In February 2026, the first tanker of ultra-light crude oil — condensate extracted from the Jafurah gas field in Saudi Arabia’s Eastern Province — loaded at Yanbu port bound for Chevron. Two more cargoes followed in March: one to ExxonMobil, one to Indian Oil Corporation. The pricing: a premium of $2-3 per barrel above Dubai quotes, free-on-board basis. The export capacity: four to six cargoes per month, approximately 500,000 barrels per cargo, shipped through the Red Sea port that now handles 80-85 per cent of Saudi oil exports while the Strait of Hormuz remains contested.
The condensate is the first physical product of a $100 billion-plus investment programme that will transform Saudi Arabia’s energy infrastructure more fundamentally than any renewable project, any data centre, or any linear city. Jafurah is not a technology play. It is a gas play — the largest unconventional gas development in the Kingdom and the largest shale gas project outside the United States. Its significance for Vision 2030 is structural: gas displaces the crude oil currently burned for domestic power generation, freeing that crude for export and eliminating the absurdity of a petro-state consuming its own most valuable export to keep the lights on.
And at the centre of the financial structure sits BlackRock — or, more precisely, Global Infrastructure Partners, the $170 billion AUM platform that BlackRock acquired in a $12.5 billion deal that closed in October 2024 and that boosted BlackRock’s private markets AUM by approximately 40 per cent. The Jafurah transaction sits within Aramco’s broader pivot from oil-led to gas-led growth. The GIP-led consortium holds a 49 per cent stake in the midstream company that operates Jafurah’s gas processing and fractionation facilities. The deal’s structure is the template for how international capital will flow into Saudi Arabia under PIF’s 2026-2030 strategy.
The Jafurah Field
Jafurah is located in the Eastern Province, approximately 100 kilometres south of the Ghawar oil field — the world’s largest conventional oil field. The comparison to Ghawar is not accidental: Aramco discovered Jafurah’s unconventional gas potential while exploring the geological formations adjacent to its established hydrocarbon provinces. The field’s reserves were revised upward in 2023 to 229 trillion cubic feet of raw gas and 75 billion stock-tank barrels of condensate — an increase from the original 200 Tcf estimate that positioned Jafurah among the largest gas accumulations discovered anywhere in the past two decades.
The total lifecycle investment is expected to exceed $100 billion. The infrastructure includes a 1,500-kilometre pipeline network (main transfer lines, flowlines, and gathering lines), the Jafurah Gas Plant, and the Riyas NGL Fractionation Facility in the industrial city of Jubail. Aramco awarded $25 billion in strategic gas expansion contracts in 2024 alone, reflecting the acceleration of a programme that CEO Amin Nasser has described as central to the Kingdom’s energy transition — not from hydrocarbons to renewables, but from crude oil as a domestic fuel to natural gas as a domestic fuel, with crude redirected to export markets where it commands a premium.
Phase 1 came onstream on 2 December 2025 — a milestone that Aramco highlighted for achieving production capacity of 450 million cubic feet per day, approximately 2.5 times the original projections for the initial phase. Phase 2 is scheduled for 2027. The 2030 production targets are ambitious: 2 billion cubic feet per day of sales gas, 420 million standard cubic feet per day of ethane for petrochemical feedstock, and approximately 630,000 barrels per day of natural gas liquids and condensate.
The scale of these targets is best understood in context. Saudi Arabia’s total gas production in 2023 was approximately 11.3 billion cubic feet per day. Jafurah’s full development would add approximately 18 per cent to the Kingdom’s gas production capacity — the single largest increment since the Ghawar gas system was developed in the 1970s.
The unconventional nature of the development adds technical complexity that distinguishes Jafurah from Saudi Arabia’s conventional gas production. Unconventional gas extraction requires horizontal drilling and hydraulic fracturing — technologies that Saudi Arabia imported from the US shale industry but that Aramco has limited operational history with at scale. Phase 1’s outperformance — 450 million cubic feet per day against original projections of approximately 180 million — suggests that the reservoir is responding better than geological models predicted, potentially indicating that Jafurah’s reserves may exceed even the upwardly revised 229 Tcf estimate.
The lifecycle investment of over $100 billion positions Jafurah as the single most capital-intensive energy project in the Kingdom’s history outside of Aramco’s upstream crude oil operations. The 1,500-kilometre pipeline network alone represents an infrastructure investment comparable to the East-West Pipeline that is currently handling 7 million barrels per day of crude exports through Yanbu. The Riyas NGL Fractionation Facility in Jubail — one of the two assets that BlackRock’s consortium has acquired a 49 per cent stake in — will process Jafurah’s natural gas liquids into propane, butane, and natural gasoline for export and domestic petrochemical use.
