Market Overview of Energy Sector July 23, 2026: Brent and WTI Quotes, TTF Gas, OPEC+ Quotas, Refineries, Renewables, and Coal

Oil and Gas and Energy News as of July 23, 2026: Brent Over $94 Amid Hormuz Strait Blockade, TTF Gas Exceeds €60/MWh, OPEC+ Quotas for August, Stabilization of the Russian Fuel Market, LNG, Refineries, Electricity, Renewable Energy, and Coal. An Overview for Investors and Energy Market Participants

The global energy market enters late July 2026 in a state not seen by traders since spring: the geopolitical risk premium has returned to prices in full force. The escalation of the conflict between the U.S. and Iran, the effective halt of shipping through the Hormuz Strait, and the maritime embargo by the Houthis against Saudi Arabia have pushed Brent crude above $94 per barrel—its highest level in six weeks. European gas at the TTF hub has surpassed €60 per MWh for the first time since March, while injections into underground storage lag behind last year's schedule. Against this backdrop, OPEC+ maintains a cautious strategy for increasing quotas, the Russian fuel market is gradually emerging from a critical gasoline shortage phase, and the global energy transition is facing a new reality: expensive LNG is bringing coal back into the energy balance in Asia. Below is a detailed overview of key events in the oil, gas, electricity, coal, and raw materials markets for investors and energy market participants.

Oil Market: Geopolitical Premium Returns to Prices

Oil prices are demonstrating the most aggressive upward movement since early summer. On July 22, the price of the September futures for Brent crude on the London ICE exchange rose by more than 3%, reaching $94.14 per barrel for the first time since June 11. American WTI also climbed over 3%, heading towards $87 per barrel. For comparison, Brent was trading below $71 on July 2 and around $80.5 in mid-June. Thus, over the past three weeks, the market has regained more than 30% of its value.

Key drivers of the current oil market rally:

• Blockade of the Hormuz Strait. Shipping traffic data indicates that on certain days last week, not a single vessel crossed the Strait, through which about one-fifth of the world's maritime oil trade passes, alongside a significant share of LNG.
• Direct attacks on the tanker fleet. Incidents have been reported involving fires and immobilizations of oil tankers attempting to pass via the southern route, as well as a case where the crew was forced to abandon their ship.
• Houthi maritime embargo. Yemeni forces announced a blockade of supplies from Saudi Arabia, threatening export flows from the largest OPEC producer.
• Expansion of the conflict front. The U.S. is increasing its military presence in the region by deploying additional aircraft to bases in Israel; the market is pricing in the risk of Washington’s full-scale involvement in the conflict.
• Decreasing inventories. The IEA reports a decline in global commercial oil stocks, enhancing price sensitivity to any supply disruptions.

What This Means for Investors

The widening Brent-WTI spread to $7–9 per barrel is a classic indicator that the market is pricing in the risk of disruptions specifically in Middle Eastern logistics, rather than a global supply shortage per se. For oil companies with a diversified resource base outside the Persian Gulf, this means a temporary expansion of margins. For oil traders and fuel companies, this leads to a sharp increase in freight and insurance rates, which are already eroding part of the price gain.

OPEC+: Cautious Quota Increase Instead of Price War

The OPEC+ alliance is maintaining a conservative stance. Following a video conference on July 5, seven countries voluntarily reducing production beyond the general quotas—Saudi Arabia, Russia, Iraq, Kuwait, Kazakhstan, Algeria, and Oman—agreed to increase quotas for August by 188,000 barrels per day. The total alliance quota for August will amount to 36.019 million barrels per day. Saudi Arabia and Russia each receive an additional 62,000 barrels per day.

Key parameters of the agreement at this time:

1. From February to August 2026, the cumulative quota has increased by approximately 940,000 barrels per day—a volume comparable to the production of a medium-sized participating country.
2. The "Seven" is returning market limits totaling 1.65 million barrels per day, considering the share of the UAE, which left the alliance in May due to dissatisfaction with quota distribution.
3. To fully unwind voluntary restrictions, September quotas must be raised by another 188,000 barrels per day. The next meeting is scheduled for August 2.
4. Iraq has publicly indicated a potential exit from the agreement if its production limit is not raised—a factor highlighting the alliance's internal fragility.

The dilemma facing OPEC+ in the second half of the year is clear: analysts predict a return of structural supply surplus following the normalization of the situation in the Persian Gulf. The alliance will need to choose between curbing production for price stability and battling for market share. So far, the current geopolitical premium masks this choice.

