Oil and Gas News and Energy, Saturday, February 14, 2026: OPEC+ Leans Toward Production Increase from April, Oil Takes Defensive Stance
As of February 13, 2026 (exact time of the report unspecified), the global energy market has entered a phase of reassessment: expectations of renewed production increases by OPEC+ from April have intensified pressure on oil prices, while EIA statistics indicated a notable rise in oil inventories in the U.S. Simultaneously, the IEA maintains a cautious tone regarding demand in its February review and warns of the risk of oversupply in 2026. For investors in oil, gas, and energy, this shifts the focus toward the sustainability of refinery margins, product supply chains, and the quality of investments in electricity and renewable energy sources.
- Oil: Brent around $67/barrel, WTI around $62–63/barrel; the market is pricing in higher supply for the second quarter.
- Gas: TTF around €32/MWh; Europe enters the gas storage injection season with low inventories (exact figures as of February 13 unspecified).
- Electricity: prices for delivery on February 14 remain in three-digit levels in some regions — network investments and connection rules become key drivers for renewable energy sources.
Oil Market: OPEC+, Demand and Expectations for 2026
A key story on the day for oil revolves around discussions within OPEC+ about returning to production increases starting in April 2026 after a pause from January to March. The market interprets this as an effort to "lock in" market share ahead of summer demand, even though the balance for the second quarter appears softer than seasonal norms. Additionally, the IEA's February report estimates global demand growth in 2026 at around 850,000 barrels per day, while global supply is projected to increase by approximately 2.4 million barrels per day in 2026. This raises price sensitivity to actual export flows and quota compliance, which is critical for hedging strategies and investment in production.
For upstream investments, this indicates higher requirements for cost efficiency and cash flow stability. "Long" projects are evaluated more stringently, and the market increasingly favors companies with strong free cash flow and predictable capital policies. Geopolitical factors (Middle East) remain a source of volatility, but their contribution to prices as of February 13, 2026, remains unspecified.
Price Indicators for February 13-14
- Brent Oil: around $67/barrel.
- WTI Oil: around $62–63/barrel.
- TTF Gas (Europe): around €32/MWh.
- Henry Hub Gas (USA): around $3.17/MMBtu.
- JKM LNG (Asia): around $11/MMBtu.
- Newcastle Coal: around $115–116/ton.
- Electricity (Nord Pool, delivery February 14): Germany ~€103.5/MWh; Netherlands ~€95/MWh; France ~€34/MWh; other regions — unspecified.
- EU ETS (carbon): around €73/t CO₂ as of February 12; as of February 13 — unspecified.
USA: Inventories, Refineries, and Signals for Oil Products
U.S. EIA statistics set the tone for discussions on the "physicals" of the market. For the week ending February 6, commercial oil inventories increased by 8.5 million barrels to 428.8 million barrels. Refineries processed approximately 16.0 million barrels per day, with a utilization rate of about 89%. Meanwhile, gasoline inventories rose by 1.2 million barrels, while distillate stocks fell by 2.7 million barrels.
For the "oil products" segment, this indicates a divergent balance: with comfortable oil inventories, the market may face local tension concerning diesel and jet fuel, especially if seasonal weather elevates demand. This is significant for investors because refinery margins and the export of oil products from the U.S. to Europe often act as a "buffer" for the global fuel market.
Refineries and Oil Products: Operational Events and Market Impact
Operational risks in refining are back in focus. In Russia, sources indicate that the Volgograd Refinery halted operations after a fire caused by a drone attack; a major primary processing unit was damaged. While this has an indirect impact on the global oil market, such events increase risk premiums for the regional balance of oil products (primarily diesel), heighten import demand, and may support margins for European refineries.
