Aramco Cut Its August Oil Price to Asia by $11 — the Biggest Cut Since 2003

$11 a barrel. The Aramco August OSP cut moved the official selling price of Arab Light crude to Asia from a $9.50 premium over the Oman/Dubai average in July to a $1.50 discount for August, a swing announced on 6 July 2026 and the largest single-month move in Reuters price records going back to 2003 [S1][S2]. It is also the lowest Arab Light differential to Asia since June 2020, the trough of the pandemic demand collapse [S22].

The wires carried the number within minutes and moved on. What almost nobody explained is what an official selling price actually is, why Saudi Arabia prices its crude as a spread rather than a price, and what a differential of that size does — and does not — tell you about strategy. A cut this large is consistent with a fight for market share, but it is not proof of one. Three other readings survive the evidence, and one of them — that the benchmark itself has become unreliable — is the most under-reported story in Middle East crude pricing this year.

The short version. An OSP is a differential, not a price. Aramco fixes it in advance; the benchmark it attaches to floats afterwards. In August 2026 the company cut every Arab grade in every region by an identical amount — $11.00 in Asia, $15.00 in Northwest Europe, $8.00 in North America — which is the signature of a flat regional repricing, not a grade-by-grade read on demand. Refiners still have to nominate volumes for the cut to work.

Last verified: 31 July 2026. The September 2026 OSP, due on or about 5 August, had not been announced at the time of writing.

What Happened: The August OSP Cut in Five Numbers

$1.50 below Oman/Dubai. Aramco set Arab Light for August 2026 loading at a $1.50 discount to the average of the Platts Dubai and Platts Oman assessments, against a $9.50 premium for July [S1][S4].

An $11.00 cut, versus an expected $6.50 to $8.00. A Reuters survey of refiners and traders in late June pointed to a premium of $1.50 to $3.00 — a cut of $6.50 to $8.00. The move overshot the top of that range by three dollars [S1].

Three consecutive cuts, each larger than the last. June was cut $4.00, July $6.00 — itself the largest since 2000 — and August $11.00, from a wartime record of $19.50 in May [S1][S4].

$15.00 off Europe, $8.00 off North America. Arab Light for Northwest Europe was set at a $0.85 premium to ICE Brent, down $15.00; for North America at a $4.60 premium to the Argus Sour Crude Index, down $8.00 [S1][S4].

Set on 6 July, before the attacks. The decision was published two weeks before the Houthi naval blockade declaration of 20–21 July and nineteen days before the 25 July strike that burned storage tanks at the Jazan refinery, one of the downstream refining assets on the Red Sea coast [S14][S15]. It was not a response to either; the Red Sea security escalation came afterwards.

The full sequence, with the September announcement still outstanding at the time of writing:

Sources: Aramco pricing documents as reported [S1][S4][S22]. Figures are differentials, not flat prices.

For the standing profile of the company that sets these prices, see our Saudi Aramco entry, and for the production-policy framework it operates inside, Saudi Arabia’s OPEC quota. This analysis covers the pricing mechanism and the August decision specifically; the quota page owns production policy and the fiscal-breakeven question belongs to our oil price impact on the Saudi economy explainer.

What Is an Official Selling Price (OSP)?

An official selling price is a differential, not a price. It is the fixed premium or discount that a state oil producer charges above or below a published regional benchmark, and it is the only number the producer actually sets. The cash a refiner pays is the benchmark’s own monthly average plus or minus that differential.

Written as a formula:

Cargo price = regional benchmark average for the loading month ± the producer’s differential

Three features of that formula do most of the analytical work, and each is routinely lost in news coverage.

The differential is fixed forward; the benchmark floats afterwards. Aramco publishes its OSPs around the fifth business day of each month for cargoes loading the following month. The August 2026 differentials were set on 6 July; the benchmark they attach to is the average of daily Dubai and Oman assessments across August, which on 6 July nobody knew. An OSP is a forward bet on market conditions, not a spot quote.

A cut to the differential is not a cut to the price. If the benchmark rises by more than the differential falls, the producer’s realised price goes up even as the headline says “cut”. Reading OSP headlines as revenue news without checking the benchmark is reading half the equation.

It only binds if buyers lift. OSPs govern term contracts — standing agreements under which refiners nominate volumes each month within contractual limits. A high OSP does not force a refiner to pay; it invites the refiner to nominate less. Nominations, not prices, are where Asian demand registers.