The War Context: Jafurah During Hormuz
Jafurah’s development timeline collided with the Iran conflict in a way that simultaneously elevated the field’s strategic importance and complicated its export logistics.
The field’s gas production — consumed domestically for power generation and petrochemical feedstock — is insulated from the Hormuz closure. Gas flows through pipelines to Saudi power plants and to the Jubail petrochemical complex. It does not require port access. The domestic utility of Jafurah’s gas is, if anything, enhanced by the war: every cubic foot of gas that displaces crude oil in domestic power generation frees that crude for export through the East-West Pipeline to Yanbu — the Red Sea port that is now handling 80-85 per cent of Saudi oil exports after the Hormuz closure.
The condensate exports are a different matter. The first cargoes — loaded at Yanbu in February and March 2026 — transit the Red Sea, which was itself the target of Houthi attacks in 2024-2025. The Red Sea route adds approximately 3,500 nautical miles to European-bound cargoes compared to the Gulf route (which would use the Strait of Hormuz, currently closed). The Yanbu routing increases shipping costs and transit times but provides the only viable export path for Saudi crude and condensate during the Hormuz disruption.
The pricing of Jafurah’s condensate — $2-3 per barrel premium above Dubai quotes — reflects the quality of the product (ultra-light, low sulphur) rather than a war premium. Condensate is prized by refineries for blending with heavier crudes and as petrochemical feedstock. The buyers — Chevron, ExxonMobil, Indian Oil Corporation — are sophisticated enough to manage the logistics risk. Their willingness to purchase during the conflict validates the commercial proposition.
The export capacity of 4-6 cargoes per month at approximately 500,000 barrels per cargo implies 2-3 million barrels of monthly condensate exports — modest in the context of Saudi Arabia’s 7 million bpd crude pipeline throughput but significant as a new revenue stream that did not exist before December 2025. At $80-90 per barrel (condensate typically trades at a discount to crude but Jafurah’s ultra-light quality commands a premium), the annualised condensate export revenue approaches $2-3 billion — a meaningful contribution to non-crude hydrocarbon revenue.
The $11 Billion Deal
The BlackRock-Aramco Jafurah midstream transaction was announced in August 2025 and closed in October 2025 — an $11 billion lease-and-leaseback arrangement that serves the specific needs of both parties.
The structure: Aramco established a new subsidiary, Jafurah Midstream Gas Company (JMGC), to hold the Jafurah Field Gas Plant and the Riyas NGL Fractionation Facility. A consortium led by Global Infrastructure Partners — now part of BlackRock — acquired a 49 per cent stake in JMGC. Aramco retains 51 per cent and leases back the facilities under a 20-year tariff revenue agreement.
The economics: BlackRock’s consortium pays $11 billion for a 49 per cent stake in assets that generate revenue through lease payments from Aramco — a contractual cash flow that is independent of gas prices, oil prices, or production volumes. Aramco receives $11 billion in cash (roughly a tenth of its 2025 dividend obligation) while retaining operational control and majority ownership. The structure does not transfer commodity risk to the investor. It does not require the investor to understand gas processing. It requires the investor to assess Aramco’s credit quality — which, as the world’s most profitable company, is not a difficult assessment.
The deal sits in a deliberate sequence. In June 2021, an EIG-led consortium acquired a 49 per cent stake in Aramco Oil Pipelines Company in a $12.4 billion transaction with 25-year tariff rights — the original template, but without BlackRock. In December 2021, a BlackRock Real Assets and Hassana Investment Company consortium agreed a $15.5 billion deal for a 49 per cent stake in Aramco Gas Pipelines Company; the transaction closed in February 2022. The 2025 Jafurah deal is the third in the sequence, the second to involve BlackRock, and the first to be structured around an unconventional gas field rather than legacy pipeline infrastructure. The three transactions together — EIG’s oil pipelines, BlackRock’s gas pipelines, BlackRock’s Jafurah midstream — define the lease-and-leaseback template that international capital now uses to participate in Saudi energy infrastructure.
