Shell (LSE: SHEL) shelves Trinidad Aphrodite gas project despite earlier FID

Shell plc (LSE: SHEL, NYSE: SHEL) has shelved its Aphrodite offshore gas project in Trinidad and Tobago for the time being after commercial negotiations with state-owned National Gas Company failed to produce acceptable gas-sale terms, reversing momentum on a development that had already received a positive final investment decision in 2025. Shell has released the jack-up rig intended for the drilling programme and is reassessing the project schedule, according to Reuters, putting the previously targeted 2027 first-gas date in doubt. Aphrodite had been expected to deliver approximately 100 million cubic feet per day at peak, equivalent to about 18,400 barrels of oil equivalent per day, through existing infrastructure in Shell’s East Coast Marine Area. The setback is modest relative to Shell’s global portfolio but materially more important to Trinidad, where declining gas availability has constrained LNG and petrochemical utilisation.

The reversal is particularly striking because Aphrodite was designed as a comparatively low-complexity backfill development rather than a stand-alone megaproject. Shell’s 2025 annual report said the field would connect into existing subsea infrastructure and send gas to the Dolphin A platform, allowing the company to use an established offshore and processing system. Shell had argued that Aphrodite and the much larger Manatee development could help sustain Trinidad and Tobago’s gas sector into the 2030s.

How did Aphrodite move from final investment decision to being shelved?

Shell announced a positive investment decision on Aphrodite in 2025, but regulatory and commercial work remained outstanding afterward. Its annual report continued to describe the project as subject to regulatory approvals, while Trinidad’s government was still awaiting a formal field-development plan and other requirements late in 2025. A final investment decision therefore demonstrated Shell’s willingness to proceed under assumed conditions but did not eliminate every governmental and commercial dependency.

The latest problem is the gas-sale arrangement with National Gas Company. Reuters reported that negotiations failed to reach terms capable of supporting the development, leading Shell to release the rig that had been designated for Aphrodite. Gas pricing is central because a technically straightforward tie-back can still fail investment thresholds if the producer cannot secure sufficient value for the molecules delivered into the domestic system.

Releasing the rig makes the pause more substantive than a negotiating delay on paper. Offshore drilling capacity is scheduled well in advance, and once a rig is reassigned, restarting a project can require finding another suitable operating window, renegotiating contractor terms and adjusting the broader offshore campaign.

Why was Aphrodite supposed to be an attractive backfill project?

Aphrodite is located in the East Coast Marine Area, where Shell already operates major gas-producing fields and associated infrastructure. The planned development would connect into existing subsea systems and route gas through the Dolphin A platform instead of requiring an entirely new offshore production hub.

That infrastructure advantage typically reduces both development cost and lead time. A producer can focus capital on wells, subsea connections and required modifications rather than building a new platform, pipeline and processing chain from scratch.

Peak output of about 18,400 boepd is small by Shell’s global standards, but the economics should be assessed relative to incremental capital and the value of filling spare infrastructure. Aphrodite’s purpose was not to become a globally significant field; it was to keep existing Trinidad facilities supplied with gas as older reservoirs decline.

Why does losing 100mmcfd matter so much to Trinidad and Tobago?

Trinidad has spent years confronting declining domestic gas production while supporting two large gas-consuming industries: LNG exports and petrochemicals. Atlantic LNG remains one of the country’s most important industrial assets, and Shell holds major interests across its trains, but insufficient feedgas has prevented the facility from operating consistently at its theoretical capacity.

Aphrodite’s approximately 100 mmcfd would not solve that structural shortage by itself. It would nevertheless represent dependable incremental supply flowing through infrastructure already tied into Trinidad’s wider gas system, which is why the project carried more national importance than its modest production rate suggests.

The country’s Energy Ministry has explicitly described restoring gas availability as necessary for industrial output, government revenue and foreign-exchange earnings. Its recent focus on accelerating Manatee, reviving mature assets and attracting new deepwater exploration reflects an attempt to rebuild supply from several sources rather than relying on one field.