Kuwait, Iraq, Iran and Abu Dhabi all publish monthly differentials too, and Aramco’s announcement has historically set the reference point for the rest [S6]. A single Saudi decision moves the entire Gulf pricing complex within days.

How Aramco Prices Arab Light: Oman/Dubai, ICE Brent and ASCI

Aramco publishes a grid, not a price: five crude grades against four regional benchmarks, revised monthly. The grades run by API gravity from Arab Super Light (above 40 degrees) through Extra Light, Light and Medium to Arab Heavy (below 29 degrees) [S4]. Arab Light is the flagship and the grade quoted in headlines.

Source: Aramco pricing document as reported by Reuters and Argaam [S1][S4].

Each benchmark matches the destination market’s crude quality and trading conventions. Dubai and Oman are medium-sour grades resembling Arab Light and are what Asian refiners hedge against. ICE Brent is the light-sweet North Sea futures complex European refiners price off. ASCI is the Argus index of US Gulf Coast sour crude, adopted for American cargoes because it tracks the sour barrels those refineries were built to run.

Every grade moved by exactly the same amount

Set the July and August grids side by side and a pattern appears that changes the interpretation of the whole decision.

Source: Aramco July and August 2026 pricing documents as reported [S1][S4].

Every Asian grade fell by exactly $11.00. Every Northwest Europe and Mediterranean grade fell by exactly $15.00. Every North American grade fell by exactly $8.00. There is no grade-level variation anywhere in the August grid.

That uniformity matters. When a producer responds to grade-specific conditions — a glut of heavy sour, a light-sweet premium, a shift in refinery yields — differentials move by different amounts. A flat, identical adjustment across an entire regional column signals something else: a wholesale repricing of the region relative to its benchmark. Aramco was not fine-tuning demand for Arab Heavy versus Arab Extra Light. It reset the whole Asian book in one move, and did the same, at different magnitudes, in Europe and America.

Why Did Saudi Arabia Cut Oil Prices to Asia?

Because Asian refiners had stopped buying, and the war premium that justified the old differentials had collapsed.

The demand collapse is documented in the nomination data. Chinese term nominations for Saudi crude fell from 47.5 million barrels in February 2026 to 14 million in June — a 70% reduction. Sinopec, historically Aramco’s single largest customer, cut from 10 million barrels a month to 2 million; Rongsheng from 7 million to 1 million. Japanese liftings fell from a historical average near 1.0–1.2 million barrels a day to roughly 130,000 b/d in May. South Korea dropped about 35% month-on-month to around 530,000 b/d, India about 30% to roughly 450,000 b/d [S7].

The cause was price. Arab Light differentials to Asia climbed from roughly $2 in March 2026 into the high teens as Hormuz disruption made Middle East barrels scarce [S7]. Two published series diverge here: OilPrice.com puts April and May at about $20 and $16, while the Aramco pricing documents reported by Reuters and Argaam put the May peak at $19.50 and June at $15.50 [S1][S4][S7]. The gap is a one-month labelling difference between announcement and loading months; the Aramco documents are the authoritative series and the one used throughout this article. Either way, Chinese refiners — already losing a reported $13 a barrel on crude runs in April — declined to nominate [S7].

The consequence showed up in export volumes. Saudi crude exports fell to 3.74 million barrels a day in May 2026, a twelve-year low, recovering to 4.53 million b/d in June against a pre-conflict average of 6.55 million b/d. Chinese imports of Saudi crude ran at 626,300 b/d in June versus a pre-conflict 1.48 million b/d [S3].

Set against that, the Aramco August OSP cut is not a strategic flourish. It is a producer discovering that its price had detached from its market and correcting hard. Reuters columnist Clyde Russell put the reasoning plainly the following day, writing that the cut reflects an assumption that “the Strait of Hormuz remains open” and an expectation of oversupply comparable to 2020, and asking whether the reduction was even large enough — because Kuwait, Iraq and the UAE were “offering discounts of several dollars a barrel, much more than the $1.50 that Aramco announced” [S3].

The sequencing that most coverage gets backwards

The August OSP was set on 6 July 2026, with Brent in the mid-to-high $70s after falling from its wartime peak; the benchmark traded near $77 on 10 July [S16][S17].