The $35 Billion Footprint
BlackRock’s total investments in Saudi Arabia now exceed $35 billion across equities, fixed income, and infrastructure — confirmed by BlackRock’s Kashif Riaz. The footprint includes:
Bond holdings exceeding $10 billion across Ministry of Finance, PIF, and Aramco debt issuances — positions that benefit from Saudi Arabia’s investment-grade credit ratings (Moody’s Aa3, Fitch A+) and that generate current income from the Kingdom’s accelerating debt issuance programme (the Saudi debt capital market is projected to reach $600 billion in outstanding issuance by the end of 2026).
The two 49 per cent infrastructure stakes: Aramco Gas Pipelines Company (2022) and JMGC/Jafurah (2025). Together, these positions represent the largest single-entity infrastructure investment in Saudi Arabia by a foreign financial investor.
The BlackRock Riyadh Investment Management platform, established with PIF, which provides the institutional framework for continued strategic growth. BlackRock has indicated plans to double or triple its Saudi allocations to $70-105 billion, with expansion into digital infrastructure, data centres, transport, logistics, ports, and airports.
The trajectory — from $10 billion in bonds to $35 billion across asset classes to a potential $70-105 billion — describes an investor that has moved from observer to participant to infrastructure partner over a three-year period. The acceleration reflects BlackRock’s assessment that Saudi Arabia’s investable universe is expanding (through the QFI reform, the IPO pipeline, and the infrastructure privatisation programme) at a pace that justifies increasing allocation.
Gas-to-Power: The Strategy Behind the Strategy
Jafurah’s significance for Vision 2030 extends beyond the field’s reserves and the deal’s financial structure. It addresses the single most inefficient element of Saudi Arabia’s energy economy: the domestic burning of crude oil for power generation.
Saudi Arabia consumes approximately 3.5-4 million barrels per day of oil equivalent for domestic energy — power generation, desalination, and industrial use. A significant portion of this consumption uses crude oil or heavy fuel oil in power plants, at an opportunity cost of the export revenue that the same crude would generate in international markets. At $100 per barrel — approximately the current Brent price during the Hormuz disruption — every barrel of crude burned domestically for power represents $100 in foregone export revenue.
The gas-to-power strategy replaces domestically consumed crude with natural gas from Jafurah and other fields, freeing the crude for export. Saudi Arabia’s published target is to convert 23 GW of power capacity from oil to gas by 2030, with 42 GW total CCS-ready capacity in the medium term. The conversion is forecast to displace up to 350,000 barrels per day of crude oil from domestic burn, freeing that crude for export. At $80-100 per barrel, the annual revenue impact reaches $10-13 billion — a meaningful contribution to the fiscal arithmetic that the 2026-2030 PIF strategy depends on.
The gas-to-power strategy also produces feedstock for the petrochemical industry — ethane from Jafurah feeds SABIC’s and Aramco’s petrochemical complexes in Jubail, producing the plastics, chemicals, and fertilisers that constitute Saudi Arabia’s largest non-oil export category. The 2030 target of 420 million standard cubic feet per day of ethane from Jafurah alone would significantly increase Saudi Arabia’s petrochemical feedstock availability — reducing the Kingdom’s dependence on imported ethane and naphtha that currently supplement domestic gas production.
Aramco’s target of 80 per cent gas capacity growth by 2030 is driven as much by petrochemical demand as by power generation substitution. The $25 billion in strategic gas expansion contracts awarded in 2024 — covering upstream development, pipeline infrastructure, and processing facilities — represents the largest single-year gas investment in Aramco’s history. The investment is concentrated in three fields: Jafurah (unconventional gas), the Haradh and Hawiyah gas compression programmes (extending production from mature fields), and the South Ghawar gas development. Together, these programmes will raise Saudi Arabia’s total gas processing capacity from approximately 11.3 billion cubic feet per day to over 18 billion cubic feet per day by 2030 — a 60 per cent increase that fundamentally alters the Kingdom’s domestic energy balance.
The war has accelerated the strategic logic. Every barrel of crude that Jafurah displaces from domestic power generation is a barrel that can flow through the East-West Pipeline to Yanbu and out into the Red Sea. In a Hormuz-constrained environment, the marginal value of a freed barrel is not the peacetime export price ($60-65 per barrel) but the wartime export price ($95-120 per barrel). The conflict has doubled the economic incentive for the gas-to-power transition, making Jafurah’s development timeline — Phase 2 in 2027, full production by 2030 — a matter of sovereign fiscal urgency rather than long-term energy planning.
