Oil Market Report - August 2026

August 2026 was less a continuation of July’s renewed war-premium rally than a repeated test of whether the crude market could finally price a credible exit from the Gulf supply crisis.

EXECUTIVE SUMMARY

August 2026 was less a continuation of July’s renewed war-premium rally than a repeated test of whether the crude market could finally price a credible exit from the Gulf supply crisis. The answer changed several times during the month. Brent and WTI collapsed in the opening sessions as Washington stepped back from another attack on Iran and diplomatic mediation revived expectations for greater Hormuz flows, only to reverse sharply once the proposed reopening arrangements proved politically and commercially difficult. Two intra-month rallies subsequently rebuilt the geopolitical premium, first as Iran hardened its conditions for use of the Strait and maritime attacks intensified, and then as the mid-June ceasefire framework effectively collapsed, tanker traffic fell back into single digits and Washington threatened Iran’s trading partners. The late-month shift from military escalation toward sanctions and renewed Iran-Oman/Qatar diplomacy generated another substantial correction, before fresh U.S.-Iran strikes around Larak Island on August 31 abruptly restored part of the premium. Thus, August produced a remarkably wide internal cycle even though the net monthly result was much less dramatic than either June or July. As of August 31, Brent front-month futures stood at $91.34/bbl, up $3.41/bbl from July 31 and recording a 3.9% MTD gain, while WTI reached $86.47/bbl, increasing by $1.80/bbl or 2.1% MTD. Monthly-average prices strengthened more convincingly: Brent averaged $87.82/bbl, $4.35/bbl above July, an increase of 5.2% MoM, while WTI averaged $82.44/bbl, $3.28/bbl higher and up 4.1% MoM. Intramonth ranges nevertheless remained exceptionally large. Brent's lowest print was $78.11/bbl on August 5 and its high was $94.83/bbl on August 21, producing a $16.72/bbl low-to-high range. WTI similarly moved between $74.24/bbl on August 5 and $87.69/bbl on August 20.

September should begin with a constructive technical setup but a fundamentally two-sided market. The central case is not another straight-line war rally; rather, Brent is likely to remain in a broad $84–100/bbl range and WTI around $79–94/bbl, with the direction determined primarily by whether observed Gulf flows finally validate—or disprove—the diplomatic reopening narrative. August 31 materially strengthened the short-term chart with momentum favors further upside tests, but not yet a runaway technical breakout. The first upside milestones are straightforward. Brent needs to clear the August high around $94.8/bbl; a sustained move above that zone would reopen July's $100–102/bbl area. WTI faces initial resistance around $87.7–89/bbl, followed by July's $93.5/bbl high. The bullish fundamental scenario requires actual deterioration in maritime flows: another collapse in visible Hormuz transits, renewed mining, damage to a major Gulf export facility, or a serious widening of the Bab el-Mandeb blockade. The August 31 Larak strikes show that this tail is very much alive. The bearish case has stronger medium-term economics. The IEA now expects global oil demand to contract by 1.6 mbd in 2026 and sees 3Q26 demand down 2.8 mbd YoY. China's weak crude appetite remains especially important: since the war began, the country has imported roughly 400 mb less crude than a year earlier, and its willingness to replenish stocks appears highly price-sensitive. OPEC+ will provide another policy test on September 6. The seven participating producers already approved a 188 kbd September adjustment, completing the unwind of the 2023 voluntary tranche. The stock position provides the principal counterweight to the bearish demand story. Global observed inventories were down around 410 mb since the start of the war by end-July, and the IEA estimates a 1.8 mbd deficit in 3Q26. The EIA expects U.S. commercial crude inventories to remain below the bottom of their five-year range through end-2026 and forecasts Brent around $85/bbl in 3Q26 under an assumption that severe Hormuz constraints begin to ease only after August. Technically, Brent has first meaningful support around $88/bbl, followed by its 50-day area around $84–85/bbl; below there, the August $78–80/bbl trough becomes the decisive bearish marker. WTI support lies around $82–83/bbl, then $79–80/bbl and finally $74–75/bbl. A real Hormuz agreement accompanied by several consecutive weeks of rising tanker volumes, falling insurance premia and stronger Middle Eastern loadings could drive prices toward those lower zones. Conversely, verified damage to Gulf infrastructure or another material contraction in Hormuz/Bab el-Mandeb traffic could push Brent above $100/bbl quickly because inventories and refinery-product buffers remain much thinner than before the war.

