last drink call, page-37

Aspen,

There's no magic number as such in 2day's cut-throat gas mkt.

However, the beauty about this gig is the area covered by Artemis prospect as such. PBR-MEO can always recalibrate their seismic data, if A#1 comes up good post-drilling & then choose a location for future appraisal wells.

So to answer y'r question, a 20m+ net thk sand with 50% gas saturation & 17% porosity & high pressure should b good enough.

Note, Hess flogged its acreage to WPL after drilling most wells where they had 28-46m thk gas-bearing sands in 2008. Another example is Jansz, thin consistent sandy reservoir that lights up like a Xmas tree on the 3D-seis, coupled with a massive areal extent. No wonder Exxon have it as 18-20 TCF prospect.

Another example is WPL's Pluto-1, which had 111m net out of 225m gross thk sands & flowed 46 MMcfd frm a 10m section & 9.5 mmcfd frm a 28m tight sandy interval. Their next well, Pluto-2 had 63m gross sands. Doesn't mean the prospect is dud, it still ticks all boxes for an LNG project.

End of the day, all PBR wants is a decent clean sand which is pressurised, has HC's, has decent porosity/perm'b at A#1, then they should b on a winner (irrespective of any mechanical issues). That's why MDT (pressure) data is necessary amongst other key variables, of coure each well is different.