November 9, 2026 | Global Oil & Gas Industry | Permian Basin
1. Executive Summary
The global oil market experienced one of its sharpest weekly corrections in years, as expectations of a diplomatic resolution to the U.S.-Iran conflict began removing the geopolitical premium from crude prices. Yet the decline comes against a backdrop of historically tight diesel inventories, continued shipping insecurity and strong financial results from major energy producers.
January Brent futures settled Friday, November 6, at approximately $98.32 per barrel, down 13.3% on a comparable-contract basis for the week. December WTI settled at $90.83, declining 12.8%. Selling continued Monday morning, November 9, with Brent trading near $94.83 and WTI near $88.17 in late-morning London trading.
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The market's change in direction reflects growing expectations that diplomatic negotiations could eventually restore more predictable Middle Eastern petroleum exports. President Trump's comments reducing the perceived likelihood of renewed strikes against Iran added to the downward pressure, although tanker attacks continue near the Strait of Hormuz.
The underlying supply picture remains complicated. The IEA projects global oil demand will decline approximately 2.6 million barrels per day in 2026, while observed petroleum inventories remain substantially below pre-conflict levels. Meanwhile, U.S. distillate inventories have fallen to their lowest level since May 2003.
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In the Permian Basin, third-quarter earnings offer a distinctly constructive picture. Diamondback Energy increased production guidance, Permian Resources expanded its Delaware Basin holdings, and major midstream companies announced additional gathering and processing investments. Drilling activity remains stable, and national frac activity recovered modestly last week.
Market sentiment: Bearish near-term price momentum, but fundamentally cautious rather than outright bearish. The market is beginning to price a geopolitical normalization that has not yet fully occurred. Further price declines are possible, but unresolved physical supply risks make a sustained collapse less certain.
2. Global Oil Market
Geopolitics: Diplomacy Begins Replacing Supply Disruption as the Dominant Price Driver
The most consequential development of the week was the market's increasing confidence that the U.S.-Iran conflict could move toward a negotiated resolution.
Reports of continuing diplomatic engagement contributed to the sharp selloff, while President Trump suggested additional military strikes were unlikely under improving negotiating conditions.
However, the security environment remains fragile. Commercial vessels were attacked near the Strait of Hormuz over the weekend, and Saudi authorities reported additional missile and drone activity. No comprehensive agreement restoring normal shipping conditions has been announced.
The distinction matters. Markets can reduce their expectations of future disruption well before physical transportation, insurance and export conditions normalize.
Saudi Arabia's experience illustrates the challenge. The kingdom has increasingly relied on its East-West Pipeline, alternative export routes and overseas storage to provide customers with dependable crude deliveries.
For the industry, the relevant measure of diplomatic success will be sustained recovery in actual petroleum shipments, not simply improved political rhetoric.
Supply and Demand: A Tight Market Confronts Weakening Consumption
The IEA's latest published Oil Market Report forecasts a decline in global petroleum demand of approximately 2.6 million barrels per day during 2026, bringing consumption to 102.4 million barrels per day.
Elevated fuel prices, weaker economic activity and restricted refined-product availability are driving the contraction. The agency expects a partial demand recovery in 2027, but consumption would remain below 2025 levels.
On the supply side, global production rebounded to 102.3 million barrels per day in September, supported by improving Gulf exports. Nevertheless, global observed inventories at the end of September were approximately 509 million barrels below pre-conflict levels.
IEA
That combination creates an unusual market.
A potential recovery in exports is bearish for crude prices, but rebuilding depleted inventories could absorb significant barrels once transportation conditions improve.
The latest U.S. inventory report reinforces this distinction. Commercial crude inventories declined for a fifth consecutive week, falling approximately 865,000 barrels to 409.8 million barrels for the week ending October 30. Domestic production increased toward 14 million barrels per day.
More importantly, distillate inventories declined 3.6 million barrels to 99.3 million barrels, approximately 13% below their five-year seasonal average.
Crude supply is becoming more manageable, but diesel availability remains a major unresolved problem.
Markets: Crude Falls Faster Than Physical Risks Disappear
The approximately 13% weekly decline in Brent and WTI demonstrates how rapidly geopolitical risk premiums can unwind.
However, the current weakness also reflects deteriorating demand expectations and improved availability of some physical Middle Eastern barrels.
The Brent-WTI spread has narrowed from the exceptional levels experienced during earlier phases of the conflict, reducing the relative international premium for crude.
