Project highlight: BP’s Cypre gasfield

Trinidad and Tobago

October 8, 2024

The Cypre gasfield is BP’s next major offshore gas development in Trinidad and Tobago. It will add up to 8.5 mcm (300 mcf) of daily production and bolster the contributions of the Corallita and Lantana fields to the domestic gas market.

Cypre is a conventional gasfield that lies approximately 78 kilometres off the southeastern coast of Trinidad and Tobago, located in the East Mayaro block in water depths of around 80 metres. It is BP’s third subsea development and is envisioned as a seven-well project tied back via 14 kilometres of new, large-diameter flexible flowlines to BP’s Juniper platform, which has been in place since 2017.

KEY PLAYERS: Cypre is being developed by BP Trinidad and Tobago (BPTT), a consortium between UK major BP (70%) and Spanish energy and petrochemicals company Repsol (30%).

INVESTMENT: An FID on the USD 854-million Cypre project was reached in 2022. The total investment since the outset of the Juniper development is estimated at around USD 2 billion.

CONTRACTORS: Aker Solutions was contracted in 2019 to provide FEED for Cypre’s Juniper platform, and the platform topsides were fabricated at the TOFCO yard in La Brea, Trinidad and Tobago. Subsea Integration Alliance, which brings together Subsea7 and SLB’s OneSubsea, has been awarded the design and EPCI contract for Cypre’s two-phase liquid natural gas tieback to Juniper, while UK offshore engineering company Aquaterra Energy is providing subsea riser systems and connectors.

PRODUCTION: bpTT spudded Cypre’s debut well in February 2024. First gas from the field is expected in 2025, and BP anticipates producing between 7.1-8.5 mcm (250-300 mcf) per day when production peaks in 2026. The extracted gas will add to that of the Corallita and Lantana fields, in operation since 2017, and be used to meet BP’s supply commitments in Trinidad.

POWER AND EMISSIONS: The Cypre development will utilise BP infrastructure already in place and will receive power from the Juniper platform, thereby saving on having to install new systems and enabling the development to bring gas to market with a minimal increase in operating emissions.

Photo of the Joe Douglas rig courtesy of BP.

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