Oil and Gas News and Energy as of July 26, 2026: Brent Retreats to $97 After Breaking $100, TTF Gas Above €63/MWh, KTK Suspension, Gasoline Export Ban in Russia Until Year-End, Newcastle Coal, Electricity, and Renewables: A Review for Investors and Energy Market Participants
The global fuel and energy complex concludes the third decade of July in a state of heightened volatility. Brent crude oil prices, which breached the $100 per barrel mark for the first time in nearly two months on Thursday, retraced some of the gains on Friday, returning to $97; nevertheless, the commodity sector still gained over 10% for the week. European gas prices at the TTF hub remained above €63/MWh, marking the highest level since January 2023. Against this backdrop, the main corporate-regulatory news of the weekend was the decision by Russian authorities to extend the full ban on gasoline exports until the end of 2026. Below is a detailed overview of key developments in the oil and gas, coal, and electricity sectors for investors, fuel and oil companies, and energy market participants.
Main Highlights by Sunday Morning, July 26, 2026
- Oil: Brent reached a two-month peak around $102 on Thursday and closed above $100, while on Friday it corrected by about 4% to $97 per barrel. WTI gave back around half of its six percent growth and is trading near $88-$89.
- Dynamics: Over the month, Brent added approximately 30%, and over the year—more than 40%. The weekly result reflects a plus of 10-12%.
- Gas: TTF futures surged above €63/MWh— a record high since January 2023; marking over 45% growth since the beginning of July and nearly a double-year-on-year increase.
- Logistics: Shipments from the Caspian Pipeline Consortium in Novorossiysk have been halted, and Kazakhstan has reduced its production.
- Russia: The gasoline export ban has been extended until the end of the year; restrictions on diesel will be lifted as the market recovers.
- Coal: Newcastle coal is holding steady around $130 per ton amid subdued demand from India.
- Electricity: A contract between OpenAI and Georgia Power for 3.2 GW solidifies data centers as a new driver of electricity demand.
Oil Market: Risk Premium Recognized, But Not Maintained
The oil market has traded on military reports rather than the supply-demand balance for the fifth week in a row. The breakout above $100 for Brent occurred following attacks by Houthi militants on two Saudi tankers in the Red Sea—a development that expanded the risk zone beyond the Strait of Hormuz and called alternative Saudi export routes into question. The Friday correction is explained simply: oil continues to flow through Middle Eastern routes, some tankers are navigating with their transponders turned off, and technical indicators of overbuying demanded a pause after the fastest monthly rally since 2022.
Factors Supporting Price Levels
- Restricted pass through the Strait of Hormuz, which traditionally accounts for about one-fifth of maritime oil trade.
- Threat to Red Sea ports: Riyadh warned on Saturday about potential dangers near Yanbu—a terminal capable of shipping millions of barrels per day.
- Suspension of Kazakh exports via KTK, removing over 1% of global supply from the market.
- Increased freight and insurance rates, which are being passed on to refinery purchase prices.
- Extended delivery routes: Asian buyers are exploring transport of Saudi oil through the Suez Canal and around Africa.
Factors Amid Restraint
- The US-Iran negotiation track is formally unbroken: both sides confirm ongoing contacts mediated by Oman and Pakistan.
- China's interest in de-escalation: disruptions in the Persian Gulf are impacting the largest oil importer in the world.
- Unused capacities from OPEC+ and the ongoing recovery of quotas.
Geopolitics: Dispute Over Passage Rules Through Hormuz
The key story of the weekend is legal, not military. Tehran stated that Washington is attempting to unilaterally open a new transit corridor through the Strait of Hormuz bypassing Iranian procedures and regards this as a violation of the June memorandum of understanding. The US insists that Iran does not control the strait, while military forces confirm that shipping is maintained by escorting forces. Simultaneously, the American side conducted the thirteenth consecutive night of strikes on Iranian infrastructure and threatened a "stern military response" to new attacks on vessels in the Red Sea. For the market, this means one thing: the premium for geopolitical risk in oil and gas prices will remain until a functioning transit mechanism is established rather than until a formal ceasefire is reached.
OPEC+: Meeting on August 2 as the Main Planned Trigger
The alliance continues a phased recovery of production: on July 5, seven countries—Saudi Arabia, Russia, Iraq, Kuwait, Kazakhstan, Algeria, and Oman—agreed on an increase of 188,000 barrels per day for August. The next meeting is scheduled for August 2 and will occur in an entirely different price reality than the previous one. OPEC+'s main challenge today is not in quotas, but rather in the fact that significant portions of reserve capacities are physically located in the Persian Gulf and depend on the Strait of Hormuz. The UAE's exit from the alliance as of May 1, 2026 has further narrowed the managed pool of supply, and the criteria for assessing maximum capacities will form the basis for the quotas in 2027—an additional source of internal disagreements.