The Houthi naval blockade of Saudi shipping was declared on 20–21 July [S15]. The strike that burned storage tanks at the Jazan refinery came on 25 July, with missiles aimed at Yanbu intercepted [S14]. Brent responded, reaching roughly $97 on 24 July and closing near $90 on 30 July [S16][S17].

The order of events is not a footnote. Aramco fixed an $11 discount into a market that then rose sharply — and because the differential is locked while the benchmark floats, August cargoes price off an August Dubai/Oman average set largely after the attacks. Any account presenting the OSP cut as a reaction to the blockade or the Jazan strike has the causation inverted by two to three weeks.

Does an OSP Cut Mean a Price War?

Not necessarily. A differential cut is consistent with a market-share war, but also with at least three other explanations, and all four are live here. The evidence for each:

Reading 1 — benchmark mechanics. This is the strongest and least reported. The Platts Dubai benchmark has been structurally damaged by the Hormuz crisis. It historically priced roughly 18 million barrels a day, about a fifth of global supply, off crude produced in the UAE, Oman and Qatar and mostly loaded inside the strait. With transits collapsed, Platts cut the deliverable grades from five to two — Murban and Oman — reducing the basket’s supply by around 40%, and participants have described the benchmark as effectively broken [S6]. Platts had already reworked the methodology in January 2026, replacing Murban’s fixed premium with a bidirectional quality adjustment, then suspended negative adjustments in March as supply tightened; trade data show one trading house taking delivery of 77 of 82 Dubai partials cargoes in March [S6]. When a benchmark becomes thin and distorted, a producer must move its differential simply to keep the delivered price sane. Some unknown share of the $11 is arithmetic, not strategy.

Reading 2 — competing grades. Kuwait, Iraq and the UAE were discounting by several dollars a barrel before Aramco moved, and the August cut still left Saudi crude priced above some rivals on Russell’s reading [S3]. A producer matching competitors is not starting a war; it is refusing to lose one.

Reading 3 — refinery margins. Asian refiners were reportedly losing about $13 a barrel on crude processing in April 2026, with product export restrictions and reserve drawdowns compounding weak runs [S7]. When downstream margins are negative, no crude differential clears the market.

Reading 4 — market share. OPEC+ approved a further 188,000 barrels a day of production increases for August at its 5 July meeting, the fifth consecutive monthly hike, with Saudi Arabia and Russia adding roughly 62,000 b/d each [S8]. A producer raising volume and cutting price simultaneously is doing the two things a market-share strategy requires. Russell’s conclusion was that the market “appears to be rapidly returning to supply growth and a price war for market share” [S3].

The discriminating test is not the size of one cut. It is whether deep cuts persist while volumes rise. One month is repricing; three months of the same is policy.

Is Saudi Arabia Fighting for Market Share?

The evidence is suggestive but not conclusive — and the September announcement is the test.

Three consecutive cuts of increasing severity, alongside five consecutive OPEC+ production increases, form a coherent volume-over-price posture, and it is what Russell read into the July decision [S3]. Against it stands the fact that Saudi export volumes in June, at 4.53 million b/d, were still 31% below the pre-conflict average [S3] — a producer genuinely prosecuting a share war would normally be exporting more than usual, not far less. The August cut is as easily read as recovering lost customers as capturing new ones.

There is also a live question about whether Aramco believes its own benchmark. On 29 July 2026, Bloomberg reported that the company had told at least two Chinese refiners it was preparing a separate official selling price for crude loaded at Egypt’s Sidi Kerir terminal for Asian delivery, because shipowners are avoiding Yanbu and Asian buyers want compensation for Cape of Good Hope voyages. Indian and South Korean refiners were reported to be seeking $5 to $10 a barrel off Yanbu-based prices, and to be pressing for reductions on both August-booked cargoes and the September OSP. Aramco declined to comment [S5]. A producer building a second pricing basis for the same crude is managing freight risk, not conducting a price war — but it is also conceding that its standard Ras Tanura-based Asian formula no longer describes how its oil reaches Asia.

The UAE left OPEC — and Saudi restraint now subsidises a competitor

The competitive frame changed permanently on 1 May 2026, when the United Arab Emirates formally exited OPEC after 59 years, the largest producer ever to leave [S9]. The US Energy Information Administration documented the resulting reduction in the group’s share of world crude production and capacity [S10].

