growth, leaving its export trajectory flat relative to the United States and Qatar.”

He said Texas is the geographic center of the American build out.

An LNG train is an industrial processing unit that cleans and cools natural gas to turn it into LNG that is converted back to gas at specialized import terminals, onshore processing plants or floating offshore units.

“Corpus Christi, Freeport, Sabine Pass and the developing Brownsville complex account for the majority of operating and under construction U.S. liquefaction capacity,” Longanecker said. “Golden Pass, the QatarEnergy and ExxonMobil joint venture at Sabine Pass, shipped its first export cargo on April 22 after its first train began production in late March.

“ExxonMobil’s leadership has said the facility’s second train is expected to reach mechanical completion by the end of 2026 with the third train following in the second quarter of 2027, bringing total capacity to roughly 21 billion cubic meters or about 15.6 million tons per year once complete.

At Corpus Christi, he said, Cheniere has completed six of the seven liquefaction trains in its Stage 3 expansion with the seventh already receiving federal approval to introduce feed gas and on track for substantial completion as early as August or September of this year. “Once finished, the expansion will bring the terminal’s total permitted capacity above 25 million tons annually,” Longanecker said. “NextDecade’s Rio Grande LNG facility at the Port of Brownsville has its first three trains under construction with first LNG expected in 2027 and a fourth train sanctioned in 2025 targeting 2030 and a fifth targeting 2031.

“Port Arthur LNG’s first phase is under construction with first LNG expected in 2027 and its second phase, sanctioned in 2025, targeting 2030.”

He said the pipeline and feedgas infrastructure supporting these terminals is the more immediate constraint. “Approximately 18 to 20 billion cubic feet per day of Gulf Coast pipeline capacity is expected to be built in 2026 alone — the largest single year build out in more than a decade with most capacity dedicated to feeding terminals scheduled to enter service in 2027 and beyond,” Longanecker said. “Export demand is pulling increasing volumes from both the Permian Basin and the Haynesville Shale into the Gulf Coast corridor and most existing pipeline routes into that corridor are already constrained or approaching constraint.

“The Blackcomb Pipeline, now commissioning to move Permian gas to Agua Dulce, and the newly sanctioned Bay Runner Twin line feeding Rio Grande LNG illustrate how closely the current midstream build out is tied to specific export contracts.”

On the multi-year outlook, he said, the industry’s trajectory is unusually visible for a sector of this complexity because large LNG terminals typically require four to five years from final investment decision to first cargo, meaning most capacity arriving through 2030 is already under construction today.

“Annual capacity additions globally are projected to rise from about 35 billion cubic meters per year in 2025 to a peak near 95 billion cubic meters per year in 2028 before tapering in 2029 and 2030,” Longanecker said. “Pipeline capacity constraints in the Gulf Coast corridor and permitting timelines for new infrastructure are the two most likely factors that could slow Texas growth because a terminal that outpaces its feedgas access will underperform regardless of its own readiness. “Geopolitical disruption affecting Middle East shipping lanes or Qatari production could tighten the market further and increase demand for United States cargoes rather than slow the build out.”

https://www.oaoa.com/local/texas-at-center-of-robust-global-lng-expansion/

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The reforms could shorten payback periods for residential rooftop solar installations to about 5.5 years for 5-kilowatt (kW) systems and 4.5 years for 10 kW systems, compared with the current six to seven years.

Thailand relies on natural gas for 66% of its electricity generation. Declining domestic gas production has increased the country’s reliance on LNG imports, exposing its power sector to global fuel price volatility and supply disruptions.

The Electricity Generating Authority of Thailand, the state utility and buyer of last resort, had more than $1b in losses from past energy crises by March 2026.

 “Thailand has significant solar potential, but weak financial incentives and policy uncertainty have constrained rooftop solar deployment,” said Haneea Isaad, Energy Finance Specialist at IEEFA.

Isaad added that strengthening the policy framework would allow consumer-led solar adoption to play a greater role in Thailand’s energy transition.

Thailand had about 11.8 gigawatts (GW) of solar capacity as of early 2026. Utility-scale, ground-mounted installations accounted for 8 GW, whilst rooftop solar accounted for 3.6 GW.

IEEFA said high installation costs, low buyback rates, restrictive quotas, and policy uncertainty have limited rooftop solar adoption. Rooftop solar installations cost about $936 per kW in Thailand, nearly 50% higher than in Pakistan, Malaysia, and Vietnam.

Thailand’s “Solar for Thai People” net billing scheme pays $0.07 per kilowatt-hour (kWh) for exported electricity, below average retail electricity tariffs of about $0.12/kWh.

The 90-megawatt (MW) residential quota under Thailand’s 2019 net billing scheme was fully used by 2024, despite being intended to run until 2030.

“Removing regulatory and financial barriers, similar to Pakistan, could boost the scale of rooftop solar adoption in Thailand, support the growth of a domestic solar installation and service industry, reduce electricity costs, and provide consumers with greater energy independence,” Isaad said.

IEEFA cited Pakistan as a case study for rooftop solar expansion.

Pakistan has deployed 38 GW of solar capacity since 2018 after removing trade barriers, avoiding strict capacity caps, and implementing a net metering framework that compensates excess generation on a kWh-to-kWh basis.

Pakistan’s policies, combined with lower solar module prices and high electricity tariffs, reduced payback periods for net-metered systems to less than two years. The country had more than 350,000 connections by the end of 2025.

Thailand uses separate mechanisms for different solar segments, including a residential rooftop solar net billing scheme, feed-in tariffs for ground-mounted projects, and a community solar initiative capped at 1,500 MW.

IEEFA said Thailand’s compensation rates and buyback mechanism favour self-consumption, which gives households and businesses with higher shares of on-site solar consumption greater savings and shorter payback periods.

“The government should consider adjusting its regulatory framework to improve project economics for consumers,” Isaad said.

https://asian-power.com/regulation/in-focus/thailand-rooftop-solar-reforms-could-cut-lng-reliance-ieefa-says

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