Reliance Industries Ltd saw revenue from its oil-to-chemicals segment for the quarter ended December 2025 (third quarter of financial year 2026) increase 8.4 percent from Q3 FY 2025 to $18 billion. That was helped by a two percent increase in refining throughput with 20.6 million metric tons of crude processed in the three-month period, despite challenges in procuring oil, according to an online statement by the diversified Indian conglomerate. “Agile crude sourcing helped sustain throughput despite procurement challenges”, Reliance said. “Partial resumption of Red Sea route also benefitted operations”, it added. Reliance operates what it says is the world’s biggest single-site refinery in Jamnagar, India. The facility has a declared processing capacity of 1.4 million barrels a day. The Q3 FY2026 statement said refinery utilization was maximized “to capture high margins”. Reliance reported 18.2 million metric tons in production meant for sale, up 1.7 percent year-on-year. Reliance’s fuel retailing network under the Reliance BP Mobility Ltd brand, a joint venture with BP PLC, expanded by 14 percent year-over-year to 2,125 outlets, driving volume growth of over 20 percent, according to the statement. A “sharp increase in transportation fuel cracks and higher sulfur realization” drove a 14.6 percent year-on-year increase to $1.18 billion in petrochemicals EBITDA. The improvement in transport fuel cracks was aided by “continued disruptions in Russian supply and unplanned outages in other regions”, Reliance said. “US/EU sanctions on Russian refiners further tightened fuel markets”. On the other hand, Reliance saw “weakness in downstream chemical margins and higher feedstock freight rates”. However, it added, “Favorable ethane cracking economics and domestic market placements continued to support profitability”. At the backdrop, both global and domestic demand for oil products grew year-on-year in Q3 FY2026, partially offset by a price decline, the statement noted. “Crude oil benchmarks declined y-o-y on expectations of

Why is the U.S. natural gas price rising today? That was the question Rigzone asked Ole R. Hvalbye, a commodities analyst at Skandinaviska Enskilda Banken AB (SEB), in an exclusive interview on Monday. Responding to the question, Hvalbye highlighted to Rigzone that Henry Hub was trading around $3.5 per million British thermal units (MMBtu) today, “up from [around] … $3.1 per MMBtu before the weekend”, and noted that “the drivers look fairly straightforward and well known rather than structural”. “Short-term forecasts turned colder across parts of the U.S., lifting heating demand expectations and supporting front-end prices,” Hvalbye told Rigzone. “Feedgas flows remain elevated and firm, reinforcing near-term demand for U.S. gas and tightening the spot balance marginally,” he added. “After the recent sell-off, the market was relatively short, so colder weather and steady LNG demand triggered short-covering rather than fresh long positioning,” he continued. Hvalbye went on to state that, “on the supply side, there’s no disruption story”. “U.S. production remains strong, storage is still comfortable, and nothing suggests a sudden structural tightening from my data – i.e., a reason why the move looks tactical rather than fundamental,” he pointed out. Hvalbye highlighted to Rigzone that today’s price increase “isn’t a clean breakout”, adding that prices “are roughly back to where they were a week ago, so part of today’s move is simply retracing last week’s dip”. “In short: weather plus LNG demand plus positioning explain today’s strength. It’s a bounce, not a regime shift,” he added. In a separate exclusive interview with Rigzone on Monday, Art Hogan, Chief Market Strategist at B. Riley Wealth, said U.S. natural gas “is bouncing off a 13-week low of $3.10 last week after the weather outlook for late January shifted colder”. “The colder than normal outlook is expected to drive strong heating demand

An appraisal well has confirmed Vår Energi ASA’ Zagato oil discovery in the Goliat area on Norway’s side of the North Sea, with preliminary estimated recoverable resources of 21-25 million barrels of oil equivalent (MMboe), the Norwegian Offshore Directorate (NOD) said. That is equivalent to 3.3-11.9 million standard cubic meters of oil equivalent (MMscmoe), up from the previous estimate of 2.8-10.1 MMscmoe before appraisal well 7122/8-3 A was drilled, the upstream regulator said in a press release. The latest target represents the 14th exploration well drilled in production license 229, awarded under the Barents Sea Project in 1997, the NOD noted. Var Energi said separately, “The latest well tested two intervals with each showing maximum flow rates of more than 4,000 barrels of oil per day, confirming reservoir quality”. “The production tests confirmed good quality reservoirs and oil quality similar to the Goliat field”, Vår Energi said. Goliat, discovered 2000, started producing 2016 and expanded with the startup of the Snadd and Goliat West accumulations in 2017 and 2021 respectively, according to field information on government website Norskpetroleum.no. Operator Vår Energi (65 percent) and partner Equinor ASA (35 percent) have now drilled five wells in the Goliat Ridge, Vår Energi noted. “Including the latest well, the Goliat Ridge is estimated to contain gross discovered recoverable resources of 35-138 MMboe, and with additional prospective resources taking the total gross potential to over 200 MMboe”, it said. “A tie-back to the nearby Goliat FPSO [floating production, storage and offloading vessel] is being planned, targeting first production in 2019. “Vår Energi was recently awarded an adjacent license to the Goliat field in the 2025 Awards in Predefined Areas, which offers additional prospectivity on trend with the Goliat Ridge discovery”. Norskpetroleum.no says plans for Goliat include a connection to the Equinor-operated gas liquefaction facility on Melkøya island.   “The recent discoveries reinforce Vår Energi’s position as a leading exploration company on the Norwegian continental shelf and continue to strengthen our ability to sustain high-value production of