UAE crude output rose from 3.3 million b/d in May 2026 to 4.1 million b/d in June, an all-time high, with a stated ambition of 5 million b/d capacity [S11]. Abu Dhabi is no longer bound by a quota, and its flagship Murban grade is not sold as a monthly differential at all: it trades as a physically deliverable futures contract on ICE Futures Abu Dhabi (IFAD), loading at Fujairah — outside the Strait of Hormuz — with continuous screen pricing and no destination restrictions [S12][S24].

That is a structurally different product from an OSP. A Saudi buyer receives a price fixed once a month by a committee in Dhahran, referenced to a benchmark that has lost 60% of its deliverable grades. A Murban buyer sees a live, exchange-traded price all day and can hedge it on the same screen. Wood Mackenzie’s assessment is that the exit rattles OPEC’s grip on the market [S23]; the pricing dimension is arguably the sharper edge. Murban’s promotion inside the Platts Dubai basket means that when Aramco cuts its Asian differential, it cuts against a benchmark in which its principal regional competitor’s grade now has an outsized vote.

Every barrel Saudi Arabia holds back to defend price is a barrel Abu Dhabi is free to sell. See our Saudi Arabia versus the UAE benchmark and the national oil companies comparison; for the strategy layer, OPEC strategy and the OPEC entry.

Does an OSP Cut Mean Cheaper Petrol?

No — and the clearest proof is what happened next. Aramco announced the record cut on 6 July 2026. By 30 July, Brent was trading around $90 a barrel, roughly 17% above its 10 July level of about $77 [S16][S17]. Crude got more expensive, not less, in the three weeks after the largest OSP cut in twenty-three years — and crude, not the OSP, is what fuel markets follow.

Three reasons an OSP cut does not reach the pump.

It is a wholesale term price, not a market price. OSPs apply to contracted cargoes sold to specific refiners in specific regions. They do not set the price of crude traded on exchanges.

It is a differential, not a level. A cut to the spread tells you nothing about the benchmark. In August 2026 the benchmark rose while the differential fell.

Crude is a minority of the pump price in most markets. Refining margins, distribution, retail margin and — decisively in Europe — fuel duty and VAT dominate. Inside Saudi Arabia, domestic petrol prices are administered under a capped mechanism rather than tracking crude at all.

An OSP cut shows up instead in the accounts of Asian refiners, in Aramco’s realised price per barrel, and — with a quarter’s lag — in Saudi government oil revenue, a channel we take apart in our reading of why the kingdom is earning more from fewer barrels and is still short. That last channel is the one that matters for the transformation.

Why This Matters for Vision 2030

Oil receipts still fund the transformation, so the differential Aramco charges is a Vision 2030 variable whether or not it appears in any Vision document.

The arithmetic is unforgiving. Aramco reported Q1 2026 adjusted net income of $33.6bn, revenue of SAR433.1bn ($115.5bn), up 6.8%, and a base dividend of $21.9bn — against free cash flow of $18.6bn, already below the dividend, after a $15.8bn working-capital build [S18]. That dividend is the single largest line funding the Saudi budget and, through the state’s shareholding, the Public Investment Fund’s domestic programme. On our own arithmetic, an $11 differential applied to even half of June’s 4.53 million barrels a day of exports is roughly $750m a month in foregone revenue, before any benchmark movement is counted.

The IMF’s calculated fiscal breakeven for Saudi Arabia in 2026 is $86.6 a barrel; Bloomberg Economics puts it near $96; on a basis including PIF off-balance-sheet spending, estimates run to $108–111. The breakeven question is treated in full on our oil price impact on the Saudi economy page, the site’s canonical treatment; the point here is narrower. Brent near $90 on 30 July sits above the IMF’s on-budget threshold and below both of the others — and Aramco has just given away $11 of differential on its largest export market.

Tim Callen, visiting fellow at the Arab Gulf States Institute in Washington and formerly the IMF’s mission chief for Saudi Arabia, has argued that the breakeven price is a poor guide to Saudi policy: its components shift constantly, it assumes budgets must balance annually when Saudi Arabia has one of the G20’s lowest debt ratios, and it excludes off-budget vehicles such as the PIF [S19]. His conclusion — that “even if the market oil price is well below the fiscal breakeven price, there is no need for concern about fiscal sustainability in Saudi Arabia” — is the strongest available counter to alarmist readings of the Aramco August OSP cut [S19]. It is also an argument about solvency rather than spending capacity. A state that can borrow is not the same as a state that can keep funding giga-projects at plan.