For U.S. producers, this development is important because many operating and acquisition economics benefited from elevated benchmarks during the third quarter.
Meanwhile, diesel and refining markets remain comparatively tight. The IEA reported global diesel exports running approximately 700,000 barrels per day below year-earlier levels in September, with prolonged constraints likely to extend into 2027.
The possibility of lower crude prices alongside elevated product prices could sustain strong margins for refiners while reducing upstream revenue expectations.
Major Company Developments: Profits Support Financial Discipline
Saudi Aramco reported third-quarter adjusted net income of $31.2 billion, up from $28.6 billion a year earlier. Free cash flow reached $28.2 billion, while downstream adjusted operating earnings increased substantially because of stronger refining margins.
The company also reported the start of production from its Zuluf crude expansion and continued work on alternative export routes and overseas storage.
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BP reported further portfolio simplification, including refinery divestitures and plans to market additional mature businesses. BP continues prioritizing balance-sheet improvement and selective investment rather than broad capital expansion.
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Shell also agreed to sell its 16.7% interest in Australia's North West Shelf gas project to Abu Dhabi's XRG for approximately $1.45 billion, illustrating continued capital recycling and international gas consolidation.
The broader corporate message is consistent: the industry is monetizing high-price cash flow, improving capital efficiency and concentrating investment in assets with durable competitive advantages.
3. Dedicated Permian Basin Report
Production Trends: Growth Continues Without an Aggressive Drilling Expansion
Third-quarter operating results reinforced the Permian Basin's position as the leading engine of U.S. upstream growth.
Diamondback Energy reported average oil production of 525,000 barrels per day and total production of approximately 1.034 million BOE per day. The company raised full-year oil-production guidance to approximately 524,000 barrels per day, supported by operational efficiency and consistent development execution.
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Permian Resources reported 208,000 barrels per day of oil and total production of 457,500 BOE per day, a 22% quarter-over-quarter increase in total volumes.
Importantly, the company reduced lease operating expenses to approximately $5.11 per BOE while generating $846 million of adjusted free cash flow.
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These results demonstrate that the basin continues generating production growth through efficient development, acquisitions and operating improvements rather than relying exclusively on larger drilling fleets.
Drilling and Completion Activity
Baker Hughes reported 273 active Permian rigs for the week ending November 6, an increase of one from the previous week.
Nationally, U.S. drilling activity increased by one rig to 604, including 463 oil-directed rigs.
Completion activity also recovered. Primary Vision's U.S. frac-spread count increased four to 195, following three consecutive weekly declines. The count remains above the 173 active spreads reported during the comparable week last year.
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The recovery is encouraging, but it does not indicate a new drilling boom.
The more important trend is that operators continue adjusting activity selectively based on well economics, service costs and expected returns.
With WTI falling sharply over the past week, the next several rig and frac reports will offer an important indication of whether producers intend to maintain current fourth-quarter programs.
M&A and Integration: Permian Resources Expands Its Delaware Basin Inventory
Permian Resources delivered one of the week's most significant acquisition updates.
The company reported completing approximately 175 transactions totaling $1.15 billion, adding roughly 24,000 net acres, 9,000 net royalty acres and 200 net two-mile drilling locations across the core New Mexico Delaware Basin.
These acquisitions were completed during the quarter rather than representing a single newly announced transaction.
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The strategy illustrates how consolidation is evolving.
Instead of relying only on multibillion-dollar corporate acquisitions, operators are assembling additional contiguous acreage, improving drilling configurations and increasing inventory quality through smaller transactions.
Diamondback's acquisition of a 7.5% equity interest in the Solitude Pipeline System also reflects an increasingly integrated investment approach, combining upstream production with access to natural-gas transportation infrastructure.
For the broader acquisition market, the latest crude-price correction introduces additional valuation uncertainty. Buyers and sellers may increasingly disagree over how much of 2026's unusually strong cash flow should be capitalized into long-term asset values.
Infrastructure and Natural Gas Takeaway: New Capacity Changes the Outlook
Natural-gas transportation remains one of the basin's most consequential infrastructure issues.
On November 3, Energy Transfer confirmed that Phase II of its Hugh Brinson Pipeline remains scheduled for the first quarter of 2027. The project is expected to increase capacity from approximately 1.5 Bcf per day to more than 2.3 Bcf per day.
The company also placed its 275 MMcf-per-day Mustang Draw II processing plant into service in the Midland Basin during October and announced Bear II, a proposed 200 MMcf-per-day Delaware Basin processing plant scheduled for the third quarter of 2027.
