Replies to This Discussion

Permalink Reply by Rock Man on January 30, 2020 at 11:52

Just looked at SONRIS a mintue ago

More info added

Allowable now 2200

Estimated potential 210

Current Allowable Type 1

Question - what units are they talking about? BO? MCF? 

Permalink Reply by Rock Man on January 30, 2020 at 12:05

Jay

Thanks for posting / looks like this was a dynamic situation today as to new info being up loaded.

• Now the question is how soon after flowback started was this test measured?
• 24 hours as Skip has indicated?
• And how will these rates change over time - especially with respect to increased O&G volumes and reduced water volumes.

If this is the stabilized rate that doesn't get any better  - Rut Row is good comment!

I see that this rate was on 18/64" choke with high flowing pressure (8200#) and SITP of 6063#. Casing Pressure 1300#. Oil gravity 52 API (condensate?) 

Thanks again

Permalink Reply by Skip Peel - Mineral Consultant on January 30, 2020 at 12:11

It will take months for monthly production volumes to appear on SONRIS.  I think we may see something from Marathon before then.  It is possible but somewhat unlikely that Marathon's end of year report, usually out in February or March, will mention the well.  Better odds for first quarter 2020 report/presentation maybe in late April or May.

Permalink Reply by Hydrocarbonite on January 30, 2020 at 12:38

Thx for posting everyone, not numbers we were hoping for.  Maybe things will improve as flowback is completed.  HC

Permalink Reply by Lisa Melder-Johnson on January 31, 2020 at 7:37

Jay, how does the 18/64" choke affect the flow?

Permalink Reply by Skip Peel - Mineral Consultant on January 31, 2020 at 11:05

The SDM2G test is flow over 24 hours.  Not nearly long enough for clean up.  So expect something better as to max flow.  A 18/64" choke seems pretty tight to me especially considering the flowing pressure.  Yes condensate, so not the price per barrel of oil.  On 1/30 WTI was $52.14/barrel.  Condensate was $44.49/barrel.

Permalink Reply by Lisa Melder-Johnson on January 31, 2020 at 11:43

Thanks Jay & Skip for your great insight & helping us understand.

Permalink Reply by David Crockett on January 30, 2020 at 12:46

Thanks Jay. Lots of frac water. Hopefully the oil percentage will increase over the next few days. 

Permalink Reply by Rock Man on January 30, 2020 at 13:55

Echoing some earlier comments by others, all the water produced may not just be frac water but instead may be coming from the AC (formation water).

Time will tell - and we are talking months to get an idea as to how good this well may be and what sort of O&G reserves and economics we are looking at.

Permalink Reply by Lisa Melder-Johnson on January 31, 2020 at 7:39

I notice this morning that I did see several truck with those drop down trailers behind them on I-49 traveling south & I haven't seen them in a while now.

Permalink Reply by Rock Man on February 3, 2020 at 3:30

Jay, good post. I figure that this well was an "traditional" natural fracture AC reservoir / lots of examples of this type of rapid decline along the entire AC trend.

Preaching to the choir but your comment on production decline importance is dead on.

Everyone should keep in mind the steep production decline profile that has taken place on the initial AC Hz Frac wells in this area (EOG well in Avoyelles Parish).

Permalink Reply by Rock Man on February 3, 2020 at 3:23

That would be pretty cool if that was the case. As always, time will tell - and the oilfield is one of the biggest rumor mills in the world!

LOL

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