I would caution to not get too excited about early post frac flow back results. There will be naturally a lot of high pressure due to the fluid volumes pumped with the frac. The early oil cut report is a positive but the key is what happens after post frac flowback rates stabilize and settle.
My biggest concern would be water influx with any O&G. As well as O&G volumes and decline over time.
The waiting game is tough since it takes so long for info to become official and posted
My cut-and-paste is the latest completion data for the subject well. The only entry that is recent is this well test.
|RPT TYP||TEST DATE||RPT DATE||OIL POT||COND||GAS DEL||WATER||BSW%||FLOW PRES||SHUTIN PRES||CHOKE||UPPER PERF||LOWER PERF||BOT HOLE PRES|
This is the deeper Tuscaloosa Sand completion below the Austin Chalk / figure this zone must have died out or watered out to merit uphole move to the AC
It is the same well by SN. Am I missing something?
This is the info that post dates the deeper Tuscaloosa SS work / completions. DJ had this in posting earlier tonight.
This shows the plug back from deeper Tuscaloosa SS perfs and setting bridge plug to allow for AC testing
L # 0128-20
AUSTIN CHALK INV # 1209732
SET CIBP IN 3-1/2" TBG @ 18760' & DB 15' CMT ON TOP; PUNCH TBG HOLES @ 18598'-600'; PUMP/SPOT 300' CMT PLUG INSIDE ANNULUS & TBG F/18300'-18600'; CUT&PULL TBG F/18100'; INSTALL TWO 7-1/16" 15M FRAC VALVES; SET CIBP IN 7" CSG @ 18080' & DB 10' CMT ON
So, number nine? Thanks.