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AEGIS estimates approximately 4.5 Bcf per day of new outbound Permian pipeline capacity will enter service during 2026, with the next significant period of congestion risk potentially emerging in early 2028.
The investment is increasingly necessary because associated-gas volumes can grow faster than crude output.
Recent results from Targa Resources reinforce this dynamic. The company reported record Permian inlet, NGL transportation and fractionation volumes during the third quarter, alongside adjusted EBITDA of approximately $1.5 billion, up 18% year over year.
Targa Resources Corp.
Pricing Differentials: Waha Weakens, Crude Takeaway Remains a Concern
Permian natural-gas pricing softened during the week.
According to AEGIS, Waha cash fell from approximately $1.46 per MMBtu on October 30 to $1.12 on November 4, before recovering to $1.39 on November 5.
December Waha basis remained near negative $1.22 per MMBtu, while winter 2027–28 basis was approximately negative $2.08.
The forward market therefore continues anticipating meaningful regional discounts despite ongoing infrastructure additions.
Crude transportation deserves equally close attention.
Earlier analysis from East Daley Analytics showed that pipelines serving Corpus Christi are approaching practical capacity limits, while Houston-bound transportation is also tightening.
New investment is responding to those conditions.
On November 6, Plains All American announced an expansion of its Permian joint-venture gathering system, adding approximately 270,000 dedicated acres in the Midland Basin under 10-year agreements with a large integrated producer. The system is expected to support approximately 225,000 barrels per day of gross volumes beginning in the fourth quarter of 2027.
The commercial implications are straightforward: as production expands, access to efficient Gulf Coast transportation will become increasingly important to realized crude pricing.
Notable Company Developments
The latest earnings reports highlight three complementary strategies within the Permian.
Diamondback is emphasizing predictable development execution, production guidance and shareholder distributions.
Permian Resources is expanding its position through smaller acquisitions while reducing operating expenses and improving production efficiency.
Plains, Targa and Energy Transfer are investing in the transportation and processing systems required to support long-term production growth.
Taken together, these strategies suggest the basin's next phase will be characterized less by rapid drilling expansion and more by integration, consolidation and optimization of existing assets.
4. What to Watch Next Week
November 10 — EIA Short-Term Energy Outlook: Updated WTI and Brent forecasts will be particularly important following crude's sharp decline. Watch assumptions regarding Middle Eastern exports, global demand and 2027 inventory rebuilding.
U.S. Energy Information Administration (EIA)
November 11 — OPEC Monthly Oil Market Report: Watch demand estimates, non-OPEC supply growth and the group's assessment of the effects of lower crude prices.
November 12 — EIA Weekly Petroleum Report: Delayed one day by Veterans Day. Distillate inventories, refinery utilization and crude-stock changes will be especially important.
U.S. Energy Information Administration (EIA)
November 13 — IEA Oil Market Report: The agency's updated analysis will help determine whether October's projected 2.6-million-barrel-per-day demand contraction remains its central scenario.
U.S.-Iran negotiations and Hormuz shipping: Any verified improvement in vessel transit, insurance availability or export volumes could accelerate removal of the geopolitical premium.
Permian activity and basis: Watch whether frac spreads continue recovering, Waha cash prices stabilize and declining WTI begins influencing 2027 capital expectations.
5. Bottom Line
The most important development this week is the disconnect between falling crude prices and continuing physical tightness in refined products.
Crude markets are beginning to price improved geopolitical conditions. Brent and WTI declined approximately 13% last week, and additional selling emerged Monday.
Yet global inventories remain depleted, diesel supply is constrained, and normal commercial transportation through the Strait of Hormuz has not fully returned.
That creates a market in which prices can decline rapidly on improved expectations but remain highly sensitive to renewed disruption.
The Permian Basin presents a stronger operational picture.
Production continues growing. Diamondback and Permian Resources are generating substantial free cash flow. Midstream operators are increasing processing capacity and expanding gathering and transportation networks.
However, the sharp decline in crude prices introduces an important test of capital discipline.
The industry's next advantage will not necessarily belong to the companies producing the most incremental barrels. It will belong to those capable of sustaining attractive margins at lower realized prices.
For energy executives, the strategic priorities remain clear: disciplined capital allocation, efficient operations, favorable transportation access and conservative commodity-price assumptions.
The coming week's EIA, OPEC and IEA reports should provide important evidence of whether the market's rapid correction reflects an enduring change in global fundamentals—or simply another phase of extraordinary geopolitical volatility.