Rompetrol Rafinare SA—jointly owned by Kazakhstan’s state-owned JSC NC KazMunayGas (KMG) subsidiary KMG International NV (54.63%) and Romania’s Ministry of Economy, Energy & Business Environment (44.7%)—is advancing a project involving installation of a 9.4-Mw photovoltaic plant at its 5-million tonne/year (tpy) Petromidia refinery in Năvodari, Constanța County, on Romania’s Black Sea coast. Designed to generate more than 9,800 Mw-hr/year of electricity for direct use by the refinery, the project aims to reduce greenhouse gas (GHG) emissions at the site by about 6,024 tpy, Rompetrol Rafinare said in a release Oct. 8. Budgeted at an overall investment of about $9.2 million—including about $2.9 million in nonrefundable modernization fund support and a $6.3-million company contribution—the project is targeted for completion by Dec. 31, 2028, under the funding call deadline. Petromidia’s solar project will complement the site’s 80-Mw cogeneration plant—operated by Kazakh-Romanian Energy Investment Fund (KREIF) subsidiary Rompetrol Energy SA—which entered commercial operation at the end of 2025 and supplies the refinery’s electricity and process steam requirements. Rompetrol reported a 98.11% capacity utilization rate at Petromidia in first-half 2026. The refinery also recorded an 86.54% white-product yield and a 92-point Energy Intensity Index during the first 6 months of 2026, according to the Oct. 8 announcement. Vega project adds battery storage Announcement of the proposed project at Petromidia follows Rompetrol Rafinare’s Aug. 21 confirmation of a separate solar-and-storage project at its Vega Ploieşti niche refinery—specialized in the production of solvents, hexane, and the only Romanian-produced bitumen—in Ploiesti, Prahova County, Romania, about 60 km from Bucharest. The planned Vega installation will combine 4.8 Mw of photovoltaic capacity with a 9-Mw-hr energy storage system. It is expected to produce more than 6,200 Mw-hr/year, equivalent to about two-thirds of the refinery’s budgeted 2025 electricity use. The battery-based storage component of the project is intended to help

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The acquisition continues a rapid buildout of Crescent’s Eagle Ford position, where the company has completed nine acquisitions since June 2023. Following closing, Crescent expects total production of about 400,000 boe/d, including roughly 170,000 b/d of oil. Management said the value proposition centers on operational improvements rather than a material increase in activity levels. Operations upside Asked whether Crescent planned to maintain Devon’s current 2-3-rig development program, Rockecharlie said the company expects to keep activity at roughly the same pace. By folding the assets into the company, he said, “we see significant capital allocation flexibility,” he said. “We think we’re going to deliver effectively the same production with less capital, just more capital efficiency, which is greater free cash flow for investors.” Crescent expects to realize about $140 million in annual synergies, fully captured by the end of 2027, across drilling and completions, lease operating expenses, and marketing. Management said most of those gains are expected to come from drilling and completion efficiencies, including longer laterals and improved surface designs. “Across our five most recent acquisitions, we’ve increased average lateral length by more than 25% versus previous operators, driving a step change in cost structure, increasing returns, and lowering breakevens,” Rynd said.  “Most of this is pretty simple and pretty straightforward… increasing lateral lengths and taking advantage of scale,” said chief operating officer Joey Hall. Calling the acreage a familiar operating area, Hall added: “This is our backyard. We understand these assets. We’ve had line of sight into them for over 10 years.” Hall expanded on the opportunity presented. “Going from an average of 6,500 ft to 11,500 ft, that’s a step change in cost structure. We’ve been doing this across our acreage, so we’re confident we can execute on it and [we’re] looking forward to hitting that target.” Rockecharlie

