Replies to This Discussion

Permalink Reply by Diamond Jim on February 12, 2020 at 15:28

Marathon updated its presentation with the flow rate of the Crowell well page 20.

1,200 bbls of oil per day of oil and ~9 mmcf of gas on a restricted (code for the well could flow much higher) Pressure at the wellhead is a staggering 9,000 psi!

http://filecache.investorroom.com/mr5ir_marathonoil/218/download/4Q...

Permalink Reply by Lisa Melder-Johnson on February 10, 2020 at 14:40

Great news Jay!   Thanks so much for sharing with us.   We do appreciate your knowledge & expertise.

Permalink Reply by Mike Johnson on February 11, 2020 at 1:21

Based on the completion information filed with the D.O.C., I find it hard to believe that they are happy with that well. While it flowed back over 3500 barrels of fluid, it is basically a water well that produces a little gas and condensate, as also indicated by the relationship of FTP and SITP. 

I looked at some of the adjacent wells in that area and virtually all of them were pretty poor producers...lots of fluid but mostly water. Obviously good permeability...just mostly water. I'm sure Marathon has a lot of information that I do not have but this location just doesn't make any sense to me.

Permalink Reply by Diamond Jim on February 11, 2020 at 1:59

This well is different from all of the other historical wells in that this well was hydraulically frac’d. With this completion method millions of barrels are pumped down the well. A significant amount of this water is recovered during the flowback phase. The 3,500 bbls of water was a rate that was reported on 1/21 which was the first day a flowback. This is why the water rate was so high and the oil rate was minimal.

Permalink Reply by Lisa Melder-Johnson on February 11, 2020 at 4:55

and we are only seeing what they want us to see, when they want & they have to provide to DNR.   Below is the Completion Report dated 2/3/20.

Attachments:

• 251809 COMPLETION REPORT.pdf, 82 KB

Permalink Reply by Skip Peel - Mineral Consultant on February 11, 2020 at 5:17

The API gravity concerns me as does the well cost.  It will take a few months before we see the costs to drill and complete the well.  Early exploration wells are always more costly than later development wells.

Permalink Reply by Mike Johnson on February 11, 2020 at 5:40

I guess what is puzzling to me is that there is no information that indicates that this well was actually fracked. They filed a well history on 10/18/19 and the completion report in early February. 

Regardless, it makes no geologic sense to fracture a high water cut reservoir that obviously already has excellent permeability, as indicated by numerous adjacent wells with extremely high fluid flow rates with no stimulation. 

Permalink Reply by Lisa Melder-Johnson on February 11, 2020 at 7:14

Fracking Work Permit 19-142 10/15/19   COILED TBG CLEANOUT OF WELLBORE PRIOR TO FRAC OPERATIONS. TREAT LATERAL FROM 22,332' TO 16,143' IN 29 PLUG & PERF HYDRAULIC FRAC STAGES, DFIT TO BE DONE @ TOE OF WELL. COILED TBG MILLOUT OF FRAC PLUGS TO PREP FOR PRODUCTION. FLOW TEST WELL

Permalink Reply by Skip Peel - Mineral Consultant on February 11, 2020 at 7:17

To get the details on the frack design you must go to the Frac Focus website and input the API well number.  It also helps to know how to do the conversion math to come up with actual volumes.

https://fracfocus.org/

Permalink Reply by CenturyMan on February 11, 2020 at 14:14

Crowell 251809

Attachments:

• 91C70EEC-DC40-4F31-BF02-13397B248B50.jpeg, 368 KB

Permalink Reply by Skip Peel - Mineral Consultant on February 11, 2020 at 14:16

Thanks.  Nice flare.  It should grow some.

Permalink Reply by David Crockett on February 11, 2020 at 14:46

thanks for posting the picture

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