Gas Market: Europe Pays a Premium and Lags Behind Injection Schedule

The European gas market is under dual pressure. Prices at the Dutch TTF hub surpassed €60 per MWh for the first time since mid-March on July 20, subsequently adjusting to €59 on Tuesday. In dollar terms, this price approached $700 per thousand cubic meters. Since early July, the European gas benchmark has increased by approximately 35%, while the Asian JKM Platts index has risen by around 25%.

The primary issue for the European Union is not just the price but the pace of filling underground gas storage:

• The 2025–2026 heating season ended with extremely low reserves: as of April 1, storage facilities were filled to 27.66%—13.4 percentage points below the average level over the previous five years.
• By July 19, storage levels reached only 53.7%, which is 15.7 percentage points below the five-year average. The gap is not narrowing, but rather expanding.
• Daily injections in July dropped to 270 million cubic meters compared to 308 million in June. A year ago, mid-summer daily replenishment averaged 338 million cubic meters—about a quarter more.
• The competition for LNG cargoes is shifting in favor of Asia, where liquefied gas is needed for current consumption rather than for replenishing reserves.

Risk Scenario for Autumn

Industry experts do not expect a repeat of the 2022–2023 peaks; however, they concede that if the conflict in the Persian Gulf persists, prices could exceed $1,000 per thousand cubic meters. An additional risk factor is the anticipated peak of El Niño in December, which could alter the heating season profile. For the European industry, energy sector, and fertilizer producers, this indicates a need for hedging already now.

LNG: Record Wave of New Capacities on the 2026–2028 Horizon

Despite the current tension, the mid-term picture of the liquefied natural gas market looks fundamentally different. According to the IEA, the global LNG market expects the largest capacity increase in history from 2026 to 2028. Projects in the U.S., Qatar, Canada, and several other jurisdictions are nearing completion. Investments in LNG infrastructure are on a stable upward trajectory—unlike investments in oil production, where a first annual decline of about 6% has been recorded since 2020, primarily due to expenditure reductions in the U.S. shale industry.

A practical conclusion for market participants: the current price spike is predominantly logistical and geopolitical in nature. Structurally, the gas market is heading towards a supply surplus in the second half of the decade, creating an asymmetry between spot prices and long-term contract expectations.

Gas Demand: IEA Predicts Decline in 2026

The International Energy Agency has revised its forecast for global natural gas demand downward. The regional picture appears mixed:

• Asia: Demand is expected to decrease by approximately 0.5%. Expensive LNG is prompting a reversal to coal generation and reducing activity in energy-intensive industries.
• Middle East: The sharpest drop—around 4%—is due to the direct impact of the conflict on infrastructure and production.
• Eurasia: A growth of about 3% is anticipated.
• Central and South America: An increase of around 3% is expected amid declining hydroelectric generation.

The price elasticity of gas demand has proven to be higher than expected: with high prices, consumers in developing economies are quickly reverting to coal. This is a key factor limiting the ceiling on gas prices even in conditions of geopolitical stress.

Russian Fuel Market: Emerging from Acute Fuel Crisis Phase

The domestic fuel market in Russia is experiencing one of the most challenging periods in recent years. The cause is the decrease in primary processing: in June and July, several major enterprises, including the Omsk and Saratov refineries, as well as the NORSI complex, suspended or limited their operations amid infrastructure damage and unscheduled shutdowns.

Consequences for the fuel market:

1. Wholesale market prices for diesel fuel on the SPbMTSB exceeded historical highs, with trading volumes for AI-95 dropping to as low as 43% during certain periods.
2. A number of regions implemented restrictions on fuel sales, including an "odd-even" scheme; in resort regions such as Krasnodar Krai, Crimea, and the Caucasus, seasonal demand exacerbated the imbalance.
3. Retail prices at major gas station chains were held within inflation limits, whereas independent stations saw prices rise significantly above that.

Regulator Measures and Early Signs of Stabilization

• Export Ban: The export of gasoline and diesel fuel is prohibited until July 31, with extension discussions underway.
• Exchange Sale Norm: The mandatory share of sales through the exchange has been reduced from 15% to 10% to enhance flexibility in direct deliveries.
• Import Substitution: Belarus has redirected gasoline volumes to the Russian market—historical maximum imports reached 141,000 tons from June 1–25. Kazakhstan, processing 15–17 million tons of oil per year, is also being considered as a potential supplier.
• Resumption of Exchange Sales: Some refineries have returned to selling fuel on the exchange, wholesale trading volumes are growing, unmet demand is decreasing, and the situation at several gas stations is stabilizing.

