Weekly Oil Market Intelligence
August 3, 2026
Prices reflect Monday-morning trading and may move materially during the session.
Executive Summary
Oil begins the week caught between rapid geopolitical de-escalation in the paper market and continued tightness in the physical market. WTI fell below $80 Monday morning after the United States paused planned strikes against Iran and raised the prospect of negotiations. Brent retreated toward $83. Iran, however, has not confirmed direct talks, and the security and operating status of the Strait of Hormuz remain unresolved.
Meanwhile, OPEC+ approved another 188,000-barrel-per-day production increase for September. The additional quota is directionally bearish, although its practical effect depends on whether Gulf exporters can move incremental barrels safely and economically.
U.S. physical fundamentals remain comparatively firm. Commercial crude inventories fell 7.2 million barrels, refinery utilization reached 97.2%, and crude exports increased. Permian drilling also strengthened modestly, with the basin adding two rigs, although the national frac-spread count declined by four.
Market sentiment: Neutral, with asymmetric upside risk.
The market is pricing a reduced probability of immediate escalation—not a fully normalized global supply chain. A failed diplomatic effort or renewed shipping attack could restore the geopolitical premium quickly.
Global Oil Market
Geopolitics: Diplomacy Reduces—but Does Not Eliminate—Hormuz Risk
The week’s dominant event was another sharp shift in the U.S.-Iran conflict. Oil rallied during the latter half of July following renewed attacks on military and shipping targets, only to reverse Monday after the United States paused further strikes and signaled an interest in negotiations.
The market is assuming that diplomacy increases the probability of improved passage through the Strait of Hormuz. That assumption remains fragile. Iran has not confirmed the same negotiating framework described by Washington, while separate discussions with Oman appear focused on navigation and control of the strait.
The central risk is logistical rather than geological. The world has available production capacity, but barrels must still be loaded, insured, transported and refined. Higher OPEC+ quotas offer limited relief when tankers are unwilling or unable to move through affected corridors.
Supply and Demand
OPEC+ will increase the combined September production target of seven participating countries by 188,000 barrels per day. The move completes the current phase of unwinding 1.65 million barrels per day of voluntary cuts introduced in 2023. Larger groupwide cuts remain in place, and producers will meet again September 6.
The bearish implication is straightforward: if Middle Eastern trade flows normalize, more OPEC+ supply could arrive as geopolitical demand premiums fade.
The bullish counterargument is equally important. U.S. crude inventories stand 7% below their five-year seasonal average, gasoline stocks are 6% below normal, and distillates are 9% below normal. The physical system therefore has less cushion than Monday’s price decline might suggest.
Markets
WTI ended July at $84.67, gaining 22% during the month, while Brent finished at $90.12, up 24%. Monday morning’s decline erased a significant portion of those gains in a matter of hours.
Natural gas presents a very different market. Henry Hub remains below $3 despite strong power-sector consumption because production and storage remain ample. Renewable generation and battery capacity are also limiting the amount of incremental gas demand created by summer heat.
The divergence is notable: global oil is trading on maritime security, while U.S. natural gas is trading on domestic production and infrastructure.
Major Company Developments
ExxonMobil reported second-quarter earnings of $14.5 billion, operating cash flow of $23.6 billion and free cash flow of $17.2 billion. The company produced more than 1.8 million barrels of oil equivalent per day from the Permian—a company record—and returned $9.4 billion to shareholders.
Chevron reported adjusted earnings of approximately $12 billion and record quarterly production. The increase was driven by the Hess acquisition, Permian growth and Gulf of America operations.
The broader message from the majors is clear: higher prices are increasing cash generation, but capital is still being directed toward integration, efficiency, balance-sheet strength and shareholder returns—not indiscriminate drilling.
Permian Basin Report
Production Trends
The Permian continues delivering production growth without a proportionate increase in activity.
ExxonMobil’s basin output exceeded 1.8 million barrels of oil equivalent per day during the quarter. Chevron also cited Permian growth as a principal contributor to record companywide production. Ovintiv averaged 231,000 barrels of oil equivalent per day from its Permian position, with liquids representing 78% of production.
These results reinforce the basin’s defining trend: scale, longer laterals, repeatable development and operating efficiencies are allowing large producers to grow volumes without returning to prior-cycle rig intensity.
Drilling and Completion Activity
The Permian rig count increased by two to 260 during the week ending July 31. The total U.S. count rose by one to 588, including 451 oil rigs, 127 gas rigs and 10 miscellaneous rigs.
Completion activity moved in the opposite direction. Active frac spreads declined by four to 194, although that remains 27 spreads above the comparable period last year.
