03-04-2016, 09:21 AM
Pet - I was happy to see the dolomite show up in A6 but then was disappointed also in the flow test at 13 MMCFD on a 40/64” choke. I was initially thinking formation damage or flow constrained by other mechanical means (tubing / down hole choke / etc). Is it possible that the reservoir at A6 just has primary porosity only with little/no fracturing? I would think the further you move away from the western fault line, the less likely for the formation to be impacted by the folding and tearing of the matrix. Without a substantial fracture network, the permeability would be much lower than the prolific number seen in A5. Oilfield 101 refresher: porosity is the value of the "void" in the matrix where the fluid resides whereas permeability is the ability for that fluid to move through the matrix with ease and ultimately into the tubing to surface.
The recent poor drilling results on well 2 and 3 for OSH in Iraq's Taza prospect showed that their reservoir fracturing varied substantially from well to well. This made the field appraisal much lower than hoped after their initial discovery well that hit the sweet spot of the fracture network.
But keeping it real, A6 was never expected to be that great a well - it was to provide control in an unknown boundary of the field. On balance today's report is better than I hoped for.
The recent poor drilling results on well 2 and 3 for OSH in Iraq's Taza prospect showed that their reservoir fracturing varied substantially from well to well. This made the field appraisal much lower than hoped after their initial discovery well that hit the sweet spot of the fracture network.
But keeping it real, A6 was never expected to be that great a well - it was to provide control in an unknown boundary of the field. On balance today's report is better than I hoped for.