The hydrogen dimension adds a layer that Aramco has not publicly emphasised but that industry analysts have noted. Jafurah’s gas production could feed blue hydrogen plants (gas reforming with carbon capture) that would complement the NEOM Green Hydrogen plant’s renewable-powered production. Saudi Arabia’s National Hydrogen Strategy targets 4 million tonnes of clean hydrogen per year by 2035, with a dual pathway of green (renewable-powered) and blue (gas-powered with CCS). Jafurah provides the feedstock for the blue pathway — a production method that leverages Aramco’s existing gas processing expertise while the green pathway scales through HUMAIN-adjacent renewable energy investments.
The Template for Foreign Capital
The Jafurah deal’s significance for the 2026-2030 PIF strategy is as a template — a replicable structure that can be applied across the Kingdom’s infrastructure portfolio, complementing the corporate-credit tier that King Street’s private-credit fund will serve.
The template’s elements: a Saudi state entity (Aramco, PIF, a government ministry) creates a special-purpose subsidiary to hold infrastructure assets. An international investor consortium acquires a minority stake (typically 49 per cent) in the subsidiary. The state entity leases back the assets under a long-term agreement that generates contractual cash flows for the investor. The state retains operational control and majority ownership. The investor provides capital without assuming operational or commodity risk.
The template can be applied to: ports (Saudi Global Ports, earmarked for IPO), airports (expansions at Jeddah, Riyadh, and NEOM), desalination plants (where ACWA Power’s existing model is similar), power transmission infrastructure, and — most relevantly for the 2026-2030 strategy — data centres. HUMAIN’s $77 billion infrastructure programme could be partially financed through lease-and-leaseback structures that monetise completed facilities while retaining operational control.
BlackRock has explicitly identified data centres, transport, logistics, ports, and airports as expansion targets for its Saudi portfolio. Each of these sectors could accommodate Jafurah-style transactions: long-duration, asset-backed, contractual revenue, minority stakes, no operational risk for the investor. The international capital that PIF’s catalytic model is designed to attract would flow through these structures rather than through the direct equity deployment that characterised the 2021-2025 period.
The Risks
The Jafurah model’s risks are concentrated in three areas.
First, geological execution. Jafurah is an unconventional gas field requiring hydraulic fracturing technology in a region where Saudi Arabia has limited operational experience. Phase 1’s outperformance (2.5 times original projections) is encouraging but does not guarantee Phase 2 or full-field performance. Unconventional gas development in the US has demonstrated that initial well productivity can decline rapidly, requiring continuous drilling to maintain production — a capital-intensive programme that Jafurah’s $100 billion lifecycle cost reflects.
Second, market access. Jafurah’s condensate exports currently route through Yanbu — the Red Sea port that serves as Saudi Arabia’s Hormuz bypass. If the Iran conflict escalates to disrupt Red Sea shipping (Houthi attacks demonstrated this vulnerability in 2024-2025), Jafurah’s export route would be compromised. The field’s domestic gas production is insulated from export risk (domestic consumption does not require port access), but the condensate exports that generate the highest-margin revenue are geographically exposed.
Third, the 20-year lease structure. BlackRock’s 49 per cent stake is locked into a two-decade agreement that extends to approximately 2045. If Saudi Arabia’s fiscal or regulatory environment changes adversely, if Aramco restructures its operations, or if the energy transition accelerates faster than projected (reducing the value of gas infrastructure), BlackRock’s position cannot be easily adjusted. The lease structure provides revenue certainty but also exit illiquidity — a trade-off that BlackRock has accepted but that less patient investors may not.
Fourth, counterparty concentration. BlackRock’s entire Saudi infrastructure portfolio depends on Aramco — a single counterparty. Aramco’s credit quality is exceptional today, but the 20-year horizon encompasses scenarios that could alter its credit profile. The counterparty risk is mitigated by the Saudi government’s majority ownership and the sovereign guarantee that effectively backs Aramco’s obligations, but the concentration is a structural feature that diversified infrastructure investors typically seek to avoid.
The Verdict
The Jafurah deal is the most important energy transaction Saudi Arabia has completed since the Aramco IPO. Not because of its size — $11 billion is significant but not transformative for a $100 billion field. Because of its structure — a structure that demonstrates how international capital can participate in Saudi Arabia’s energy transition without assuming the risks that the Kingdom’s geopolitical, geological, and fiscal environment creates.
