Looks like there has been a new Permit issued for Crowell well SW of Glenmora.   Was SN# 251311 & now it is SN# 251809.

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Anything to make of this lateral being longer than other Louisiana Austin Chalk Wells? I know Eagles Ranch was 16,000' to 21,000' or 5'000 ft lateral. This looks closer to 8,000' lateral... 

Considering that 10,000'+ foot laterals are the norm in other horizontal play areas (with 12,500' to 15,000' becoming more common), I think that two issues are impacting shorter laterals in this area.

  • Rig capabilities
  • Acreage limitation (difficult to pull together units to support longer laterals)

I will add another "intangible reason" - operators looking to save some $$ by drilling shorter laterals while proving up the play / then go for longer laterals if early wells deems it is economic.

NEW UPDATE TODAY "REACHED TD OF 22,500' 10/1/2019, SET 5 1/2" LINER @ 22,490', POOH TO TEST BOP"

Looks like they got to the permitted / planned lateral TD (MD). Casing (liner is misnomer here) set - hoping they got good cement bond across lateral.

Now they should rig down the big unit and start prepping location to move in completion / frac equipment.

Good progress!   Hopefully we will know more in the next few weeks.  But they are not putting out much info.

I would change weeks to months. Don't expect to hear official post frac test results for some time / 3-4 months at a minimum.

But rumors based on observations and interpretations will be ramparnt!

Thanks Bob, just seen your post after my post.

FRACK WORK PERMIT Reference Number 19-142, Application Date 10/15/2019 with Expiration Date 10/14/20, Work Permit Status Date 10/16/2019, Total Depth 22397

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

Good looking plan assuming that they don't run into any problems.

Coiled tubing clean out will remove any cement and/ or drilling mud from cased hole prior to starting frac operations.

Perf and Plug frac is most aggressive approach to stimulation / 29 stages works out to around 210' per frac stage / good frac density.

DFIT test at toe is good first step to get an actual measurement of break down pressures and formation perm. This info will help is planning actual frac jobs. 

Looks like permit gives them up to a year to do this work before having to re-apply.

THX for response RM,, for educational purposes what is DFIT test at toe and why is that a good first step?

As I touched on in previous response, DFIT test is intended to obtain information about breakdown pressures for the formation in question and more importantly the permeability of the formation in question - with the assumption that the tested section at the toe of the lateral is representative of the overall formation covered by the lateral.

This is basically an "ultra mini frac" where a few perforations are shot and then subjected to a pump in of fluid. Then well is shut in and pressures are recorded to see how quickly the induced high pressure created by the mini frac bleeds off (or is absorbed into the formation).

I have attached a Halliburton PDF that explains this a lot better than I can.

Why is this done? Knowing perm of the reservoir interval is helpful in understanding formation response over time as well as how to more properly frac the well. This is an expensive process but worthwhile to do in early wells in any new play area.

Good move by the operator in my opinion.

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