The connected pieces: Aramco’s Q1 2026 war dividend covers the earnings baseline, the 2026 budget the spending side, and Saudi Arabia’s oil exports volumes and destinations. Progress on replacing these receipts is tracked at non-oil revenue and explained at Saudi Arabia’s non-oil revenue.

Risks, Contradictions and Open Questions

The Hormuz assumption may be wrong. The cut was premised, on Russell’s reading, on the strait remaining open [S3]. Lloyd’s List Intelligence recorded 25 non-Iran-linked transits in the week of 13–19 July, down from 108 the week before, with total traffic down about 90% year-on-year [S13]. The defensible description is effectively closed with partial transiting — not normalised. If Aramco priced August on a normalisation that has not occurred, the differential is wrong in the buyer’s favour.

We cannot see the reasoning. Aramco does not comment on OSP decisions and declined to comment on the Sidi Kerir report [S5][S6]. Every attribution of motive here, including our own, is inference from published prices and volumes.

The benchmark distortion is unquantified. We can document that Platts cut the Dubai basket from five deliverable grades to two and that participants call it broken [S6]. We cannot say what share of the $11 is benchmark correction and what share is commercial strategy. Anyone who claims a split is guessing.

Volume recovery is unproven. The test of the Aramco August OSP cut is whether Chinese, Indian, Japanese and South Korean nominations rebound for August and September liftings. As of 31 July 2026 no nomination data for those months had been published.

Route economics may have overtaken price. With Bab al-Mandeb loadings driven to near zero and cargoes routing via Suez and the Cape [S14][S21], and Aramco reportedly preparing a separate Sidi Kerir OSP with buyers seeking $5–$10 discounts [S5], freight is competing with the differential as the determining variable. A refiner weighing a $1.50 discount against a Cape voyage is not won back by price alone.

The two-week gap is the trap. Because the cut and the attacks fall so close together, coverage that omits the dates reads as though Aramco discounted in panic. It did not. Any analysis of the September OSP that fails to distinguish pre-blockade from post-blockade pricing repeats the error in the opposite direction.

When Is the Next OSP Announced?

Around the fifth business day of each month, for cargoes loading the following month. On that schedule the September 2026 OSP was due on or about 5 August 2026, and it had not been announced as of 31 July 2026, the date of this analysis.

Recent announcement dates confirm the pattern: July 2026 prices on 8 June, August 2026 prices on 6 July [S1][S4]. Aramco issues a pricing document to term customers; the wires reproduce the grid within the hour, and Argaam publishes the full grade-by-region table [S4].

Two events land immediately before it. The OPEC+ ministerial meets on 2 August 2026 [S8], and Aramco reports first-half 2026 results on 4 August [S25]. The September differential therefore arrives after the market has seen both the production decision and the company’s half-year cash position — making it the most informative OSP announcement in at least a year.

What to Watch Next

• ~5 August 2026 — the September OSP. A second consecutive deep cut, particularly one again moving every grade by an identical amount, confirms sustained repricing rather than a one-month correction. A partial restoration towards a premium implies the August cut was a benchmark and freight correction that has run its course.
• 2 August 2026 — the OPEC+ ministerial. A sixth consecutive production increase alongside a second deep OSP cut is the clearest available signal of a volume-over-price strategy [S8].
• 4 August 2026 — Aramco H1 2026 results. Watch realised price per barrel, gearing and the dividend. Q1 free cash flow of $18.6bn was already below the $21.9bn base dividend [S18][S25].
• Whether a separate Sidi Kerir OSP is formalised. Bloomberg reported the mechanism as unfinalised on 29 July 2026 [S5]. Publication would be the first structural change to Aramco’s Asian pricing basis in years.
• August and September nomination data from Asian refiners. Chinese nominations ran 47.5m barrels in February and 14m in June [S7]. A recovery towards February levels is the only real proof the cut worked.
• Hormuz transit counts and Platts Dubai basket composition. Lloyd’s List’s weekly series tests the normalisation assumption [S13]; any restoration of deliverable grades alters the arithmetic under every Middle East OSP [S6][S20].
• UAE output above 4.1m b/d and Murban’s IFAD volumes. Sustained growth in both makes Murban, not Dubai, the reference Asian refiners actually price against [S11][S12][S24].

