The company said its initial assessment of the well results suggest that the Lancaster field is "likely to be significantly greater than the 200 MMbbls 2C case." However, these results are subject to refinement of the provisional data.
This proved a minimum oil down to of 1,620 m (5,315 ft) TVDSS, 240 m (787 ft) TVD below structural closure, confirming the reservoir model for Lancaster. Management believes similar results could be replicated on its nearby Lincoln, Warwick, and Typhoon prospects and Whirlwind discovery.
DST testing of the basement reservoir delivered a maximum natural flow rate of 6,600 b/d, boosted via artificial lift to 11,000 b/d, with no formation water produced. The flow is though to emanate from a single fault zone.
Wireline and well test data indicate that no pressure barriers were detected in the reservoir, and wireline oil samples have been recovered to surface from deeper than the minimum oil down to case.
Drilling has since started on the sidetrack horizontal well.
Hurricane has also progressed plans for the early production system, and now anticipates a 62 MMbbl development with life‐of‐field operating costs of $26/bbl.
It will continue to work with FPSO and subsea production facility providers in the run-up to a final investment decision during the first half of next year.
A seabed and environmental survey has been completed over areas adjacent to Lancaster and Lincoln which might be required for FPSO moorings.
"The combination of high flow rates, an extensive oil column, and underlying aquifer materially de-risks Hurricane’s plans for a future Lancaster field development and further underlines the potential of the fractured basement west of Shetland," Hurricane CEO Robert Trice said.