BP Completes Second Atlantis Expansion, Lifts Gulf Deepwater Capacity by 10,000 Boed
Back-to-back expansions at BP's Atlantis field add 25,000 boed in total, with a larger $5 billion Tiber-Guadalupe project targeted for first production around 2030.
BP raised production capacity at its Atlantis deepwater field in the Gulf of America by 10,000 barrels of oil equivalent per day on Thursday (2026-07-30). It was the second expansion at the asset within twelve months and the latest step in a Gulf build-out the company is pursuing while scaling back its position in the North Sea.3
The addition came via two new subsea water injection wells, completed ahead of schedule and under budget, according to BP. Before either expansion began, Atlantis was already running at a declared peak of 200,000 barrels of oil and 180 million cubic feet of gas per day. BP puts the field's estimated recoverable resources at 275 million barrels of oil equivalent.3
An earlier project, the Atlantis Drill Center 1 Expansion, added 15,000 boed when it completed in late 2025. Together, the two programmes have added 25,000 boed of new capacity at a field already producing near its declared peak before either project began. Both were delivered under budget and ahead of schedule, BP said.3
That execution record reflects a broader set of portfolio decisions. In June (2026-06), Bloomberg and the Financial Times reported that BP was weighing a sale of all or part of its UK upstream business, potentially worth around £2 billion ($2.7 billion), and that talks with Ithaca Energy as a prospective buyer had fallen through. New capital is going to the Gulf of America.2
BP's finances support the investment. The company reported 1Q26 underlying replacement cost profit of $3.2 billion, more than double the prior quarter's $1.5 billion. Reported profit for the same period was $3.8 billion, according to BP's quarterly report. The effective tax rate fell to 32% from 43% in the prior quarter, reflecting a shift in the geographic mix of profits.1
The bigger Gulf commitment is still years away. BP sanctioned the Tiber-Guadalupe oil project last year, targeting first production around 2030 from a new production platform, BP's seventh operated in the Gulf, designed for 80,000 barrels per day. The development involves six wells in Tiber and a two-well tieback in Guadalupe, budgeted at $5 billion in total investment. BP estimates the initial phase holds around 350 million boe of recoverable resources.3
ICE Brent crude front-month was trading at $90.15 per barrel as of Wednesday (2026-07-29), and NYMEX WTI crude front-month settled at $85.00 per barrel on the same date. At those levels, deepwater Gulf oil production sits well inside the money. NYMEX Henry Hub front-month gas sat at $2.65 per MMBtu on Wednesday (2026-07-29), down 0.38% on the session, though the softness in gas prices carries limited weight for predominantly oil projects in the deepwater Gulf.
The gap in complexity between the Atlantis water injection expansions and the Tiber-Guadalupe greenfield is considerable. Adding injection wells to an established deepwater installation is operationally proven. A new $5 billion production platform with a six-well drilling programme, executed across a four-year schedule, is a different undertaking, where cost inflation and contractor availability can press against the original sanction figure.3
But BP's Atlantis record lends the programme some credibility. Two expansions, both delivered early and under budget, against a high-producing deepwater field operating near its declared limits. Tiber-Guadalupe will test whether that discipline carries into new-platform construction at a time when offshore supply chains remain under pressure. BP's next capital guidance update is where any early cost movement against the $5 billion sanction estimate will first show up.3