July 2026 brought another sizeable restoration of global oil production, but the month was much less straightforward than the headline increase suggests. Upstream volumes continued to recover from the extraordinary spring collapse, while the logistics supporting those barrels deteriorated again as the month progressed. The International Energy Agency estimated that global oil supply rose by 2.4 mbd in July to 101.5 mbd, with Gulf production alone increasing by a further 2.5 mbd to 23.9 mbd after a 3.7 mbd gain in June. Yet 8.3 mbd of Gulf output was still shut in relative to pre-war levels. More importantly, production and exports moved in opposite directions: regional exports, including volumes carried through routes bypassing Hormuz, fell by 2.1 mbd to 15 mbd after the Strait was effectively closed again and attacks on tankers and energy infrastructure intensified. Gulf loadings briefly reached around 20 mbd at the beginning of July before sliding to roughly 12 mbd later in the month. July therefore looked stronger in monthly-average production statistics than conditions at month-end actually were. The IEA consequently cut its 2026 global supply forecast again and now expects production to decline by 4.3 mbd this year to around 102 mbd before rebounding by 8.3 mbd in 2027.

The U.S. Energy Information Administration painted an even stronger sequential recovery in July. World liquids production climbed to 101.03 mbd, increasing by 3.57 mbd from June, equal to a 3.7% MoM rise. That extended the recovery to a second month and lifted output to the highest level in five months. Seasonality played only a supporting role in such a large increase, as only about one-fifth of July’s rebound can be associated with the usual June-to-July seasonal pattern, while the overwhelming part reflected the restoration of war-curtailed production. That interpretation is consistent with the EIA’s own assessment that Middle Eastern crude shut-ins still averaged around 5.5 mbd in July despite the substantial improvement from the spring trough. Even after two strong recovery months, world supply remained 6.20 mbd lower than in July 2025, down 5.8% YoY, extending the annual contraction to five months. The gap to normal seasonality, however, had narrowed dramatically: global output was only 1.15 mbd, or 1.1%, below the July five-year average, compared with the much deeper deficits recorded during the acute phase of the war.

OPEC crude production recorded another powerful recovery in July 2026. According to cartel’s own data, total crude output increased by 1.65 mbd from June to 19.85 mbd, rising 9.1% MoM. That was the strongest monthly growth rate in almost 10 years, extended the recovery to a second consecutive month and lifted the group to its highest level in five months. Seasonality explains only a small fraction of that move. The five-year average normally rises by around 154 kbd between June and July; July 2026 added more than ten times that volume, meaning that roughly 90% of the increase came from factors outside the normal seasonal pattern. Iraq, Saudi Arabia and Kuwait alone provided around 1.55 mbd, or approximately 94%, of the headline monthly gain, making July overwhelmingly a Gulf restart story. The historical damage remained visible despite that improvement. OPEC production was 4.52 mbd below July 2025, down 18.6% YoY, extending the annual contraction to a fifth month, and remained 3.91 mbd, or 16.5%, below the five-year July average. The key change from June was therefore not normalization, but the speed at which previously curtailed Gulf barrels began returning before security conditions deteriorated again later in July.

