Ya. Opinion needed, page-4

D,

For now GOR remains the 'missing' variable & wasn't reported for IW#1. It appears that they have everything else from the Core hole at IW#1, wireline logs, pressure profile, rock mechanics info etc.

There's 2 ways to get a GOR, denoted in bbls/mmcf & it varies depending on the complex depo-history of the rocks. Some early EF wells were ranging from 40-600.

Firstly thro' wireline logs, ie RFT or an MDT tool which is basically is pulled over at the relevant depths in a reservoir & takes a fluid (oil, gas, water, cond) sample into a sample chamber, records the Pressure reading (in PSI) & in essence the flowability of the payzone (in md/cp).

Once the tool is pulled back on Surface, the sample is retrieved from the sample chamber & analysed & one can infer the oil's specific gravity in API, viscosity, its color etc and same goes for Gas.

This HC sample is further analysed in the Lab via detailed chromatography for high C10-C20 etc. So they can tell for sure what exactly those lighter HC's are.

Second way to estimate a GOR more accurately is via a proper Flow test from an test interval.

Once u open the wellbore post-perf & cleanout, it starts unloading its content (or not, depending on the Pressure). An operator takes numerous fluid samples at this juncture & can say for sure whatever the fluid its recovered, the flowrates, surface Pressure readouts on variable choke settings & other properties.

At IceWine#2, u r looking at a Shale reservoir which is a tighter rock then a conventional Sandstone Reservoir, so that makes it challenging to collect a 'representative' fluid sample from any Zone from their Logging tool. That's what their update was alluding to this week.

However, last year at the cored hole at IW#1, they had recovered light oil from the cored section of the HRZ in the lab as was shown on a Photo with the depths etc marked up. So they need to do a proper DST & then report any GOR after that.

What matters more for now is the pressure gradient denoted as psi/ft.

For the E'Ford, Pressure gradient ranges between 0.4 to 0.8+ with 0.76 psi/ft being the magic number given its tectonic history, Burial depth & 'cooking' time for the organic matter in nature's kitchen (depths of 10000+ ft, temperature, pressure, maturity etc).

Given the reported depth of the HRZ at IW#1 & the Overpressure, their pressure gradient (in psi/ft) should give them reasonable amount of confidence in proceeding with the testing program, which in itself is a cumbersome process (pump the frac fluid at a set pressure & bbls/minute in the wellbore, shut the well, monitor the pressure drop on the EMR gauges over a wk or two, open the well bore, flow at a controlled rate thro' variable choke settings & Recover the frac fluid and any HC's).  

That's the long & short of it.

As for the DFIT not sure why they cancelled it. They should have the Imaging logs which shows the bedding pattern, dips, fractures, faults & borehole breakout.

This info along with data from the other Wireline logs, ie Sonic logs, density, Res, Gamma etc should give them the complete picture.

Sonic logs will tell them the Elastic properties of the rock, ie Young' Modulus & Poisson's Ratio or simply put zones that r more brittle as per the matrix. Data from the matrix analysis done from the cored intervals should tell them the most likely Brittle zones that can b fractured easily or already has natural fractures.

Caliper logs should measure the wellbore dia & any change in it from high stress patterns (from 6.125" in which they cemented the 4.5" liner).  

So essentially at the end of the logging run they should b able to put together the complete picture of the subsurface & plan the forward going Ops with regards to test interval.

They r at a interesting juncture, so hope all is revealed next month.

Hope this helps.