Dynagas LNG Partners LP on Thursday reported $38.89 million in revenue for the third quarter, down from $39.07 million for the same three-month period last year. The decrease brought down net profit adjusted for nonrecurring items from $14.48 million for Q3 2024 to $14.23 million, or $0.36 per share, for Q3 2025, the Athens-based owner and operator of liquefied natural gas (LNG) carriers said in its quarterly report. The revenue fall was driven by “the decrease of the daily hire rate of the Arctic Aurora in the three-month period ending September 30, 2025, and the decrease in revenue earning days of the Yenisei River due to unscheduled repairs”, Dynagas said. “The above decrease in voyage revenues was partially offset by the non-cash effect of the amortization of deferred revenues and the value of the EU ETS emissions allowances due to the Partnership by the charterers of its vessels”. Dynagas logged average daily hire gross of commissions of nearly $70,000 per day per vessel in Q3 2025, down from around $72,800 per day per vessel for Q3 2024. Its fleet, consisting of six carriers with a combined capacity of approximately 914,000 cubic meters (32.28 million cubic feet), had utilization rates of 99.1 percent and 100 percent in Q3 2025 and Q3 2024 respectively. “Our fleet-wide time charter equivalent of $67,094 per day comfortably exceeded our cash breakeven for the quarter of approximately $47,500, allowing us to continue generating stable free cash flow”, said chief executive Tony Lauritzen. While revenue dropped, net income grew from $15.05 million for Q3 2024 to $18.66 million for Q3 2025. This was “mainly attributable to the increase of other income from insurance claims for damages incurred in prior years, the decrease in net interest and finance costs… [and] the decrease in general and administrative expenses”, Dynagas said.

Russian oil giant Rosneft PJSC plans to pay the lowest interim dividends since the pandemic in 2020 as slumping crude prices, a stronger ruble and looming US sanctions bite. The board of directors of Russia’s largest state-controlled oil producer recommended to pay 11.56 rubles, $0.14, per share in interim dividends, according to a regulatory filing on Thursday.  The recommendation comes just a day before unprecedented US sanctions are due to hit Rosneft and fellow Russian oil giant Lukoil PJSC. President Donald Trump’s administration last month stepped up restrictions on Russia’s oil industry, which together with gas accounts for about a quarter of the nation’s coffers.  Rosneft’s earnings were already undermined by lower global oil prices amid fears of global surplus and much stronger ruble, with the appreciation of the nation’s currency meaning fewer rubles for each sold barrel. As a result, Rosneft’s net income shrank by 68% in the first half of the year from the same period in 2024.  Rosneft, responsible for over a third of the nation’s oil output, has been paying dividends to the state since 1999, and to other shareholders since 2006 when it began trading publicly. The producer started to pay interim dividends in 2017, distributing half of its profit to shareholders. It scrapped the payouts for the first half of 2020 after posting a loss for the period. Lukoil’s board of directors will discuss recommendations on interim dividends on Friday. The oil producer initially planned to discuss nine-month payouts on Oct. 23, but postponed after US announced sanctions against the company on Oct. 22. Some Lukoil units on Friday received extensions to sanctions waivers that the Trump administration imposed. WHAT DO YOU THINK? Generated by readers, the comments included herein do not reflect the views and opinions of Rigzone. All comments are subject to editorial review. Off-topic, inappropriate

Oil fell after Ukrainian President Volodymyr Zelenskiy said he agreed to work on a peace plan drafted by the US and Russia aimed at ending the war in Ukraine. West Texas Intermediate fell 0.5% to settle above $59 a barrel on Thursday, paring some losses from intraday lows following Zelenskiy’s comments. A peace deal, if followed by the elimination of sanctions on Russian oil over its invasion of Ukraine, could unleash supply from the world’s third-largest producer. Oil markets are already staring down expectations for a surplus as OPEC+ and other producers ramp up output, with the commodity heading for a yearly loss amid concerns of a glut. The flurry of renewed activity to end the war comes just hours before US sanctions targeting Russia’s two largest oil companies, Rosneft PJSC and Lukoil PJSC, are due to come into effect. Russia has consistently found a way to sell its sanctioned oil through so-called “shadow” channels. But Moscow’s oil revenue is expected to stagnate amid falling global crude prices, posing a risk to its budget and broader economy. Still, any accord remains far from certain. The US has signaled to Zelenskiy that he should accept the deal drawn up in consultation with Moscow, according to a person familiar. But the plan outlines known Russian demands for concessions that Kyiv has repeatedly said are unacceptable and that have so far hindered any breakthrough in efforts to reach a ceasefire. “Notably, Ukraine is reiterating its openness to discuss ending the war, what’s uncertain is Russia’s real interest in ending the war,” said Rachel Ziemba, an adjunct senior fellow at the Center for a New American Security. “It remains to be seen if Russia is interested in ending the war or just in buying time to reduce more extensive sanctions.” Earlier in the day,