Gas Market: TTF at Highs, Winter Risk for Europe Grows
European gas has become the second epicenter of the crisis. The TTF increase of more than 45% since the beginning of July has been driven by a combination of structural factors: a reduction in Qatari LNG supplies following damage to facilities in Ras Laffan, a redirection of Atlantic cargoes to premium Asia, an abnormal heatwave in Europe increasing demand for electricity for air conditioning, and soaring freight costs. The largest gas supplier in the region has warned that the EU is unlikely to meet the target of 80% storage capacity ahead of the heating season. The lag in injection rates compared to the five-year average makes the winter of 2026–2027 a primary risk for European industry and energy, with the window for accelerated filling narrowing: seasonal demand growth starts as early as the end of September.
KTK and Kazakhstan: Logistics as the Bottleneck for Exports
The Caspian Pipeline Consortium has suspended loading at the marine terminal near Novorossiysk following a series of drone attacks on tankers. Since July 21, Kazakhstan has halted the flow of crude to the system: shipowners are refusing to approach offshore mooring facilities, with some tankers waiting in line. The Ministry of Energy of the Republic has confirmed a "controlled adjustment" of daily production to prevent overflow of storage facilities. KTK provides more than 80% of Kazakhstan's oil exports and connects the Tengiz and Kashagan fields, developed by Chevron, ExxonMobil, and Shell, with the Black Sea. For European refineries oriented towards the light low-sulfur grade CPC Blend, this means an urgent search for replacement batches in an already tight market.
Russia: Gasoline Export Ban Extended Until the End of 2026
The main decision of the outgoing week for the Russian oil products market was announced on July 25: the full ban on gasoline exports is extended until the end of the current year and applies to both producers and non-producers. Restrictions on diesel fuel are planned to be lifted gradually as the market recovers. The regime that was set to last until July 31 is now transforming from a seasonal measure into a half-year long one.
The context of the decision reflects a highly challenging summer for the industry in recent years:
- The volume of oil refining in June dropped to approximately 4.1 million barrels per day—a low for recent years—due to damage to refineries;
- Attacks on plants continue: in late July, facilities in the Ulyanovsk region were affected, previously in Omsk and Saratov;
- The regulatory mandate for mandatory exchange sales of Euro-5 gasoline has been reduced from 15% to 10% for the period until September 30;
- The import duty has been nullified, and the import of oil products is being increased;
- Marine shipments of oil products in June set a historical minimum.
Relevant agencies report a gradual improvement in fuel supply in several regions and a transition to a "targeted" mode of managing shortages. Priorities remain unchanged: harvesting campaigns, northern supplies, and ensuring supplies to Siberian regions. For oil companies, the extension of the embargo means predictable but prolonged compression of export margins and the necessity to maintain high internal sales loads until the end of the year.
Coal: A Quiet Haven with Limited Upside
The coal market remains a beneficiary of the LNG shortage but without any frenzy. Australian energy coal Newcastle 6000 kcal is trading around $130 per ton—not far from the lows since early March: subdued purchases from India, which has increased its own production and reserves, are offsetting rising demand in Northeast Asia. Japan remains a leader in increasing coal generation amid declining gas use, while South Korea has sharply increased imports. Industry estimates indicate additional demand in the APEC region for 2026 at around 70 million tons, potentially escalating to 90 million tons. Notably, major mining companies are not sanctioning new projects: the market perceives the upswing as cyclic rather than structural.
Electricity and Renewables: Demand Growing Faster Than Supply Capacity
The energy shock has not slowed down the energy transition but has accelerated it. Global electricity demand is projected to increase by 3.6% in 2026 and by another 3.8% in 2027, while renewable generation will surpass coal for the first time in history on a global scale; the share of renewables in global generation is moving from 33% to 37%. The drivers remain unchanged: industry, electric transport, air conditioning, and data centers.
The latter factor is no longer an abstraction. The 25-year contract announced this week between OpenAI and Georgia Power encompasses the supply of up to 3.2 GW for a data center in Georgia, with capacity commissioning occurring from 2028 to 2032, involving investments of at least $20 billion and an option for managed load reduction down to 1 GW. This stands as one of the largest single capacity commitments in the history of American technological infrastructure and is a clear illustration of why electricity is becoming an independent investment class alongside oil and gas.
Implications for Investors and Energy Market Participants
- Hedging is essential. Movements of 4-7% per session make unhedged positions in oil, gas, and petroleum products a source of unacceptable risk.
- Refinery margins are under pressure from both sides. Expensive raw materials amid administrative export restrictions and retail prices compress refinery crack spreads.
- Logistics are more important than geology. The Strait of Hormuz, Bab-el-Mandeb, and Novorossiysk have shown that the price of a barrel is determined by the passability of bottlenecks.
- Premium for predictability. Coal, nuclear, and assets with long contract horizons are being repriced upwards.
- Winter risk in Europe is not alleviated. Lagging gas storage filling poses potential for a new surge in TTF in the fourth quarter.
The upcoming week’s calendar sets four focal points: the OPEC+ meeting on August 2, statistics on the filling of European storage facilities, the progress of negotiations on shipping regimes in the Strait of Hormuz, and the quarterly reporting block of the largest oil and gas companies. Any of these events could shift prices by $5-10 per barrel within a single session. The baseline scenario for oil, gas, and energy over the coming months is sustained elevated volatility at least until the end of the third quarter of 2026.
