Weekly Oil Market Intelligence
August 10, 2026
Executive Summary
The oil market begins the week with a familiar but more complicated tension: diplomatic progress around the Strait of Hormuz is advancing, while security conditions around the same corridor are deteriorating. Iran says an agreement with Oman establishing new shipping lanes is in its final stages, but Tehran is conditioning a full reopening on broader U.S. concessions. Over the weekend, the UAE accused Iran of attacking an ADNOC-linked vessel in the strait, while Houthi forces claimed a strike on Saudi Aramco’s Jazan refinery.
That uncertainty has kept crude highly reactive. WTI moved below $76 during the week as traders anticipated a Hormuz breakthrough, rebounded above $82 as tensions returned, and opened Monday near $79. Brent was trading around $84–$85 Monday morning. The market is increasingly treating every diplomatic statement as a change in near-term supply probability rather than as confirmation that Gulf logistics have normalized.
Outside the Middle East, China’s July crude imports recovered sharply from June’s near-decade low, while U.S. crude inventories unexpectedly increased. At the same time, the U.S. Senate approved legislation that could materially tighten pressure on Russian energy buyers if it clears the House and becomes law.
In the Permian, the operating picture is constructive. The basin added three rigs to reach 263—the highest level since July 2025—and several leading operators raised production guidance or reported record output while maintaining disciplined capital programs. The more important structural development remains natural gas: new takeaway capacity is beginning to improve Waha economics, but second-quarter results show just how costly regional basis weakness became before that relief arrived.
Market sentiment: Neutral to cautiously bullish. The downside case rests on a durable Hormuz reopening, recovering supply and softer demand. The upside case remains asymmetric because a fresh shipping disruption can remove physical barrels faster than producers can replace them.
Global Oil Market
Geopolitics
The Strait of Hormuz remains the market’s central geopolitical variable, but the story changed during the past week. Iran now says its technical agreement with Oman on new shipping lanes is nearing completion, yet it continues to insist that reopening depends on additional U.S. actions, including sanctions relief, compensation and other security commitments. Iran also says direct U.S.-Iran talks are not currently underway, with messages instead moving through intermediaries.
That distinction matters. A shipping-lane agreement can improve the mechanics of transit without resolving the political dispute governing whether vessels can actually use those lanes safely. The UAE’s accusation that an ADNOC-linked tanker was targeted by Iran reinforces that gap between diplomatic structure and physical security. ADNOC said its shipping operations have suffered repeated missile and drone attacks during the conflict.
Risk also widened beyond Hormuz. Houthi forces claimed a drone attack on Saudi Aramco’s 400,000-barrel-per-day Jazan refinery, where Saudi authorities confirmed a fire that was later extinguished without injuries. The event highlights the possibility that Red Sea infrastructure and Bab el-Mandeb traffic remain exposed even if conditions in Hormuz improve.
Russia added a separate layer of supply risk. The U.S. Senate passed legislation authorizing sanctions and potentially steep tariffs on major buyers of Russian energy if the measure clears the House and is signed into law. Meanwhile, a Ukrainian drone strike hit the Nizhnekamsk industrial area in Russia, where major refining and petrochemical facilities are located.
The broader implication is that global oil risk is becoming less concentrated. The market is simultaneously pricing Gulf shipping, Red Sea infrastructure, Russian refining and sanctions enforcement.
Supply and Demand
China offered the clearest positive demand signal of the week. July crude imports rose roughly 22% from June to 35.73 million metric tons after the previous month fell to the lowest level in nearly a decade. The rebound was supported by improved Gulf flows and additional purchases from suppliers outside the Middle East, including Russia. Imports nevertheless remained materially below year-earlier levels, so the data point is better characterized as a recovery from disruption than evidence of a broad Chinese demand boom.
U.S. fundamentals moved in the opposite direction on crude inventories. Commercial stocks increased by 2.5 million barrels to 407 million barrels for the week ending July 31 as imports increased and refinery runs eased slightly. Even after the build, crude inventories remained about 6% below the five-year seasonal average, while gasoline and distillate stocks declined and remained below normal levels.