Exxon Mobil Corp. lifted a force majeure on its Rovuma liquefied natural gas project in Mozambique as security concerns subside, a key step toward sanctioning the development and committing construction funds.  The force majeure was put in place after Islamic State-affiliated militants carried out an attack near its operations in northeastern Mozambique in 2021. Ending the force majeure will allow work to resume and is a crucial step toward Exxon making a final investment decision on the project, which is expected next year. TotalEnergies SE, which is building a separate $20 billion LNG plant nearby, ended its own suspension last month.  “We have lifted force majeure for the Rovuma LNG project,” an Exxon spokesman said. “We are working with our partners and the government of Mozambique to ensure the safety of our people and facilities, as we look to develop a world-class LNG project that can help drive economic growth.” The Exxon and TotalEnergies projects are expected to be online by the early 2030s — assuming no further delays — and will enable Mozambique to ship gas around the world for decades. They also promise to transform the country’s economy, one of the world’s poorest, into an energy-export powerhouse.  Mozambican President Daniel Chapo is keen to realize those promises and has worked in recent months with Rwandan troops to help secure the Cabo Delgado region. He called the area “relatively stable” in July and urged companies to resume work even if threats remain.  “If we’re waiting for Cabo Delgado to be a heaven, we won’t lift force majeure,” he said at the time.  Exxon used the delay to refine Rovuma’s design, envisioning it will produce as much as 18 million tons of gas annually, up from the original 15.2 million tons. Partners include China National Petroleum Corp. (CNPC), Abu Dhabi National Oil Co., Seoul’s

North America dropped two rigs week on week, according to Baker Hughes’ latest North America rotary rig count, which was published on November 14. The total U.S. rig count increased by one week on week and the total Canada rig count dropped by three during the same period, taking the total North America rig count down to 737, comprising 549 rigs from the U.S. and 188 rigs from Canada, the count outlined. Of the total U.S. rig count of 549, 527 rigs are categorized as land rigs, 19 are categorized as offshore rigs, and three are categorized as inland water rigs. The total U.S. rig count is made up of 417 oil rigs, 125 gas rigs, and seven miscellaneous rigs, according to Baker Hughes’ count, which revealed that the U.S. total comprises 476 horizontal rigs, 62 directional rigs, and 11 vertical rigs. Week on week, the U.S. offshore and land rig counts remained unchanged, and the country’s inland water rig count increased by one, Baker Hughes highlighted. The U.S. oil rig count increased by three, its gas rig count dropped by three, and its miscellaneous rig count increased by one, week on week, the count showed. The U.S. directional rig count increased by three and its horizontal rig count dropped by two week on week, while the country’s vertical rig count remained unchanged during the period, the count revealed. A major state variances subcategory included in the rig count showed that, week on week, New Mexico added two rigs, Louisiana added one rig, and North Dakota and Oklahoma each dropped one rig. A major basin variances subcategory included in the rig count showed that, week on week, the Permian basin added two rigs, the Cana Woodford basin dropped three rigs, and the Eagle Ford, Granite Wash and Williston basins each

In its latest short term energy outlook (STEO), which was released on November 12, the U.S. Energy Information Administration (EIA) increased its West Texas Intermediate (WTI) spot average price forecast for 2025 and 2026. According to this STEO, the EIA now sees the WTI spot price averaging $65.15 per barrel in 2025 and $51.26 per barrel in 2026. In its previous STEO, which was released in October, the EIA projected that the WTI spot price would average $65.00 per barrel in 2025 and $48.50 per barrel in 2026. The EIA’s September STEO forecast that the WTI spot price average would come in at $64.16 per barrel this year and $47.77 per barrel next year. A quarterly breakdown included in the EIA’s latest STEO projected that the WTI spot price will average $58.65 per barrel in the fourth quarter of 2025, $50.30 per barrel in the first quarter of next year, $50.68 per barrel in the second quarter, and $52.00 per barrel across the third and fourth quarters of 2026. The EIA’s October STEO saw the WTI spot price averaging $58.05 per barrel in the fourth quarter of next year, $47.97 per barrel in the first quarter of next year, $48.33 per barrel in the second quarter, $48.68 per barrel in the third quarter, and $49.00 per barrel in the fourth quarter of 2026. In its September STEO, the EIA projected that the WTI spot price would come in at $65.14 per barrel in the third quarter of 2025, $55.41 per barrel in the fourth quarter, $45.97 per barrel in the first quarter of next year, $46.33 per barrel in the second quarter, $48.68 per barrel in the third quarter, and $50.00 per barrel in the fourth quarter of 2026. The EIA’s latest STEO showed that the WTI spot price averaged