The priority for ensuring the domestic market remains at the level of the profile Deputy Prime Minister. Official estimates suggest a normalization by August as repairs at refineries conclude. Industry experts are more cautious and anticipate possible delays in the timeline, while noting that the supply restriction is temporary: a price reduction is possible in two to three months post resolution of processing issues.

Electric Power and Renewables: Record Investments Amid Growing Flexibility Requirements

The global electricity sector is undergoing structural transformation. Total global investment in energy exceeded $3.3 trillion, with investments in clean technologies—renewable energy, grids, storage, and nuclear generation—doubling those in fossil fuels, which accounted for about $1.1 trillion. Solar photovoltaic energy is attracting more capital than any other technological domain within the energy sector. Investments in the energy transition reached $2.3 trillion in 2025.

Key trends in electricity:

• Renewables and nuclear outpace coal in the global energy generation balance—a turning point confirmed by IEA forecasts.
• Data Centers as a New Demand Driver: In North America, electricity consumption is growing by about 2%, predominantly due to computational infrastructure and AI workloads.
• Asia Sets the Pace: India is showing a demand growth of around 6.6%—the largest contribution to global dynamics.
• Nuclear Renaissance: More than a hundred reactors in France and the U.S. are providing record volumes of nuclear generation, and Japan is gradually returning previously shut-down units to operation.
• Flexibility Shortfall: The growing share of variable generation demands proactive investments in energy storage systems and network upgrades—without which reliability of supply decreases.

Coal: Fuel of Last Resort Returns to the Game

Despite the long-term trend toward decarbonization, the coal market has received short-term support from the gas crisis. The mechanism is straightforward: expensive LNG in Asia makes coal generation economically preferable, as confirmed by decreased regional gas demand. Developing economies in the Asia-Pacific region continue to rely on coal as a tool for providing baseload load and energy security.

For investors, this creates a characteristic asymmetry: coal assets demonstrate strong cash flows during periods of energy stress but remain under structural pressure from climate regulation and capital costs. The largest exporters—Indonesia, Australia, Russia, and South Africa—retain the ability to rapidly increase supplies, limiting the potential for price rallies in the coal market.

Raw Materials Sector and Logistics: Insurance Premiums as a Hidden Tax

Participants in the market should pay special attention to the transformation of transportation and logistics costs. Military danger in the Hormuz Strait is being transmitted to the market through several channels:

1. Freight rates for VLCC-class tankers are rising as the number of vessel owners willing to operate in the risk zone decreases.
2. Insurance premiums for war risks are being adjusted upwards, effectively forming an additional tax on every barrel of Middle Eastern oil.
3. Route Lengthening and redirection of flows increase fleet turnover time, reducing the effective supply of tonnage.
4. Reevaluation of delivery premiums in favor of producers outside the Persian Gulf—West Africa, Latin America, and the North Sea.

Several governments are already preparing for possible disruptions in energy resource supplies by reassessing strategic reserve parameters. Meanwhile, regional intermediaries are attempting to negotiate a ten-day ceasefire between Washington and Tehran, which could serve as the basis for new negotiations. Tehran is considering the proposal, but final agreement is yet to be reached.

Forecast and Conclusions for Energy Market Participants

The current configuration of the global energy market is characterized by the overlay of a short-term geopolitical shock onto a mid-term trend toward a supply surplus. Practical guidelines:

• Oil: The range of $85–95 per barrel for Brent will persist until there is clarity regarding shipping conditions in the Hormuz Strait. Achieving a ceasefire agreement could quickly eliminate a $10–15 premium.
• Gas: TTF prices are expected to range between €55 and €65 per MWh, with a risk of exceeding this range under an unfavorable scenario in autumn. A key indicator to monitor will be the daily injection rates into European gas storage facilities.
• Oil Products in Russia: A gradual restoration of balance is anticipated as repairs at refineries are completed; the question of extending the export ban after July 31 remains the primary regulatory risk.
• Electricity: The investment focus is shifting from generation to grids, storage, and sources of flexibility—where the deficit is forming.
• Coal: Tactical support from expensive gas exists while maintaining long-term structural pressure.

For investors, fuel, and oil companies, the key skill in current conditions is not predicting price direction, but effectively managing volatility: revising hedging strategies, stress-testing logistics chains, and reevaluating counterparty risks in high military threat zones. The energy market has entered a phase where reaction speed is more crucial than forecast accuracy.