Namibia Walvis Basin PEL 37
- Tullow Namibia Limited (Operator) 35.00%
- ONGC Videsh Limited 30.00%
- Pancontinental Oil & Gas Group 20.00%
- Africa Energy Corp. 10.00%
- Paragon Oil & Gas (Pty) Ltd 5.00%
A number of ponded turbidite, slope turbidite, basin floor turbidite fans and channels forming very large leads and prospects closely associated with, and within the Inner Graben of PEL 37 have been identified and mapped. The first exploration well on the +120MMBBL potential Cormorant Prospect is due in September 2018 .
Namibia Orange Basin PEL 87
- Pancontinental Orange Pty Ltd 75.00%
- Custos Investments (Pty) Ltd 15.00%
- National Petroleum Corporation of Namibia (NAMCOR) 10.00%
Water depths are between 500m and 3,200 m and the area is on trend with the actively explored Total / Impact Oil and Gas deepwater block, the subject of a farmin by Total in October 2017.
Pancontinental has a large interest in this area. Preliminary mapping already shows evidence of traps in large turbidite fan plays .
Kenya Lamu Basin L6
- FAR Limited (Operator) 60.00%
- Pancontinental Oil & Gas Group 40.00%
- Milio International Group 0.00%
- FAR Limited (Operator) 24.00%
- Pancontinental Oil & Gas Group 16.00%
- Milio International Group* 60.00%
* after earn in
The Kifaru Prospect and Kifaru West Prospects are interpreted to be large stacked Miocene reefs, with interpreted good lateral and top seals and close proximity to mature Eocene source rocks.
The Tembo Prospect is a large tilted fault block trap, with interpreted sandstone reservoirs at a number of levels.
- UIL Energy (Operator) 30.00%
- Pancontinental Oil & Gas NL** 70.00%
**Assumes option exercised to earn the interest by funding a 3D seismic survey in 2018, covering the Walyering Gas Field.
A thick interbedded fluvio-deltaic sandstone reservoir system is present with top and lateral seals mostly provided by intra-formational shales and siltstones.
The target reservoirs are relatively deep, between 3,000m and 4,000m but when drilled correctly have been shown to have good natural flow potential. The Upper Cattamarra Coal Measures sand reservoir in Walyering-1 flowed naturally to surface at up to 13.5 MMcfd.
The reservoirs and trapping mechanism are very similar to that in the producing Gingin – Red Gully gas fields on geological trend some 80 km to the south.
USA California Sacramento Gas Basin Dempsey Gas Project
- Sacgasco Limited (Operator) 50.00%
- Empyrean Energy PLC 30.00%
- Xstate Resources Limited 10.00%
- Pancontinental Oil and Gas NL* 10.00%
Via 100% subsidiary Bombora Natural Gas LLC
The shallower Tertiary and Upper Cretaceous targets are generally identified by seismic amplitudes, and are produced extensively in the nearby region. These reservoirs were deposited in a fluvial-deltaic to shallow marine environment, and are generally of good quality. Individual wells produce 1-3 BCF from these shallow zones.
The deeper Cretaceous rocks are less explored, and hold significantly greater potential. Multiple sand intervals extend over the structure at depth with better reservoir quality interpreted off the flanks of the structure. Seismic interpretation shows clear sequence thickening and amplitude brightening on the flanks of the Dempsey structure. These rocks were deposited in a deepwater environment, with the reservoirs deposited in turbidite fans. The structural history of the Dempsey feature indicates these turbidites sandstones are focussed on the flanks of the structure rather than across the top.
The lower Cretaceous has not been extensively drilled in the Basin (just 16 partial well penetrations) and most of these were very old wells that were not drilled on structure.
There is strong evidence that the gas trapped in the shallow, traditional producing zones such as the Kione and Forbes Formations, has been generated by source rocks within the underlying Lower Cretaceous section. The intersection at Dempsey 1-15 was significantly overpressured throughout, and almost entirely gas saturated.
USA California Sacramento Gas Basin Tulainyo Gas Project
- California Resources Production Corporation (Operator) 41.67%
- Cirque Resources LP 25.00%
- Gas Fields LLC 33.33%
Equity interests are assumed post full earning via a staged farmin requiring funding of three wells. Gas Fields is managed by and owned 40% by Pancontinental.
The Tulainyo-1 drilling program in late 2014 to early 2015 encountered high pressure gas in a number of reservoirs but could not be tested due to mechanical difficulties. Good quality wireline log data was matched to extensive adjacent outcrop within the Coastal Ranges, indicating that the reservoir section thickens downdip and will continue at depth within the structure. The well data indicated potential for all the reservoirs within some 10,000` (+3,000 metres) of vertical mapped closure to be gas filled, creating a potentially giant-scale gas resource.
Over 11 TCF of dry gas has historically been produced from Late Cretaceous and younger sandstone reservoirs in the Sacramento Gas Basin. In the Northern part of the Basin, Pancontinental believes the gas is sourced from the older Cretaceous section like that beneath the Tulainyo structure. The region is characterised by extensive gas production infrastructure.
USA California Sacramento Gas Basin Alvares Gas Discovery
- Sacgasco Limited (Operator) 39.00%
- Empyrean Energy PLC 25.00%
- Xstate Resources Limited 21.00%
- Pancontinental Oil & Gas NL 15.00%
Via subsidiary Bombora Natural Gas LLC
The Alvares-1 drilled in 1982 had extensive high gas shows in the Early Cretaceous Stoney Creek Formation. A thick sequence of sandstones, silt and conglomerates were penetrated in the well below 8,300 feet (2,530 metres) with gas shows extending over some 1,500m that were either not tested or improperly tested in the original discovery well.
The gas reservoirs are interpreted from E-log, core, cuttings and test data to have fair to moderate reservoir quality and are older than the Early Cretaceous reservoirs encountered in the Tulainyo-1 well program. Despite at least 3 gas columns being present in the original well, mechanical conditions prevented valid flow testing although a partially successful test did flow good quality dry gas at 0.4 MMcfd to surface.
A more recent reservoir engineering review of the well results indicates that natural flow of between 4.0 and 10.0MMcfd could be achievable from these reservoirs if drilled and completed optimally, using modern technology.