BP Takes Sole Control of Calypso Deepwater Gas Field as Woodside Exits Trinidad
BP's acquisition of Woodside's 70% Calypso stake consolidates its upstream position behind Atlantic LNG's 15 million metric ton per year liquefaction chain.
BP agreed on Thursday (2026-08-06) to acquire Woodside Energy Group's 70 percent operating stake in the Calypso deepwater gas field offshore Trinidad and Tobago, becoming the field's sole owner. The deal completes Woodside's full exit from the Caribbean country, following the Australian company's sale of its producing assets in the Greater Angostura complex to Perenco last year for AUD 206 million, or approximately $145 million.5
Atlantic LNG — the joint venture that BP co-owns with Shell PLC and Trinidad and Tobago's National Gas Co — holds 15 million metric tons per year of liquefaction capacity, according to the venture's own website. Calypso is a potential future feedgas source for those trains. Sole ownership gives BP control over a resource that would otherwise sit with an operator that no longer holds any downstream stake in Trinidad's LNG export chain.5
Woodside's withdrawal unfolded in two stages. The Greater Angostura sale handed Perenco the shallow-water Angostura and Ruby fields. Those produce roughly 300 million standard cubic feet of gas per day, around 12 percent of Trinidad and Tobago's national output, according to Perenco at the time of that deal. Calypso, early-stage and deepwater, was left behind. BP has now absorbed it.5
Calypso is not a near-term feedgas fix. BP has not disclosed a final investment decision timeline. But early-stage status made the acquisition relatively clean, and it keeps a potentially significant deepwater resource within the Atlantic LNG supply chain rather than in the hands of an unaffiliated operator.5
With Perenco now running the Angostura and Ruby fields, the feedgas picture for Atlantic LNG involves more participants than before. BP's move on Calypso is partly about managing that fragmentation. It secures a deepwater resource that could in time complement the shallow-water production base that Woodside has now vacated entirely.5
Shell's involvement in the Caribbean gas story extends beyond its Atlantic LNG stake. A June (2026-06-19) report noted that Venezuela had been moving toward a regional gas export corridor that would use Trinidad's existing liquefaction capacity, with Shell's presence on both sides of the arrangement seen as central to its feasibility. If that corridor progresses, demand on Atlantic LNG trains could increase, adding weight to an upstream resource like Calypso that remains years from first production.1
Shell's global LNG scale puts the Atlantic basin in perspective. The company's LNG sales reached 72.9 million metric tons in 2025, up 11 percent on the prior year, according to its annual report. Its LNG Outlook 2026 forecast global demand reaching nearly 700 million metric tons per year by 2050, an increase of roughly 65 percent from 2025 levels.4,2
BP's own numbers add texture. The company's gas and low carbon energy segment posted underlying replacement cost profit before interest and tax of $2,122 million in the second quarter and $3,458 million across the first half, according to its quarterly report. Reported production for Q2 was 765,000 barrels of oil equivalent per day, 2.1 percent below the same period in 2025. The Calypso deal is an upstream portfolio call, not a diversification pivot.3
Asian LNG JKM front-month stood at $21.11 per MMBtu on Friday (2026-08-07), while ICE Endex TTF front-month held at €55.74 per MWh in European trade. Those prices support Atlantic LNG economics broadly but leave limited headroom for the capital intensity of deepwater development.
BP's development timeline for Calypso is now solely its own call. How quickly the company moves the field toward a final investment decision, and what capital it commits to do so, sets the ceiling on when Calypso can contribute meaningfully to Atlantic LNG's feedgas supply.5