The August 2 OPEC+ decision preserved the gradual quota-unwind policy, but physical availability remained much more important than formal targets. Saudi Arabia, Russia, Iraq, Kuwait, Kazakhstan, Algeria and Oman agreed to implement another 188 kbd adjustment in September, while reiterating their commitment to compensation for past overproduction and retaining flexibility over subsequent changes. In an ordinary market, another quota increase would be a meaningful signal of looser supply. In the present environment it remained secondary: the IEA estimated that the eight OPEC members covered by its target table were collectively producing 4.58 mbd below their implied July targets, including shortfalls of 2.11 mbd in Saudi Arabia, 1.50 mbd in Iraq and 900 kbd in Kuwait. A 188 kbd policy increment is small beside those involuntary gaps. Until export routes and damaged infrastructure allow the Gulf producers to approach their existing targets, the principal constraint remains deliverability rather than OPEC+ willingness to supply.

Non-OPEC total oil production continued to recover in July 2026, but the headline improvement concealed an unusually polarized regional picture. Total liquids supply rose by 750 kbd from June to 76.9 mbd, gaining 1.0% MoM and extending the sequential upswing to a third month. The aggregate reached its highest level in five months. At first glance, the move was not exceptional from a seasonal perspective: the five-year average normally increases by roughly 660 kbd between June and July, so the magnitude of the headline gain was broadly consistent with the usual summer pattern. Its composition, however, was anything but normal. Africa & Middle East alone added around 670 kbd as the U.A.E. and Qatar continued to restore production from war-depressed levels; the Americas supplied another 308 kbd and Europe 176 kbd, whereas the CIS lost 292 kbd and Asia-Pacific 111 kbd. Excluding Africa & Middle East, therefore, non-OPEC supply increased by only around 80 kbd. The annual comparison remained negative for a fifth month: output was 1.2 mbd below July 2025, down 1.6% YoY. The gap was concentrated in Africa & Middle East and the CIS, partly offset by persistent growth in the Western Hemisphere. Even after the wartime disruption, non-OPEC production still stood 3.8 mbd above the five-year July average, a 5.2% premium, illustrating how much the structural supply base outside the cartel had expanded before the Gulf crisis.

U.S. total oil production paused in July 2026 after five consecutive monthly increases, but the data looked much more like a high-level plateau than the beginning of a broad supply contraction. Total liquids output averaged 24.2 mbd, declining by 47 kbd from June, or 0.2% MoM. This was the fastest monthly decrease in six months and the first negative print since January. The move was also counter-seasonal: the five-year average normally increases by around 94 kbd between June and July, so normal calendar effects would have supported rather than reduced production. The composition helps put the decline into perspective. Crude oil fell by around 70 kbd and accounted for more than the entire net setback; renewables added 20 kbd, NGL production was essentially flat but positive, while processing gains and the products adjustment changed only marginally. On a year-over-year basis, total U.S. output was still 1.0 mbd higher, rising 4.4% YoY and extending the annual expansion to 22 months. Production stood 2.7 mbd, or 12.7%, above the five-year July norm. Given that the latest EIA outlook still expects U.S. crude output to average around 13.8 mbd in 2026, July is better interpreted as a pause around historically elevated production than as evidence of a rapid supply retrenchment.

U.S. shale oil production across the three major deposits — Permian, Bakken and Eagle Ford — eased to 9.06 mbd in July 2026. Combined output fell by 24 kbd from June, or 0.3% MoM, reversing the small increase recorded a month earlier and taking the aggregate to its lowest level in six months. The move was modest in absolute terms, but it was clearly counter-seasonal: according to the five-year averages, three-hub production normally increases by around 56 kbd between June and July, whereas this year it declined. More importantly, July also marked a rare deterioration in the annual comparison. Output was 14 kbd below July 2025, down 0.2% YoY, breaking an extraordinary 62-month run of annual increases. Still, the negative annual change was marginal and largely reflected deep weakness in Bakken and Eagle Ford outweighing continued Permian growth. Three-hub supply remained 933 kbd above the five-year July average, a sizeable 11.5% premium. The aggregate represented 65.5% of total U.S. crude production, up 15.0 bps from June because nationwide crude output fell somewhat faster, but 213 bps below its year-earlier share. July’s small decline therefore looks less like the beginning of a broad shale contraction and more like a plateau at historically elevated production, accompanied by an increasingly pronounced divergence between the Permian and the two mature secondary basins. That interpretation is also consistent with drilling activity: the U.S. oil rig count continued to rise during July and reached its highest level since May 2025 rather than signaling an industry-wide retreat.