The balance therefore remains mixed. Crude availability is improving at the margin, but product inventories and global transportation constraints continue to limit the degree to which that additional supply translates into a comfortable market.
This week should materially sharpen the outlook: both the IEA’s August Oil Market Report and the next OPEC Monthly Oil Market Report are expected on August 12, providing updated assessments of global demand, supply recovery and inventory balances.
Markets
Price action during the week demonstrated how little conviction currently exists around a single base case. Oil sold off sharply when traders expected a near-term Hormuz deal, then recovered as Iran attached additional conditions and regional attacks continued. WTI fell below $76 early in the week before rebounding to more than $82 on Thursday; Monday morning it was trading around $79, with Brent near $84–$85.
The important signal is not the exact price level—it is the speed of repricing. Physical oil fundamentals do not change by $5–$7 per barrel in a day. Perceived probabilities of shipping disruption do.
That makes the current market unusually difficult for producers and buyers to budget around. The forward outlook may be improving, but prompt barrels still carry exposure to events that can alter freight, insurance and refinery feedstock availability almost immediately.
Major Company Developments
BP reported a sharp improvement in second-quarter results as higher oil and gas prices and stronger refining margins lifted upstream and downstream earnings. The quarter reinforces the financial leverage large integrated producers have to a supply-disrupted environment, particularly when higher crude prices coincide with stronger refining margins.
ADNOC Logistics & Services committed approximately $1.3 billion to acquire 11 crude and LPG carriers, substantially expanding its tanker fleet. The timing is notable: amid heightened concern over maritime security, ADNOC is investing directly in its ability to control more of the transportation chain supporting future production and exports.
For the broader industry, that is an increasingly important theme. In a market where logistics can become the bottleneck, ownership of production alone is not enough; shipping, pipeline access, processing and export capacity are becoming more strategically valuable.
Permian Basin Report
Production Trends
Permian producers used second-quarter earnings to demonstrate that the basin can still deliver incremental production without proportionate capital growth.
Diamondback produced approximately 525,000 barrels of oil per day and more than 1.0 million barrels of oil equivalent per day during the quarter. It raised full-year oil and total-production guidance while leaving its roughly $3.9 billion capital budget unchanged—a strong signal that productivity and operating efficiency, rather than materially higher spending, are driving the increase.
Permian Resources reported second-quarter oil production of approximately 198,000 barrels per day, up 3% sequentially, and raised the midpoint of its full-year oil guidance to 199,000 barrels per day. Management said higher working interests, increased workover activity and acquired production contributed to the increase; notably, the company expects to produce nearly 10% more oil than last year while spending less capital than in 2025.
ConocoPhillips also reported record Permian production of more than 900,000 barrels of oil equivalent per day.
The common message is clear: the next increment of Permian growth is coming from better inventory utilization, longer laterals, workovers, operating scale and acquisition integration—not simply from adding rigs.
Drilling Activity
The U.S. rig count held at 588 during the week ending August 7, but the mix shifted toward oil. Oil-directed rigs increased by three to 454, their highest level since May 2025, while gas rigs declined by three.
The Permian added three rigs to reach 263, its highest count since July 2025. That represents a modest but notable strengthening in activity and suggests operators are selectively responding to improved oil economics without abandoning capital discipline.
Frac activity remains more restrained. The most recent Primary Vision data showed 194 active U.S. frac spreads, below the 198 recorded the prior week but still above year-earlier levels.
That divergence—rising Permian rigs but relatively steady completion crews—supports a measured-growth interpretation rather than the start of an aggressive shale acceleration.
M&A and Integration
The Permian M&A market remains active, but the strategy has changed. Enverus reported that total U.S. upstream deal value declined to $9.1 billion in the second quarter as commodity volatility slowed large transactions, while competition for premium Permian inventory remained strong.
Permian Resources offered one of the clearest examples of the current model. The company said it has deployed roughly $1.05 billion across about 190 transactions this year, adding approximately 54,000 net leasehold acres, 20,000 net royalty acres and 5,000 barrels of oil equivalent per day. Instead of one transformational acquisition, the company is effectively assembling inventory through repeated small transactions where operating proximity and basin knowledge create an advantage.
