What a standalone gas division actually changes – Saudi Aramco Looking Ahead

On paper, this looks like an org chart. In practice, it is a financing and accountability decision.

Gulf national oil companies have spent the last several years listing or monetizing everything except the core oil barrel. ADNOC listed pieces of gas, drilling, and retail. Aramco already listed SABIC and has raised billions against pipelines and midstream assets. The Jafurah processing system itself was packaged last year into an $11 billion lease-and-leaseback with a BlackRock/GIP-led consortium. A gas division with its own president is the next step: a clean vehicle that can raise project finance, sell minority equity, and chase LNG deals without putting Ghawar on the table.

The operating footprint is already large enough to justify the split. Aramco is the Kingdom’s exclusive gas supplier. Sales-gas production averaged about 11.4 billion standard cubic feet per day in 2025. Raw-gas processing capacity reached 19.6 bscfd by year-end. The official target is to lift sales-gas production capacity by about 80 percent from 2021 levels by 2030, taking total gas and associated liquids to roughly 6 million barrels of oil equivalent per day. Incremental operating cash flow from that expansion is estimated at $12 billion to $15 billion in 2030, subject to domestic demand and liquids prices.

Jafurah is the centerpiece. The unconventional field covers about 17,000 square kilometers and is estimated at 229 trillion standard cubic feet of raw gas and 75 billion stock tank barrels of condensate. First shale-gas production started in December 2025. By 2030 Aramco wants 2 bscfd of sales gas, 420 million scfd of ethane, and about 630,000 barrels per day of high-value liquids from the play. Tanajib, one of the world’s largest gas plants, also started up in December 2025 and is expected to reach 2.6 bscfd of raw-gas processing in 2026 from associated gas at Marjan and Zuluf. Master Gas System Phase 3 is scheduled to add about 3.15–3.2 bscfd of transmission capacity by 2028 through roughly 4,000 kilometers of new pipeline and 17 compression trains, extending gas to more western and southern demand centers.

A standalone division does not invent those assets. It isolates them so gas can be measured, funded, and marketed as a business rather than as the leftover stream from oil.

What it means for the Saudi grid

Saudi electricity is the reason this matters.

For years the Kingdom has burned crude and fuel oil to keep air conditioners, desalination plants, and industry running through 40-plus-degree summers. Natural gas already supplies the majority of generation—recent estimates put gas around 62 percent and oil around 38 percent, with renewables still a rounding error—but oil remains the swing fuel when temperatures spike or associated gas slips. Combined crude and fuel-oil burn has run well above 1 million barrels per day at summer peaks and was still close to that level even after early displacement gains.

Vision 2030’s Liquid Fuel Displacement Program aims to take more than 1 million barrels of oil equivalent per day out of domestic use by 2030, with the utilities sector carrying most of the load—nearly 860,000 barrels of oil equivalent per day in official planning language. The power mix target is a 50/50 split between gas and renewables by 2030. Plant conversions are already under way, including the 3.5 GW PP10 complex near Riyadh and a broader Saudi Electricity Company slate of more than 22 GW of liquid-to-gas conversions.

Gas is the only fuel that can do the baseload half of that job at the speed the grid needs. Solar helps at midday. It does not keep the system up at 9 p.m. in August. That is why Aramco raised the gas-growth target from 60 percent to 80 percent and why CEO Amin Nasser has said the company intends to replace a million barrels of oil with gas as cities, industry, and now data centers pull more power.

The displacement math is already in the public numbers:

Aramco has said the unconventional gas program, with Jafurah at the core, is expected at peak to generate electricity equivalent to displacing 500,000 barrels per day of crude.

Rystad Energy has estimated Jafurah alone could offset up to 350,000 bpd of crude burn by 2030, starting small in the first year of production and rising as phases come online.

Other industry estimates put Jafurah’s oil-displacement contribution above 300,000 bpd at maturity, with the wider gas program approaching 500,000 bpd.

Those barrels do not disappear. They become exportable crude, condensate, and refined product—or, in a tight export-route year, a buffer Aramco can choose not to burn at home.2026 also showed why the standalone gas push cannot wait. After oilfield shut-ins tied to disrupted export routes, associated-gas output slipped, and Saudi fuel-oil imports jumped to about 360,000 bpd in April. Analysts warned that crude-plus-fuel-oil burn for power could again exceed 1 million bpd in summer, reversing the 2025 improvement. A gas division with its own capital budget is a bet that Jafurah, Tanajib, and the Master Gas System will make that relapse the exception rather than the planning assumption.

