This decision follows the completion of extended wireline logging activities after some equipment malfunctioned.

But the Perth-based company is still uncertain about the well’s commercial viability.

Log results from Mputa-2 have confirmed that the upper reservoir sands intersected in Mputa-1 and Waraga-1 were laterally extensive, but at this location are water wet, according to Hardman.

Pressure data also confirms that a 100m hydrocarbon column exists in the upper zone of the Mputa field, although at this upper level, the Mputa and Waraga structures do not have a common oil leg, the company said.

“The implications of this pressure data and the fact that the target sands came in over 100 metres shallow to prognosis are both positive to the interpretation of the Mputa Field,” Hardman chief executive Simon Potter said.

“The new data is being integrated with existing models in order to provide estimates of oil in-place for these upper sands shortly.”

Potter added that potential production flow rates from these sands would be determined once flow-testing operations begin at Waraga-1, expected in mid-June.

Meanwhile, oil samples recovered from the lower reservoir zone in Mputa-2 can be correlated to similar oil-bearing zones in both Mputa-1 and Waraga-1, the company said.

“The presence of oil-saturated sands in these basal units in all wells drilled to date implies an extensive stratigraphic trapping mechanism at this level,” Potter said.

“The gross interval of these units is variable and there does not appear to be pressure communication between them.”

But contained within the sequence are “obvious” oil-bearing zones, totalling about 5m thickness, which will be flowed in Hardman’s Waraga-1 flow-testing program to determine if they can produce sustained commercial flow rates.

This information will subsequently determine if Mputa-1 or Mputa-2 will be flow-tested.

“Assessing where the thicker sand units and more extensive net pay exist in these sequences will be key to their commercial potential and the need for 3D seismic acquisition is currently being evaluated,” Potter said.

“The results from the three discovery wells and the testing program will be integrated to define the reserve estimates, commerciality and potential development scenarios for the onshore area.”

Hardman has also started planning additional onshore exploration/appraisal wells and a test of a prospect just offshore, expected to start drilling in the fourth quarter of this year.

Plans for the acquisition of further 2D seismic data in the north of the block are also well advanced, Potter said.

The Block 2 Ugandan joint venture comprises Hardman and Tullow Oil (each holding a 50% stake).