That is likely to remain the dominant Permian deal structure: fewer headline megamergers, more bolt-ons, minerals, working-interest purchases and acreage trades designed to improve lateral geometry and lower full-cycle costs.
Infrastructure and Natural Gas Takeaway
Gas infrastructure is finally beginning to catch up with associated production.
The Gulf Coast Express expansion has added roughly 570 MMcf per day of capacity, while Blackcomb has begun commissioning and is expected to provide as much as 2.5 Bcf per day of new Permian-to-South-Texas takeaway. Energy Transfer’s Hugh Brinson project is also beginning to move initial volumes, with additional capacity expected to ramp in stages. In total, roughly 4.5 Bcf per day of new outbound capacity is expected to enter service during 2026.
The operating consequences are already visible. Waha turned positive during July after severe second-quarter weakness, and regional production increased as new takeaway became available.
This infrastructure cycle may prove as important to future Permian oil growth as the rig count itself. Associated gas must have an economic outlet before higher-GOR wells can operate consistently at full oil capacity.
Pricing Differentials
Permian crude transportation remains comparatively well supplied; natural gas basis is still the more consequential regional differential.
Second-quarter company results show the severity of the issue. Diamondback reported an average realized natural gas price of negative $2.15 per Mcf before hedging, while Permian Resources said Waha averaged negative $3.14 per Mcfduring the quarter and traded as low as negative $9.52. Permian Resources curtailed some high-GOR production exposed to Waha and used marketing and hedging to materially improve its netback.
Those numbers reinforce a key operating distinction: an oil well can have excellent headline WTI economics and still face production constraints if its associated gas has no viable market.
The improvement in July is meaningful, but it should not yet be viewed as permanent. Rising gas-to-oil ratios and continued oil development could refill newly available pipeline capacity faster than expected.
Notable Company Developments
Diamondback’s quarter stands out for raising production guidance without increasing its full-year capital budget and for doubling its share-repurchase authorization to $16 billion. The combination suggests management sees improved operating productivity as a source of growth while still directing incremental cash toward shareholders rather than maximizing drilling.
Permian Resources generated record adjusted free cash flow of $751 million while simultaneously increasing workover activity and pursuing more than $1 billion of bolt-on acquisitions. Its strategy illustrates how mature Permian platforms can create production growth through both subsurface development and corporate “ground game” activity.
ConocoPhillips reported record Permian output while preparing for a September CEO transition from Ryan Lance to Andy O’Brien. The company is simultaneously managing a large multiyear free-cash-flow growth program, making continued Permian execution particularly important as leadership changes.
What to Watch Next Week
Hormuz implementation: Whether the Iran-Oman shipping agreement is finalized—and, more importantly, whether commercial vessels actually regain dependable access.
Russian sanctions: Whether the House advances the Senate-approved legislation targeting Russian energy buyers.
IEA and OPEC outlooks: Both organizations are scheduled to publish fresh oil-market assessments on August 12.
U.S. inventories: The August 12 EIA report will show whether the latest crude build was temporary or the beginning of broader inventory normalization.
Permian activity: Whether the basin’s three-rig increase is followed by stronger completion activity.
Waha basis: Whether improving takeaway keeps prices positive as associated gas production rises and Blackcomb commissioning progresses.
Bottom Line
The global oil market is moving toward greater supply normalization, but it has not yet reached normal operating conditions.
China’s crude imports are recovering, U.S. crude inventories increased and Gulf shipping negotiations are advancing. Those are meaningful bearish developments. At the same time, tanker attacks, the Jazan refinery incident, Russian infrastructure strikes and potential new sanctions keep the market exposed to sudden physical disruptions.
The Permian remains one of the clearest areas of fundamental strength. Production guidance is rising, drilling activity is firming, bolt-on M&A remains active and gas infrastructure is finally providing some relief from chronic takeaway constraints.
For industry executives, the central signal this week is that operational efficiency and market access are becoming more valuable than simple production growth. The companies best positioned for the next phase are those that can grow volumes without proportionately increasing capital—and can reliably move every molecule they produce.