Ann: Hydrocarbon gas recovered & evaluation program forward plan, page-1432

Actually no, we should not conclude that the sands in the Upper Angwa are low poro perm because that would contradict the current evidence from M-2 (and initially observed in M-1) that the mud losses and differential sticking are due to good permeability.

Having too much mud overbalance (2500 psi) as occurred in M-1 and M-1ST was sure to cause formation damage, and consequently a "skin" effect can be interpreted as an additional dP from well test analysis (I am explaining this for the benefit of non oil and gas people). We do not need to have broken or fractured core plugs as evidence of formation damage - it can be manifest as pore structure damage making the core sample non representative. Thin section and CT scans are invaluable in determining the degree of damage.