Can Shell simply replace Aphrodite volumes with Manatee?

Manatee is much larger. Shell expects the project to reach around 104,000 boepd at peak and continues to target first gas in 2027, making it potentially several times the size of Aphrodite. The government has been working with Shell on whether still greater Manatee volumes could be delivered to the domestic market.

The two projects are not perfect substitutes, however. Trinidad needs multiple backfill sources because offshore fields decline over time, while new gas has to support LNG, petrochemical plants and domestic electricity demand simultaneously. A larger Manatee contribution can reduce the immediate effect of Aphrodite’s delay but does not make the lost 100 mmcfd economically irrelevant.

Concentrating expected growth in fewer projects also raises execution exposure. If Manatee experiences schedule or ramp-up problems, the absence of Aphrodite would leave less incremental supply available to offset mature-field decline.

Could Venezuelan gas eventually fill the gap?

Trinidad has also pursued the Dragon and Loran-Manatee cross-border resources involving Venezuela, with Shell positioned as a key participant. Those projects could offer larger regional supply options, but their history demonstrates why Trinidad cannot treat cross-border gas as certain replacement volume. Progress has repeatedly depended on United States sanctions licences, bilateral arrangements and political relations alongside conventional project economics.

The Aphrodite pause therefore reinforces the value of diversification. Trinidad needs domestic developments, mature-field optimisation, new exploration and cross-border imports progressing in parallel if it wants to rebuild utilisation across the downstream gas chain.

Recent approval for Occidental Petroleum to partner Exxon Mobil Corporation in the TTUD-1 ultra-deep block adds another exploration route, but frontier drilling cannot replace near-term backfill because a discovery would still require appraisal and development.

What would have to change for Shell to revive Aphrodite?

The immediate requirement is commercially acceptable gas-sale terms. The precise disagreement has not been publicly quantified, so it would be speculative to identify a specific price needed to restart the project. Shell and National Gas Company would need a structure that makes the development economic for the producer while remaining workable for Trinidad’s downstream customers.

Regulatory timing also matters. Shell’s previous disclosures showed that government approvals remained part of the project pathway even after FID. Any material revision to development schedule, drilling configuration or commercial arrangements could therefore interact with the outstanding regulatory process.

The rig decision makes 2027 first gas increasingly difficult unless negotiations are resolved quickly and drilling capacity can be remobilised without a major scheduling penalty. Shell has not formally cancelled the resource, so Aphrodite retains option value, but the project has moved from sanctioned growth into an uncertain holding pattern.

What does Aphrodite tell investors about Shell’s LNG growth strategy?

For Shell shareholders, Aphrodite is too small to alter group earnings materially by itself. Its wider significance lies in Shell’s strategy of using relatively low-cost backfill developments to keep existing LNG and gas-processing infrastructure operating at high utilisation.

That strategy works particularly well when commercial agreements are straightforward because existing plants have already absorbed much of their capital cost. Trinidad shows the limitation: infrastructure can exist, gas can be discovered and a project can even reach FID, but value still cannot be created if upstream pricing and downstream affordability cannot be reconciled.

Shell remains one of the world’s largest LNG suppliers and continues developing substantially larger gas projects elsewhere. Aphrodite nevertheless offers a useful reminder that mature LNG systems are only as valuable as their future feedgas. For Trinidad, resolving that equation has now become more urgent because one of the projects expected to help bridge the supply gap has moved backward rather than forward.

Meta description: Shell has shelved Trinidad’s Aphrodite gas project after commercial talks failed, putting a planned 100mmcfd source and 2027 start at risk.

LinkedIn hook: Shell had already sanctioned Aphrodite and planned roughly 100mmcfd of gas through infrastructure that largely already exists. Yet the rig has now been released because the gas-sale economics could not be agreed, exposing how commercial terms rather than geology can strand valuable backfill in a gas-short LNG market.