Oil prices surged about 5% on Thursday, Oct. 8, as renewed attacks on commercial vessels in the Middle East and hurricane-related production shutdowns in the US Gulf of Mexico raised concerns about near-term crude supply. Oil prices rose sharply in early Thursday trading, with Brent crude climbing 5% to above $105/bbl and US West Texas Intermediate (WTI) also posting strong gains. Both benchmarks later eased a bit from their session highs. The advance reflected growing supply risks in two major producing regions. In the Middle East, renewed attacks on commercial vessels have disrupted a recovery in tanker traffic through the Strait of Hormuz. Meanwhile, offshore operators in the US Gulf of Mexico have shut in production and evacuated personnel ahead of Hurricane Isaias. Shipping disruptions intensify Security conditions in the Persian Gulf have deteriorated in recent days, with attacks reported near Qatar, Oman, and the Strait of Hormuz, renewing concerns about the reliability of the shipping corridor. According to the Financial Times, oil flows through the strait had recovered to nearly 90% of prewar levels in late September before declining again as attacks intensified. Transit volumes subsequently fell to about 11 million b/d, with flows estimated at roughly 4 million b/d on Tuesday, Oct. 6. The renewed disruptions threaten to reverse recent improvements in regional crude exports and prolong uncertainty over Middle Eastern oil supplies. Uncertainty surrounding the US-Iran conflict has added to market concerns. Axios reported that the Pentagon had ordered preparations for potential large-scale military operations against Iran. However, President Donald Trump said Thursday that the US would not resume military strikes against Iran before the Nov. 3 midterm elections, as diplomatic discussions continued. US Gulf production curtailed ahead of hurricane In the US, offshore producers have curtailed operations as Hurricane Isaias approaches the northern Gulf Coast. According

Global LNG markets are entering winter with limited supply cushion, even as a growing carrier fleet and shorter Atlantic voyages keep shipping rates subdued. Meanwhile China is showing signs of returning to long-term US contracting. New liquefaction capacity and higher utilization outside Qatar and the UAE have offset about 60% of Middle East LNG supply losses since March, according to a recent analysis from Morgan Stanley. Weaker demand outside Europe and European storage withdrawals have helped offset the remaining supply loss, but left inventories unusually low heading into winter. EU storage was about 70% full in late September, compared with 82% a year earlier and a 10-year average of 87%. Morgan Stanley raised its fourth-quarter JKM forecast to $27.50/MMbtu from $25/MMbtu, citing a slower Qatari restart and continued winter upside risk. Europe is drawing more flexible US supply. About 57% of US LNG exports were headed to Europe in September, up from 53% in August, while US feedgas rose about 6% month over month as Freeport recovered from an outage. Strong European demand is supporting vessel demand, but shorter US-Europe voyages and rapid fleet growth are more than offsetting that pressure. Atlantic spot rates for modern two-stroke LNG carriers stood at about $25,750/day on Oct. 6, while Pacific rates were about $39,000/day, according to Spark Commodities data. About 55 new LNG carriers were delivered in the first 7 months of 2026, with more expected by yearend. Morgan Stanley similarly noted that Asia LNG carrier rates had fallen about 80% from early-March highs and returned near pre-conflict levels, although route costs remain above levels immediately before the conflict. Meantime, the investment bank expects more than 30 million tpy of non-Middle East capacity to start by end-2027, before additional volumes from Qatar’s North Field expansion. China contracting returns China is adding another

US crude oil inventories for the week ended Oct. 2, excluding the Strategic Petroleum Reserve, decreased by 3.2 million bbl from the previous week, according to data from the US Energy Information Administration (EIA). At 424.1 million bbl, US crude oil inventories are 1% above the 5-year average for this time of year, the EIA report indicated. Gasoline inventories increased 0.4 million bbl, 6% below the 5-year average. Propane-propylene inventories decreased 1.8 million bbl, 18% above the 5-year average. Total commercial petroleum inventories decreased by 6.9 million bbl for the week. Distillate inventories remained unchanged, 12% below the 5-year average. US crude oil refinery inputs averaged 16.5 million b/d for the week ended Oct. 2, which was 223,000 b/d more than the previous week’s average. Refineries operated at 92.7% of capacity. Gasoline output averaged 9.3 million b/d, and distillate production increased to 5.3 million b/d. Crude oil imports increased 1.1 million b/d to 6.8 million b/d. The 4-week average of 6.4 million b/d is 4.3% above the year-ago level. Gasoline imports averaged 512,000 b/d; distillate imports averaged 118,000 b/d. Over the past four weeks, total product supplied averaged 21.1 million b/d, up 0.7% year over year. The 4-week average for gasoline product supplied dereased 0.3% year over year to 8.8 million b/d, while the 4-week average for distillate product supplied decreased 1.6% to 3.8 million b/d. The 4-week average for jet fuel product supplied increased 6.0% year over year.