BlackRock’s $35 billion Saudi footprint is not a bet on Saudi Arabia’s vision. It is a bet on Saudi Arabia’s assets — the physical infrastructure (pipelines, gas plants, fractionation facilities) and the contractual cash flows (20-year leases, investment-grade counterparty) that generate returns regardless of whether The Line is built, the Mukaab rises, or the Year of AI produces the results its promoters promise.
The strategic implications extend beyond Jafurah. If BlackRock doubles its Saudi allocation to $70 billion, the additional $35 billion must be deployed across asset classes that generate the contracted cash flows BlackRock’s infrastructure model requires. The candidates: HUMAIN’s data centres (which will need build-out capital and can generate cloud service revenue under long-term contracts), the Expo 2030 infrastructure (which can be monetised post-event through commercial real estate operations), the FIFA 2034 stadiums (which can generate naming rights, hospitality, and event revenue under multi-decade operating agreements), and the 15 million TEU port capacity being developed at Yanbu and Oxagon (which generates container handling revenue under port concession agreements).
Each of these represents a Jafurah-style opportunity: a physical asset with contractual revenue, a sovereign counterparty, and a structure that separates the infrastructure investor’s returns from the project’s operational or commodity risk. The $35 billion expansion is not a target BlackRock has formally committed to — it is an indication, reported by Bloomberg, of the scale the firm considers achievable. But the achievability depends on Saudi Arabia’s ability to produce investable infrastructure at the pace and quality that BlackRock’s due diligence requires. Jafurah passed that test. Whether the data centres, stadiums, and ports will pass it remains to be demonstrated.
The Jafurah model separates the investable from the aspirational. The field’s gas is investable — it is physical, measurable, and contractually committed. The Kingdom’s transformation is aspirational — it depends on execution, oil prices, and geopolitical stability that no lease-and-leaseback structure can guarantee. BlackRock invests in the former. PIF is responsible for the latter. The $11 billion deal is the point where the two mandates meet — and where the distinction between investing in Saudi Arabia and investing in Vision 2030 becomes clear.
The distinction is not academic. It determines how the $70-105 billion in potential BlackRock allocation will be deployed. Infrastructure transactions against Aramco’s credit — pipelines, gas plants, fractionation facilities — are investments in Saudi Arabia. They generate returns from physical assets with contractual cash flows. Data centre investments against HUMAIN’s projections — GPU clusters, cooling systems, fibre networks — are investments in Vision 2030. They generate returns from a business model that is eleven months old, in a company that has not yet reported revenue, in a market that a research firm projects will reach $16.9 billion by 2032.
The Jafurah deal’s $35 billion footprint establishes BlackRock’s comfort with Saudi Arabia as a jurisdiction. Whether that comfort extends to Saudi Arabia’s AI ambitions — where the assets are newer, the revenue is projected rather than contracted, and the technology refresh cycles make 20-year leases problematic — is the test that BlackRock’s expansion will face. Jafurah’s gas will flow for decades. NVIDIA’s GB300 GPUs will be obsolete in three years. The infrastructure models are not the same. The question is whether BlackRock’s Saudi team, having mastered the first, can adapt to the second — or whether the $70-105 billion target will be achieved through replication of the Jafurah model across oil-adjacent assets rather than extension into the technology assets that PIF’s 2026-2030 strategy prioritises.
This analysis draws on Aramco’s Jafurah field specifications and 2026 gas strategy update; the Jafurah Midstream Gas Company transaction documentation (announced August 2025, closed October 2025); the EIG-led $12.4 billion Aramco Oil Pipelines transaction (June 2021) per EIG; the BlackRock Real Assets / Hassana $15.5 billion Aramco Gas Pipelines transaction (announced December 2021, closed February 2022) per Aramco; first Jafurah condensate export reporting from PGJ Online (February 2026 — Chevron, ExxonMobil, Indian Oil buyers); BlackRock’s $12.5 billion GIP acquisition closing (October 2024) per BlackRock Investor Relations; Aramco’s $8.8 billion Master Gas System Phase 3 capex (15 contracts, Q2 2024 start, Q4 2028 completion); Zawya’s reporting on the Saudi 23 GW gas-to-power conversion target and 350,000 bpd crude displacement by 2030; IMARC’s Saudi domestic gas market sizing ($10.9B in 2025 growing to $20.8B by 2034); and the CNBC reporting on the $4 billion 2019 ADNOC Oil Pipelines deal (BlackRock + KKR) that BlackRock and KKR exited in 2024. Vision2030.AI is editorially independent and is not affiliated with BlackRock, Aramco, PIF, or any official Vision 2030 entity.