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.
- Forums
- ASX - By Stock
- CTP
- flow testing
flow testing, page-31
Featured News
Add CTP (ASX) to my watchlist
(20min delay)
|
|||||
Last
4.9¢ |
Change
0.000(0.00%) |
Mkt cap ! $36.26M |
Open | High | Low | Value | Volume |
0.0¢ | 0.0¢ | 0.0¢ | $0 | 0 |
Buyers (Bids)
No. | Vol. | Price($) |
---|---|---|
2 | 513087 | 4.9¢ |
Sellers (Offers)
Price($) | Vol. | No. |
---|---|---|
5.0¢ | 150000 | 1 |
View Market Depth
No. | Vol. | Price($) |
---|---|---|
2 | 513087 | 0.049 |
2 | 16822 | 0.048 |
1 | 100000 | 0.046 |
2 | 173952 | 0.045 |
1 | 50000 | 0.044 |
Price($) | Vol. | No. |
---|---|---|
0.050 | 150000 | 1 |
0.054 | 96554 | 1 |
0.055 | 86605 | 1 |
0.056 | 19995 | 1 |
0.058 | 172431 | 1 |
Last trade - 07.00am 13/09/2024 (20 minute delay) ? |
Featured News
CTP (ASX) Chart |
Day chart unavailable