'oliver.gump' pid='78325' datel Wrote:Thanks for refreshing on this. That motivated me to look back. I pasted below old info but did not succeed in finding anything defining the reservoir base depth in A5 expected vs. actual from drilling. This is different from the OWC. But assuming that your info above is correct and the total gross reservoir thickness in A5 is 755 feet greater than expected, then indeed Well A7 could be very impressive if this expansion continues in the westerly direction. OSH says A7 has an upside of 1-2 TCF.
'Kaliboo' pid='78274' datel Wrote:
'bdahl385' pid='78266' dateline='<a href="tel:1481516 Wrote:. Correct. Recall is poor but I think I recall that we hit top of pay ~50-100 feet higher than expected in a well in the last 2 years. I don't recall whether the base also was shifted up by a similar amount, but if so, then you can imply that the reservoir is maintaining constant thickness and sloping and infer that dip angle in the direction of the slope. Erosion, scouring and other depositional processes can change the thickness. That's how they project the top and bottom depths in the next wells. The further away from existing well control, the less certain. Presence of faults changes the whole picture and can dramatically change the pore pressure gradient.
'Kaliboo' pid='78241' dateline='<a href="tel:1481386 Wrote:
'ArtM72' pid='78240' dateline='<a href="tel:1481382 Wrote:casing shoe depths are determined by pore pressure and frac pressure gradients in the earth. They tend to increase as you drill deeper so that requires an increase in mud weight. A wide variation from well to well is an indication of very different geology or encountering steeply dipping beds of the same stuff at different depths.
Is there anything we can glean from the 13-3/8" casing size down to 1,300 meters? This pic from Wike show a 13-3/8" casing to 4,000 feet leading to a 14,000+ foot TD hole. https://upload.wikimedia.org/wikipedia/commons/d/d8/Casing-Diagram.jpg
In laymen's terms, I believe Kaliboo has stated that we cannot infer planned TD of this well based on what size casing has been set at the stated depth.
Kaliboo, you are correct, at Ant 5, the top of the reservior was found to be 230m higher than expected [1] however the base of the reservoir was not shifted up higher. This means that the reservoir is significantly bigger than first estimated, yet the numbers went down when it got to a "deal".
My sentiments looking back on this stuff reminds me how badly shareholders are getting ripped off by these guys. This is so wrong. There is no freaking way anyone should be willing to sell this company until after A7 is drilled and fully evaluated and the recertification is done. Additionally, I wouldn't sell until I drilled some of the other periphery wells to the near field objectives around Antelope. These will have a high Ps of hitting gas. I would keep drilling objectives around Antelope until I don't find anything, i.e., probably lots of TCF later.
Got this from a Q4 2015 M, D & A presentation:
On December 23, 2014, we spudded the Antelope-5 appraisal well. On February 16, 2015, we announced the Antelope-5 appraisal well had intersected the top reservoir at 1,534 meters. The well reached a total depth of 2,307 meters on February 24, 2015. - On April 27, 2015, the well was open to clean up. On June 2, 2015, after downhole gauges
were run on Antelope-5 the flow testing commenced. The purpose of the test was to flow sufficient volumes of gas from the Kapau Limestone to create measurable depletion in order to
allow volume estimates of gas in place and improve the understanding of productivity and connectivity. The well was produced via two parallel choke manifolds at four different chokes
sizes, 32/64”, 40/64”, 44/64” and 48/64” per manifold over a 72 hour period. Corresponding rates were approximately 30, 40, 50 and 60 mmcfpd. The flow test was completed mid June
2015. A total of 152.9 mmcf gas, 2008.4 bbls of condensate and 46.2 bbls of water were produced. - During the test, gauges were also installed at the base of the reservoir in the Antelope-1 well to observe reservoir pressure response from the Antelope 5 flowing. Pressure response showed no significant pressure depletion and excellent reservoir connectivity.
Got this from a March 20, 2016 IOC press release:
Antelope-5 appraised the western flank of Elk-Antelope about 1.8km south-south-west of Antelope-3. The top of the carbonate reservoir was intersected at 1,534 meters (5,033 feet)
TVDSS, about 230 meters (755 feet) higher than InterOil’s reference case. The result provides evidence that the good quality, reefal reservoir extends further west than originally thought.
During June 2015, a well test at Antelope-5 flowed a total volume of 152.9 million standard cubic feet gas (mmscf) of gas over a 72 hour period with listening gauges in Antelope-1. An extended well test of Antelope-5 in early 2016 flowed a total volume of 760 mmscf over 14 days and then was shut-in for 16 days to record the subsequent pressure build-up.
Also this from the MIC in August on Antelope 7:
The well, scheduled to commence drilling early in the fourth quarter of 2016, is to be located approximately 1.3 kilometres west-south-west of the Antelope 5 well, targeting a potential extension of the Late Oligocene to Miocene age carbonate reservoir rocks comprising the Antelope Field as defined and set-out in Annex 2 of the Total Sale Agreement.