Related Vision 2030 Context

• Saudi Aramco: company profile and structure — ownership, production and the state’s shareholding.
• Saudi Arabia’s OPEC quota and production policy — the volume framework the pricing decision sits inside.
• Oil price impact on the Saudi economy — the canonical page for fiscal breakeven and revenue dependency.
• Saudi Arabia’s oil exports: volumes, markets and pricing — where the barrels actually go.
• Asian energy markets and Saudi crude demand — the buyers whose nominations decide whether the cut works.
• Saudi Arabia’s Hormuz bypass and Red Sea logistics — East-West Pipeline and Yanbu route economics.
• Yanbu: Red Sea export terminal — the port at the centre of the freight problem.
• The oil dependency paradox — why diversification still runs on crude receipts.

Sources

• [S1] Reuters (syndicated via BOE Report), Saudi Arabia Cuts August Arab Light Asia OSP, Biggest Drop in Over Two Decades, news report, 6 July 2026. https://boereport.com/2026/07/06/saudi-arabia-cuts-august-arab-light-asia-osp-biggest-drop-in-over-two-decades/
• [S2] Reuters (via TradingView, newsml_L1N4380DN), Saudi Arabia Cuts August Arab Light Asia OSP, Biggest Drop in Over Two Decades, wire copy, 6 July 2026. https://www.tradingview.com/news/reuters.com,2026:newsml_L1N4380DN:0-saudi-arabia-cuts-august-arab-light-asia-osp-biggest-drop-in-over-two-decades/ — the Zawya syndication of the same Reuters copy returned an HTTP error to automated retrieval; figures here are taken from the BOE Report and TradingView reproductions.
• [S3] Clyde Russell, Reuters (syndicated via BOE Report), Saudi Arabia Slices Crude Oil Prices, but Is It Enough?, column, 7 July 2026. https://boereport.com/2026/07/07/saudi-arabia-slices-crude-oil-prices-but-is-it-enough-russell/
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• [S14] The National, Saudi Arabia Shifts to Suez as Houthis Drive Bab Al Mandeb Oil Exports to Near Zero, news report, 26 July 2026. https://www.thenationalnews.com/business/energy/2026/07/26/saudi-arabia-shifts-to-suez-as-houthis-drive-bab-al-mandeb-oil-exports-to-near-zero/
• [S15] Al Jazeera, Yemen’s Houthis Declare Naval Blockade of Saudi Arabia: What to Know, news explainer, 20 July 2026. https://www.aljazeera.com/news/2026/7/20/yemens-houthis-declare-naval-blockade-of-saudi-arabia-what-to-know
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• [S19] Tim Callen, Arab Gulf States Institute in Washington, The Breakeven Oil Price Is a Poor Guide to Saudi Arabia’s Fiscal and Oil Production Policies, analysis, 2 August 2023. https://agsi.org/analysis/the-breakeven-oil-price-is-a-poor-guide-to-saudi-arabias-fiscal-and-oil-production-policies/
• [S20] S&P Global Commodity Insights, Platts Dubai/Oman Benchmarks FAQ, methodology document. https://www.spglobal.com/content/dam/spglobal/ci/en/documents/platts/en/our-methodology/methodology-specifications/crude-oil/supporting-materials/dubai-oman-benchmarks-faq.pdf
• [S21] Al Jazeera, Can the Suez Save Asian Oil Consumers After Houthis Shut Bab al-Mandeb?, news analysis, 22 July 2026. https://www.aljazeera.com/news/2026/7/22/can-the-suez-save-asian-oil-consumers-after-houthis-shut-bab-al-mandeb
• [S22] MacroMicro, Saudi Arabia — Official Selling Price for Arab Light Crude to Asia vs Oman/Dubai, historical data series. https://en.macromicro.me/series/24960/saudi-arabia-official-selling-price-for-arab-light-to-asia-vs-oman-dubai
• [S23] Wood Mackenzie, UAE’s Exit Rattles OPEC’s Grip on the Oil Market, research commentary, 2026. https://www.woodmac.com/blogs/the-edge/uaes-exit-rattles-opecs-grip-on-the-oil-market/
• [S24] AGBI, Can Abu Dhabi’s Murban Become the Asian Crude Benchmark?, opinion analysis, May 2026. https://www.agbi.com/opinion/oil-and-gas/2026/05/can-abu-dhabis-murban-become-the-asian-crude-benchmark/
• [S25] Aramco, Investor Overview and Results Calendar, corporate investor-relations page, accessed 31 July 2026. https://www.aramco.com/en/investors