The global oil demand picture remained depressed in July 2026, but the monthly data were considerably less bearish than they initially appear. The acute consumption shock of March-May had passed, the June recovery subsequently lost momentum, and renewed hostilities around the Strait of Hormuz again complicated product availability just as the Northern Hemisphere entered peak summer demand. The IEA responded by cutting its 2026 global oil demand forecast for another month: it now expects consumption to decline by 1.6 mbd this year, 510 kbd more than projected in July. The agency sees the contraction easing from 4.9 mbd in 2Q26 to 2.8 mbd in 3Q26 before demand returns to modest growth in the final quarter. Importantly, the constraint has increasingly shifted from crude availability toward refined products. Global refinery throughputs rose by 1.8 mbd in July but remained almost 5 mbd below a year earlier, while seaborne product trade was down by 3.8 mbd in annual terms. Diesel exports from Russia, the Middle East and Asia alone were around 1.3 mbd lower, with jet-fuel exports down by roughly 670 kbd. The continuing shortage of usable products therefore remained an important drag on end-user consumption even as more crude became available.

According to the EIA, global oil consumption averaged 101.5 mbd in July, slipping by 238 kbd from June, or 0.2% MoM. The decline broke the two-month recovery from May’s war-driven trough and was the fastest monthly contraction in three months, but its magnitude should not be overinterpreted. Normal seasonality points in precisely the same direction and, in fact, much more strongly: based on the change in the five-year monthly averages, global demand would ordinarily fall by around 520 kbd between June and July. Actual consumption therefore performed roughly 280 kbd better than the normal seasonal pattern. The more important weakness remained in the annual comparison. World oil use was 3.6 mbd below July 2025, down 3.5% YoY, extending the annual downturn to five months. Consumption also remained 369 kbd below the July five-year average, a 0.4% deficit. July consequently looked less like a renewed demand collapse and more like an interruption of the post-May recovery against a seasonally softer monthly backdrop. The scale of the annual deficit, rather than the small sequential decline, remains the clearest indication of how much demand the Gulf war, product shortages and elevated fuel prices have removed from the global system.

The brief respite in global oil inventories proved short-lived in July. According to the International Energy Agency, observed crude and product stocks around the world fell by 69 mb over the month, reversing June’s 21 mb increase and taking the cumulative draw since the start of the Gulf war to about 410 mb, or 2.7 mbd on average. The anatomy of the July decline was almost the mirror image of June. In June, oil on water had swollen by 117 mb as an armada of Gulf cargoes finally moved toward distant refining centers; in July, renewed disruption to Gulf and Caspian exports sharply reduced barrels in transit and pulled the global aggregate lower again. Onshore inventories were comparatively stable, declining by only 6 mb as the pace of emergency releases slowed, but this relative stability should not be confused with replenishment: total observed stocks finished July at just below 7.9 bn barrels, the lowest since April 2025. The renewed draw coincided with a deterioration in the physical Gulf recovery. Regional exports, including bypass routes, fell by 2.1 mbd to 15 mbd as the Strait of Hormuz became effectively constrained again; loadings had briefly approached 20 mbd at the start of July before dropping toward 12 mbd later in the month. With the IEA now estimating a 1.8 mbd global supply deficit for 3Q26, inventories have again become an active balancing mechanism rather than a passive residual of the supply-demand equation.