The oil that can be sold instead of burned

This is the commercial core of the story.

Saudi Arabia has been consuming a French-sized oil market inside its own power sector at peak. Every incremental bscfd that reaches a converted turbine is a barrel that can go to Yanbu or Ras Tanura instead of a boiler. At $70 a barrel, 500,000 bpd of freed crude is nearly $13 billion a year of export revenue. The full Liquid Fuel Displacement Program, if executed across power, desalination, industry, and agriculture, is a 1 million bpd prize. That is why Aramco can talk about $12–15 billion of incremental gas-related operating cash flow in 2030 and still be understating the national balance-sheet effect, because the oil not burned is additional sovereign export capacity.

There is a second liquids story inside the gas story. Jafurah is liquids-rich. Condensate cargoes have already been sold to U.S. and Indian buyers, with Aramco lining up regular 500,000-barrel liftings. Ethane and NGLs feed petrochemicals. The gas division, if carved out cleanly, captures both the molecules that keep the lights on and the liquids that look a lot like light crude in a tanker.

Rebalancing the grid toward gas is therefore not a climate talking point. It is an export-optimization program. Burn gas at home. Sell oil abroad. Use the cash to fund Vision 2030, dividends, and the next increment of gas infrastructure.

LNG exports: portfolio first, Saudi molecules later

Readers should not confuse a standalone gas division with an imminent Saudi LNG export terminal flooding the Atlantic Basin.Domestic demand is the binding constraint. Power, desalination, industry, and incoming AI load will absorb most new Jafurah and associated-gas volumes through 2030. Aramco’s own language puts Kingdom demand first. A large dedicated LNG plant on the Gulf or Red Sea only becomes logical after the Liquid Fuel Displacement Program is largely done and the Master Gas System has spare molecules. Until then, “LNG export” for Aramco means a trading and equity portfolio, not a second Qatar.

• That portfolio is already being assembled:
• Long-term target of about 20 million tonnes per annum of LNG capacity, as stated by CEO Amin Nasser, with a smaller volume already in progress.
• A 20-year offtake of 1.2 mtpa from NextDecade’s Rio Grande LNG Train 4 in Texas.
• A 20-year SPA with Commonwealth LNG in Louisiana for 1 mtpa, with earlier reporting of an option to move toward 2 mtpa.
• A strategic stake in MidOcean Energy, which has been used to gather interests across existing and developing LNG projects.
• Additional heads of agreement and talks around U.S. Gulf Coast expansion projects.

A standalone gas division is the natural home for that book. Offtake contracts, shipping, trading, and minority liquefaction stakes can sit in a vehicle investors understand. They can be listed, leveraged, or used as currency in future asset swaps. They do not require Aramco to divert Jafurah gas away from Riyadh’s turbines in 2027.

Could Saudi-origin LNG come later? Yes, if displacement works, if renewables take a real share of the daytime load, and if non-associated gas overshoots domestic call. The reorganization keeps that option alive without pretending the option is already in the money.

The competitive clock

A frequent quest on the Energy News Beat Podcast, Prandelli’s comparison with XRG is the uncomfortable part of the analysis. ADNOC’s international gas arm has been buying into projects while Aramco has been defending crude logistics and standing up Jafurah. Rio Grande, Turkmen gas, Venezuelan acreage, Argentine LNG-linked blocks, and reported interest in Canadian LNG are the kind of positions that are easier to take before the next wave of FIDs is fully spoken for.

Aramco is not late at home. Jafurah, Tanajib, and Master Gas System Phase 3 are real steel. It is late, or at least later, in the global equity-and-offtake race. A listed or listable gas division is how Riyadh tries to close that gap with other people’s capital while keeping operational control—the same ADNOC playbook, executed a cycle behind.

The near-term risk is that geopolitics keeps stealing associated gas and forcing oil back into the power stack, which would delay both the export dividend and the moment when surplus Saudi gas could support a domestic LNG train. The medium-term opportunity is the opposite: a grid that runs on gas and solar, a crude stream that is no longer a power-plant feedstock, and an LNG trading desk that can sell U.S. and other molecules into Asia and Europe under the Aramco name.

That is what a standalone gas division means. It is not a rebrand. It is an attempt to make gas pay for itself, stop burning the export barrel in the desert, and enter the LNG market as a structured business instead of as an afterthought to oil.

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Appendix: Sources and links