The combination of more rigs but fewer completion crews suggests measured development rather than an aggressive production surge. Operators may be adding drilling capacity, building inventory or addressing scheduling issues without materially accelerating near-term well turn-ins.
Recent Texas permit activity remained concentrated in Reagan and Reeves counties, with Pioneer, EOG, Continental Resources and other operators targeting the Spraberry, Wolfcamp and Bone Spring formations.
M&A and Integration
No new Permian megadeal dominated the reporting period. Instead, attention shifted toward extracting value from transactions already completed.
ExxonMobil’s record basin volumes highlight the continued integration of Pioneer Natural Resources. Chevron’s record production similarly reflects the combined impact of Hess assets and organic Permian growth. This suggests the current phase of consolidation is increasingly about execution after acquisition—aligning drilling schedules, infrastructure, personnel and inventory—rather than simply accumulating acreage.
For prospective buyers, contiguous acreage, existing infrastructure and immediate operating synergies should command a greater premium than disconnected inventory requiring a new standalone organization.
Infrastructure and Natural Gas Takeaway
The Permian remains close to its gas-egress limits, but several projects are beginning to provide relief.
The Gulf Coast Express expansion adds approximately 570 MMcf per day. Blackcomb is expected to transport up to 2.5 Bcf per day toward Agua Dulce, while Energy Transfer’s Hugh Brinson system has begun limited intrastate flows ahead of full system completion. AEGIS expects bottlenecks to ease materially by late 2026 or early 2027 as these projects ramp.
Hugh Brinson began initial flows June 13, although the system is expected to ramp in stages and may not be fully operational until March 2027. This distinction matters: nominal pipeline capacity does not immediately equal fully available takeaway.
Local demand is also becoming more important. Chevron has signed a 20-year agreement to develop a 2.67-gigawatt gas-fired power facility supporting a Microsoft data center in West Texas. Projects of this scale could gradually convert Permian gas from a transportation liability into a local power-generation asset.
Pricing Differentials
A directly comparable, independently verified daily Midland crude differential was not available at publication, so this report is not assigning a precise figure.
The more pressing regional pricing issue remains Waha natural gas. AEGIS describes the current forward curve as unusually weak for this period and warns that maintenance on existing pipelines could again pressure cash and prompt-month prices. Historically, Waha has frequently settled below the price producers could have hedged one year earlier.
For producers, firm transportation, basis hedges and gas-marketing arrangements can be nearly as important as the headline Henry Hub price. An oil well’s economics can deteriorate quickly when associated gas must be curtailed, flared or sold at a deeply negative basis.
Notable Company Developments
ExxonMobil: Record Permian production above 1.8 million barrels of oil equivalent per day demonstrates the impact of operating scale and Pioneer integration.
Chevron: Record company production was supported by Permian growth, while its Microsoft power agreement creates a potential long-term local demand source for basin gas.
Ovintiv: The company maintained Permian capital guidance of approximately $1.325 billion to $1.375 billion, with roughly five rigs and 125–135 net wells expected during 2026. It raised companywide production guidance without increasing capital guidance.
Diamondback Energy: Second-quarter results are scheduled after Monday’s close, followed by its investor call Tuesday morning. Commentary on rig additions, Waha exposure and full-year production plans will be especially important.
What to Watch Next Week
Confirmation—or denial—of formal U.S.-Iran negotiations.
Actual tanker traffic and insurance availability through the Strait of Hormuz.
Wednesday’s EIA petroleum report.
Diamondback Energy results and Tuesday’s conference call.
Permian Resources results Wednesday and its Thursday conference call.
ConocoPhillips results Thursday.
Progress and flow volumes on Hugh Brinson and Blackcomb.
Waha cash pricing during pipeline maintenance or extreme heat.
Whether higher Permian rig activity translates into renewed frac-spread growth.
OPEC+ compliance with August targets and preparations for the September increase.
Bottom Line
Monday’s oil decline reflects a lower perceived probability of immediate escalation—not a fully resolved supply problem.
OPEC+ is adding barrels, but U.S. inventories remain below normal, refineries are operating near capacity, and the Strait of Hormuz remains a material source of uncertainty. The market can move sharply in either direction as diplomatic and shipping developments unfold.
The Permian outlook remains constructive. Rig activity is increasing modestly, leading operators are reporting record production, and new gas takeaway and local power-demand projects should improve the basin’s long-term economics.
The strongest strategy remains unchanged: underwrite investments at conservative commodity prices, control operating and basis risk, and preserve the upside created by volatility.