I think psi81 was looking for information regarding porosity for an INP project.
McGee & Assoc 2 Jan 06
"PEL 103 (INP 35%) Flax Oil Field The mean oil-in-place resource for the Patchawarra Formation and Tirrawarra Sandstone in the Flax Oil Field was estimated to be 20 mmstb with a P90 to P10 range of 8 - 36 mmstb. However, it should be noted that test data has not definitively confirmed that the reservoir fluid in the Patchawarra Formation in the Flax Oil Field is oil. The development potential of the Flax Oil Field is discussed below. The pressure data for the Flax Oil Field, derived from production tests and drill stem tests, was projected to the regional aquifer gradient line and suggested an oil-water contact for the Tirrawarra Sandstone reservoir at a level similar to that estimated from the structural mapping. A similar contact level as for the Tirrawarra Sandstone was assumed in the Patchawarra Formation. As a development approach for Flax similar to that employed on the Tirrawarra and Moorari oil fields is likely to be applicable, available reservoir and production data for these fields were reviewed. It was concluded that the main reservoir and hydrocarbon properties encountered in the Flax field were analogous to those prevailing in the nearby Tirrawarra and Moorari oil fields. Akin to the Tirrawarra and Moorari oil fields, the Permian oil reservoirs in PEL 103 are expected to have no aquifer support, and will rely on gas expansion from solution gas as the primary recovery mechanism. The associated gas from Flax has a high LPG content, and when reinjected is likely to provide a miscible or near miscible flood with a reasonable recovery during the enhanced oil recovery (EOR) phase. The reservoir sandstones have an average permeability and porosity of 1 to 2 md and 11% respectively, which is similar to the Tirrawarra and Moorari oil fields. Fracture stimulation was used at Tirrawarra/Moorari to enhance productivity and will also be needed at Flax. EOR was successful at Tirrawarra/Moorari where average recovery efficiencies of around 25% were achieved despite inconsistent injection rates and an inefficient ethane injection phase. Recoveries of greater than 30% were achieved within the well spot patterns in the Tirrawarra Oil Field. In defining the recovery factors to be used in determining the oil reserves for the Flax Oil Field, the production performance of Flax 1, both pre- and post- fracture stimulation, was examined. Consideration was also given to the thinner Tirrawarra Sandstone unit (11 metres cf 21 metres in Tirrawarra field) and the presence of some limited high permeability streaks in the Tirrawarra field that have yet to be shown to be present in the Flax Oil Field. This led to a recovery factor of 20% being applied to the in-place Tirrawarra Sandstone resource, assuming pressure maintenance by rich gas injection and fracture stimulation of the wells. In the case of the Patchawarra Formation, no production testing has been performed to date and uncertainty over reservoir connectivity led to the application of a 15% recovery factor to the Patchawarra Formation resource. On this basis, the planned development of the Flax Oil Field is expected to recover mean reserves of 3.2 mmstb.
CTP Price at posting:
45.0¢ Sentiment: Hold Disclosure: Held
