From the Sjeikh over on IVRe: "Drilling & Logging" suggest BHN-1 is a Winner; Ekofisk Chalk Group AND... cont'd. I say forget the chromatograph. We have the RST, which is a totally unmatched closed hole logging tool, with the largest C/O characterization as well as capture-sigma calibration data base of any nuclear tool in our industry. It continually locates bypassed h/c zones in old forgotten or "nearly depleted" (read; cased) wells. In gas and water bearing zones, the carbon content is low (i.e. the carbon/oxygen ratio is low). Hence, for Dualex to spesifically point out no water indication implies no gas indication. On Dualex's RST reading the C/O ratio is high and indicative of oil, not water, nor gas (or retrograde gas*/condensate), and it has this same reading throughout the Abiod. Any amount of carbon with significance to the RST tool is found in liquid h/c in the reservoir, it's that simple. *Sorry, I'm a nerd and prefer to use the term "retrograde". Besides, many an investor not experienced in the petroleum industry may not know that hydrocarbons labeled with the term "condensate" almost always is found in a gas or vapor state in the reservoir, which is condensed as pressure and temperature decreases towards surface (known as "retrograde" phase behaviour, hence the term.) This is important to know to understand how the RST is able to draw a line between "condensate" and oil. They would have used data from SLK to calibrate it correctly and account for matrix carbon. In addition, gas sigma (the rate at which thermal neutrons are captured by the formation) is much lower than oil sigma, i.e. quite easily distinguishable. I don't think Porter Bradley would have bought a million shares in the PP if the C/O ratio or capture sigma was low on the RST. The oil may be in the "volatile" category with an API between 40 or 45 degrees (as at for instance Sidi el Itayem, our other neighbour), i.e. high shrinkage, but even so, light oil is light oil. Our beloved Cooper/Jacka's total (prognosed) depth at Hammamet West-3 is 3840 meters. The top of the Abiod is at 3010 meters. The oil is around 30 degrees API. Eni's Maamoura produces 41 degrees API from the Abiod at around 3000 meters depth. Hydrocarbons encountered in and above the Upper Cretaceous (Maasrichtian) Abiod are more likely to be oil rather than gas. Gas and condensate may be found at shallower depths, but generally within the deeper Cretaceous petroleum system in Tunisia. A combination of access and migration from the different source rocks (i.e. Cretaceous and Tertiary) and their different maturation and "charge histories" is responsible for this differentiation. In actuality, Tunisia doesn't have many NG/condensate producing fields compared to oil fields. The only two significant ones are BG's Miskar field producing from the Campanian (lowest Maastrichtian) Abiod a 53 degrees API retrograde gas from 10 wells at a depth of 3400 meters (40% of Tunisia’s gas requirements), and the Hasdrubal field (also BG) set on production in 2009, producing gas, retrograde gas and oil from El Gueria at 2870 meters, having tested 21 MCF/d of gas, 1,988 b/d of retrograde gas, and 1,800 b/d of 37 degrees API crude. There are many more points that could be made, but there isn't much time left before our moment of truth, so I will now and henceforth let silence reign from the Norwegian camp. These are my thought patterns only, presented as best I can gather and lay them out. Draw your own conclusions, and don't take my word for anything. I could be wrong you know, in any and all aspects of my contemplation. Cheers, Morten