Santos: The A$36 Billion Takeover That Collapsed and What Came Next

Three separate attempts to acquire Santos have now failed, which tells you more about Australian energy M&A than about Santos. Foreign buyers are consistently attracted to Australian LNG equity and consistently defeated by the combination of Foreign Investment Review Board scrutiny, domestic gas politics, union and community opposition, and the sheer complexity of joint venture structures with pre-emption rights. This article covers the company, the bid and what happens now.

What is Santos and where does it operate?

Santos was founded in 1954 in Adelaide as South Australia Northern Territory Oil Search, and the Cooper Basin gas it developed became the backbone of eastern Australian domestic gas supply for decades. It remains Australia’s second-largest producer of oil and gas after Woodside.

The modern portfolio spans four positions. Darwin LNG in the Northern Territory, now backfilled by the Barossa field. GLNG at Gladstone in Queensland, converting coal seam gas into LNG. A minority interest in PNG LNG, operated by ExxonMobil, which is among the most profitable LNG projects in the world. And Pikka, an oil development on Alaska’s North Slope.

Santos also holds a stake in the TotalEnergies-operated Papua LNG project, which has been repeatedly delayed and has been targeting a final investment decision. Together, its equity LNG interests total roughly 4.83 million tonnes a year — the asset that made it attractive to a Gulf buyer looking to scale an LNG portfolio quickly.

What exactly happened with the XRG takeover?

In June 2025 a consortium comprising XRG (ADNOC’s international investment vehicle), Abu Dhabi state investor ADQ and US private equity firm Carlyle made a non-binding, all-cash indicative offer of US$5.76 per share, valuing Santos at about US$18.7 billion or A$36.4 billion. It was roughly a 28% premium to the prior close, and the Santos board indicated it would recommend the offer subject to due diligence.

The exclusivity period was extended twice while the consortium worked through due diligence and regulatory pathways. On 17 September 2025 XRG announced it would not proceed. Santos said the consortium “would not agree to an appropriate allocation of risk” under the scheme implementation agreement, specifically on the obligation to secure regulatory approvals and on a commitment to domestic gas development and supply.

Reporting around the collapse pointed to additional friction: a long-running methane leak at the Darwin LNG facility that the consortium learned about from media reports, and a late request that the buyer bear capital gains tax normally borne by selling shareholders. Whatever the precise weighting, the pattern is familiar — the deal died on risk allocation, not on price.

Why do foreign takeovers of Australian energy keep failing?

Because the approval process assesses more than competition. The Foreign Investment Review Board considers national interest, which in energy includes domestic supply security, tax outcomes and the character of the acquirer. A state-owned Gulf oil company buying Australia’s second-largest gas producer is precisely the transaction that attracts the most political and union attention, and the Offshore Alliance and other groups publicly urged the government to block it.

There is also a structural obstacle. Santos’s most valuable assets are minority interests in joint ventures operated by others, and those agreements typically carry pre-emption rights allowing partners to match a sale. A corporate takeover can sometimes sidestep them, but the uncertainty is real and expensive to resolve.

For the seller, a failed bid is not neutral. It removes a valuation floor, invites questions about board and management performance, and leaves the company obliged to deliver the standalone case it had been prepared to abandon. Analysts questioned the tenure of chairman Keith Spence and chief executive Kevin Gallagher immediately afterwards, and target prices were cut.

What is Barossa and why was it contentious?

Barossa is an offshore gas field in the Timor Sea developed to backfill Darwin LNG, whose original Bayu-Undan feedstock had been depleted. It delivered first gas on 22 September 2025, five days after the takeover collapsed, restoring production at a facility that had been idle.

The project faced sustained legal and regulatory challenge. Litigation over consultation with Tiwi Islands Traditional Owners halted drilling at one point and forced a redesign of the pipeline route, and environmental groups labelled the field high-carbon because of its relatively high reservoir carbon dioxide content. Santos ultimately obtained the approvals it needed, but only after significant delay and cost.

The strategic lesson is that in Australia, the technical risk in an offshore gas project is now often smaller than the consultation and approvals risk. Every developer in the sector has repriced the time and expense of social licence accordingly, and that repricing is one reason Australian LNG growth has slowed while US Gulf Coast projects have accelerated.

What does the standalone case actually look like?

Higher volumes from lower spending. Barossa and Pikka phase one both came online within eight months of each other, and Santos has guided that unit production costs should trend lower as those volumes ramp. Analysts have suggested combined project delivery could lift output materially by 2027, which changes the cash generation profile substantially.

The capital cycle turns at the same time. After several years of construction spending, capital expenditure falls once projects are complete, and the difference between a company spending heavily and one harvesting is not incremental — it is the entire free cash flow line. Santos has committed to a capital management framework directing that cash toward shareholder returns while reinvesting to backfill existing infrastructure.

The remaining growth optionality is Papua LNG, where Santos holds a minority position in a TotalEnergies-operated project targeting final investment decision. If it proceeds, Santos gains further LNG equity without operating responsibility; if it does not, the company becomes a much simpler cash-returning business, which some shareholders would prefer.

How should CFOs read the Santos story?

As a lesson about optionality and timing. Santos ran a build programme through a period of high capital costs and contested approvals, then received a full-priced offer just as the projects were about to deliver — and lost it. Shareholders were offered a certain outcome and now hold an uncertain one, which is the definition of execution risk transferred back onto the owner.

It is also a lesson about disclosure discipline in an M&A process. Whatever the merits, an acquirer discovering a material operational issue through media coverage rather than the data room damages trust irreparably. Due diligence is a trust-building exercise as much as an information exercise, and surprises are disproportionately costly.

Finally, it demonstrates how much of Australian energy value now depends on policy. Domestic gas obligations, the Australian Domestic Gas Security Mechanism, environmental approvals and foreign investment screening are not background conditions — they were, on Santos’s own account, among the reasons a A$36 billion transaction did not complete.

How does Santos fit into east coast gas supply?

Centrally, and that is part of why the takeover attracted political attention. Santos’s Cooper Basin operations have supplied eastern Australian domestic gas for decades, and its GLNG project at Gladstone both exports LNG and buys gas from the domestic market to fill its trains — a structure that makes it simultaneously a supplier and a competitor for the same molecules.

That dual role is why domestic gas commitments were a live issue in the XRG negotiations. Any acquirer of Santos inherits a position in the east coast supply balance, and Australian governments have shown they will use the Australian Domestic Gas Security Mechanism and heads of agreement to extract domestic supply commitments from exporters.

For a foreign state-owned buyer, that is an unusual form of regulatory risk: not a licence condition or a tax rate, but an open-ended expectation that the asset will be operated partly in the national interest of another country. Pricing that expectation into a bid is close to impossible, which is a large part of why the deal did not complete.

What is Pikka and why is Santos in Alaska?

Pikka is an onshore oil development on Alaska’s North Slope in which Santos holds an operated majority interest, delivering first oil on 18 May 2026. It is a conventional oil project in a mature basin with existing pipeline infrastructure, which makes it lower-risk technically than a frontier development even though the location is remote.

The strategic rationale is liquids exposure. Santos’s portfolio is heavily weighted to gas and LNG, whose contract prices are often oil-linked but whose margins are compressed by liquefaction and shipping costs. Direct oil production converts a barrel of reserves into revenue with far less infrastructure between the wellhead and the buyer.

The critique is portfolio coherence. A mid-cap Australian producer operating in Alaska, Papua New Guinea, the Timor Sea, Queensland and South Australia carries a management and capital burden that a more concentrated peer does not. Every failed takeover renews the question of whether Santos should simplify rather than diversify.

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