The latest detailed OECD statistics, which currently extend through May 2026, reveal how much of that inventory cushion had already been consumed before the renewed July escalation. OECD commercial stocks fell to 446.81 mln tons in May, a further 8.95 mln-ton decline from April, or 2.0% MoM. The draw extended to a third consecutive month and drove inventories to their new multi-decade low. Compared with May 2025, the stockpile was lower by 21.61 mln tons, a contraction of 4.6% YoY and the sharpest annual rate of decline in 41 months. The deficit to the five-year May norm widened to 41.00 mln tons, or 8.4%. This was emphatically not a normal calendar effect. Over the previous five years, OECD inventories on average declined by only about 0.13 mln tons between April and May; the actual 8.95 mln-ton loss was almost seventy times larger. May was therefore another war-driven depletion month even though oil prices were already retreating from their April extremes. That distinction matters: price relief emerged faster than physical normalization, while Gulf output was still 13.6 mbd below its pre-conflict level and global observed inventories were drawing at 4.6 mbd during May. OECD government stocks were simultaneously being mobilized at an exceptional pace, falling by 163 mb from the start of the war to their lowest level since December 1990.

July finally interrupted the three-month collapse in total U.S. oil inventories, but the stabilization was much less reassuring than the positive headline suggests. Aggregate stocks rose by 2.79 mb to 1 527.6 mb, increasing 0.2% MoM and posting the strongest monthly growth rate in four months. The rebound was nevertheless tiny relative to the preceding losses and left U.S. inventories 137.61 mb below July 2025, down 8.3% YoY—the sharpest annual decline in 42 months—and 174.37 mb, or 10.2%, beneath the five-year July average. The seasonal test is particularly useful here. U.S. total oil inventories normally increase by around 10.8 mb between June and July; 2026 delivered only about one-quarter of that typical build. July therefore should not be described as a genuine normalization month. It was a weak seasonal recovery in which commercial stocks finally rebuilt but another large SPR withdrawal and renewed product draws absorbed most of the improvement. The overall system remained very close to June’s multi-year low and entered the second half of the summer with an inventory cushion that was unusually thin by both annual and historical standards.

Cushing crude inventories finally moved away from the edge of the operational danger zone, although only modestly. Inventories at the NYMEX WTI delivery hub increased by 1.29 mb to 20.96 mb in July, a 6.6% MoM rise that broke three consecutive months of declines and produced the strongest monthly growth rate in four months. The rebound is more notable because it was counter-seasonal: Cushing stocks have historically fallen by around 2.62 mb between June and July, whereas this year they increased. Even so, there is little basis for calling the hub comfortable. Inventories remained 1.60 mb below July 2025, down 7.1% YoY, the sharpest annual decline in eight months, and stood 8.29 mb below the five-year July average, a 28.4% deficit. July therefore changed the immediate direction, not the structural condition. After June had pushed Cushing below 20 mb and close to levels regarded as operationally uncomfortable, even a counter-seasonal 1.29 mb recovery left the hub with less than three-quarters of its normal July stock cover. The inland market gained some breathing room, but not enough to eliminate its sensitivity to refinery runs, pipeline flows and another burst of export demand.

Vortexa’s global offshore inventory measure delivered perhaps the most dramatic July reversal anywhere in the stock complex. Worldwide offshore stocks jumped by 42.77 mb to 127.47 mb, an increase of 50.5% MoM that extended the recovery to a second month and was the strongest growth rate in eight months. Inventories reached a three-month high and stood 33.37 mb above July 2025, up 35.5% YoY, extending the annual expansion to thirteen months. Against the five-year July average, the surplus widened to 37.77 mb, or 42.1%. Almost none of this can be attributed to ordinary seasonality: the historical June-to-July increase is only around 2.6 mb, barely 6% of the observed build. The surge therefore reflected an abnormal reconfiguration of waterborne barrels. At first glance this seems to conflict with the IEA’s finding that global oil on water fell sharply in July, but the measures are not like-for-like. Broad oil-in-transit volumes can decline when Gulf exports collapse at the same time that a larger proportion of the remaining barrels becomes delayed, anchored or otherwise classified as offshore/floating inventory. July’s combination of lower Gulf export volumes and sharply higher Vortexa offshore stocks is therefore consistent with a market in which normal voyage flow deteriorated and cargo distribution became more congested and uneven.

AC - Oil Market Report - Aug-2026.pdf

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