In Europe, sanction compliance is altering even operational models: TotalEnergies has taken full operational control of the Zeeland refinery in the Netherlands while retaining a stake for Lukoil, concentrating raw material procurement and oil product sales under one management framework. In Africa, a significant signal from Nigeria: Dangote has resumed operations at a large atmospheric distillation unit, with a test launch of the gasoline block expected in the coming days — potentially boosting the substitution of oil products in the region and altering regional demand for oil.
Gas and LNG: Europe Between Underground Storage and New Supply Regimes
The gas market in Europe remains sensitive to storage levels and competition for LNG. TTF holds around €32/MWh, but for investors, the trajectory of underground storage injections is more critical: public estimates suggest that European storage is around 35–36% full (exact figure as of February 13, 2026 — unspecified). Additionally, the EU has approved a phased ban on the import of Russian gas by the end of 2027 (LNG — earlier), solidifying Europe's structural dependence on the global LNG market and enhancing the value of flexible supply.
In Asia, the JKM marker at around $11/MMBtu indicates relatively calm demand, but supply depends on the schedules of mega-projects. Reports indicate that the launch of the first phase of Qatar's LNG capacity expansion has been shifted to the end of 2026. This situation supports a premium for "ready molecules" in European and Asian markets and emphasizes the importance of investments in regasification, gas infrastructure, and electricity flexibility.
Electricity and Renewables: Prices, Networks, and Investment Cycles
As of February 14, electricity prices in Europe, according to Nord Pool, remain heterogeneous: Germany around €103.5/MWh, Netherlands around €95/MWh, France around €34/MWh. The disparity is explained by the generation structure (nuclear, gas, renewables), inter-system connectivity, and network limitations. The investment cycle in the energy sector increasingly focuses on infrastructure: in the UK, record solar generation subsidy contracts have been issued, while the dispute between London and Paris over financing additional interconnection cables highlights how network projects are becoming a political factor in renewable energy deployment.
On the continent, the "network cost" is increasing: in Germany, a mechanism is being discussed where renewable energy developers will bear more of the costs associated with connecting to the power grids. For renewable projects, this may entail a reassessment of internal rate of return (IRR) and more precise site selection. France bets on the growth of decarbonized electricity (nuclear and renewables) and encourages electrification of demand, thereby enhancing structural demand for investments in networks and flexibility (storage, demand management).
Coal: Price Benchmarking, Asia, and Carbon Risks
Coal remains a "hedging" resource in global energy markets, particularly in Asia. Newcastle is holding steady around $115–116/ton, maintaining significance for marginal electricity generation and portfolio hedging. In Europe, the role of coal is shaped by the cost of CO₂ and the energy system regime: sharp movements in the price of EU ETS temporarily alter the economics of coal generation but do not alleviate long-term restrictions on financing coal assets and projects.
Regulation, Sanctions, and Outlook
Regulatory and sanction risks continue to be systemic within the energy sector. In Europe, instability in CO₂ pricing increases uncertainty for investments in decarbonization, while changes in the sanction regimes within the oil and gas sector can rapidly redistribute oil flows and feedstock to refineries (including Venezuelan avenues). For the coming days, the baseline scenario for oil is consolidation within the $65–70 range for Brent amid the prevailing theme of OPEC+ supply.
Scenarios for the Coming Days:
- Base Case: oil within range, gas — influenced by weather and underground storage dynamics, electricity — affected by network limitations.
- Upside Risk: infrastructure disruptions and tightening sanctions elevate risk premiums for oil and diesel, supporting refinery margins and prices for oil products.
- Downside Risk: accelerated expectations for production increases and rising availability of heavy oil apply downward pressure on oil and upstream investments.
Checklist for Energy Market Participants:
- OPEC+ communications ahead of the meeting on March 1;
- Weekly EIA data for oil, gas, and oil products;
- Trends in European underground storage and competitive landscape in the LNG market (as of February 13 — unspecified);
- Updates on refineries (maintenance, incidents) and oil product supply chains;
- Decisions on networks, interconnectors, and carbon impacting electricity and renewables.