According to the U.S. Energy Information Administration’s (EIA) latest short term energy outlook (STEO) which was published on January 13, the West Texas Intermediate (WTI) spot price average will drop in 2026 and 2027. The EIA projected in this STEO that the WTI spot price will come in at $52.21 per barrel this year and $50.36 per barrel next year. The commodity averaged $65.40 per barrel in 2025, the EIA’s January STEO showed. A quarterly breakdown included in the outlook forecast that the WTI spot price will come in at $54.93 per barrel in the first quarter of 2026, $52.67 per barrel in the second quarter, $52.03 per barrel in the third quarter, $49.34 per barrel in the fourth quarter, $49.00 per barrel in the first quarter of 2027, $50.66 per barrel in the second quarter, $50.68 per barrel in the third quarter, and $51.00 per barrel in the fourth quarter of next year. In its previous STEO, which was released in December, the EIA projected that the WTI spot price would average $65.32 per barrel in 2025 and $51.42 per barrel in 2026. That STEO did not offer an average WTI spot price forecast for 2027. The EIA’s November STEO saw the WTI spot price averaging $65.15 per barrel in 2025 and $51.26 per barrel in 2026. A chart hosted on the EIA’s website, which was last updated on January 14 and displayed the annual average Cushing, OK, WTI spot price, on a free on board basis, from 1986 to 2025, showed that this commodity hit a peak in 2008, at $99.67 per barrel. The commodity saw its lowest price, between 1986 and 2025, in 1986, at $15.05 per barrel, the chart highlighted. The highest price the commodity has seen this decade came in 2022, at $94.90 per barrel,

Chevron Corp and its local partners have agreed on a $2.36-billion final investment decision (FID) for stage 1 of a project to raise production in the Leviathan natural gas and condensate field offshore Israel. Expected to start operation in the second half of 2029, the first stage of Phase 1B aims to increase capacity to about 21 billion cubic meters (741.61 billion cubic feet) a year, consortium member NewMed Energy LP said in a stock filing on Friday. On August 21, 2025, it said the Energy and Infrastructures Ministry had approved Phase 1B. Leviathan, discovered 2010 off the coast of Haifa city, went onstream December 2019 under Phase 1A, which has a capacity of about 12 Bcm per annum, according to NewMed Energy. Chevron upstream president Clay Neff said in a separate statement issued online by the United States energy giant, “Chevron is a leading energy player in the Eastern Mediterranean, where we are focused on natural gas production and exports”. “Our decision to invest in the expansion of Leviathan’s production capacity reflects our confidence in the future of energy in the region”, Neff added. Neff claimed, “Pragmatic U.S. and regional energy policies are helping to strengthen energy security across the Eastern Mediterranean and foster an environment that encourages investment in the Middle East and globally”. “This milestone demonstrates our ongoing commitment to partner with the state of Israel to develop natural gas resources and provide essential energy to millions of people in Israel, Egypt and Jordan”, said Jack Baker, Chevron managing director for the Eastern Mediterranean.  NewMed Energy’s regulatory disclosure said, “According to the development plan, Stage One of the Expansion Project includes the drilling and completion of three additional production wells, the addition of supplementary subsea systems and expansion of the processing systems on the platform, with the aim

The Philippines has discovered a new natural gas source for the first time in over a decade, extending the life of its depleting gas field as the nation seeks to cut its dependence on coal. The discovered reservoir in Malampaya East-1, near the existing Malampaya gas field, is estimated to contain around 98 billion cubic feet of gas, equivalent to almost 14 billion kilowatt hours of electricity per year, President Ferdinand Marcos Jr. said in a video message on Monday. “This helps Malampaya’s contribution and strengthens our domestic gas supply for many years to come,” Marcos said. Initial testing showed that the well flowed at 60 million cubic feet per day, indicating it has the potential to produce more and confirming it’s a rich resource comparable to the original Malampaya wells, he added. The latest gas find could help the Southeast Asian nation reduce its dependence on coal but it will need to continue importing liquefied natural gas to meet its growing energy needs.  Yet it pales in comparison with the massive gas assets in neighboring Indonesia and Malaysia, which are in the trillions of cubic feet. Malaysia’s state-owned gas company produces 7 billion cubic feet per day, while Indonesia’s oil firm has output at 2.8 billion cubic feet per day. Shares in Philippine energy firms climbed following the announcement. PXP Energy Corp. surged as much as 20.8 percent while Oriental Petroleum rose as much as 8.3 percent and First Gen Corp., which sources gas from Malampaya, jumped by up to 10.2 percent. The discovery could help secure long-term gas supply and eventually benefit companies like First Gen and San Miguel Corp., said Luis Limlingan, head of sales at Regina Capital Development Corp. in Manila. “But any real impact may take time as infrastructure and development need to catch up,” he said. Malampaya has