Replies to This Discussion

Permalink Reply by Rock Man on May 16, 2018 at 9:22

Interesting.

I am a SONRIS / La semi novice - in a situation like this, does the state have different API / serial numbers for the original vertical wellbore and then another for the newly drilled (re-entry) lateral?

Switching gears - in Texas, one can pretty easily differentiate water from oil tankers (mostly in panel codes and colors as well as tanker shape / type). Getting an idea of numbers of each running in and out of location would be interesting.

There can only be a finite amount of storage capacity on location.

Last point (finally) - this Blackbrush well is basically a "play concept test well" - BB is looking to see if they can get some decent O&G volumes from a small short lateral before drilling new 5000'+ laterals from scratch.

OK - now the last point: Is there a flare stack on location" Best to look at night to see flare height and color.

Permalink Reply by Skip Peel - Mineral Consultant on May 16, 2018 at 9:33

This well, S/N 250723, is a re-drill of S/N 220356.  Both wells have the same API number: 17079204600000.

Permalink Reply by Rock Man on May 16, 2018 at 9:39

OK - killed that possibility / thanks for explaining this 

Permalink Reply by Bob Zimmerman on May 16, 2018 at 10:02

Well, the first effort resulted in a dry hole (or so they said)at or near the same TD (14182)with laterals and the permit was for the AC also. About all I can conclude is there was something in the matrix, and the fracking released it. I'll wager that's exactly what they have concluded, and they don't want anybody but corporate and the rig hands to know anything about their new hot potato.

There's a caveat to the trucking. Frequently in the AC here there is enough capacity onsite for oil storage, but not enough for a lot of produced water so it has to be hauled. However, the more water hauled off, the more oil is being accumulated onsite. Eighty percent water cuts are not unusual, but do require some extra expense.

You know if they come back and drill in injection well on the pad they,in the words of Pres. Trump, have a "winner" on their hands.

Permalink Reply by Bob Zimmerman on May 17, 2018 at 2:51

<3/29/18, SET 4 1/2" CSG @16,026' W/510 SKS, TD 16,435".(FINAL REPORT ON THIS WELL) STATUS DATE: 3/29/18 REACHED SIDE TRACK TD OF 16,435' MD 3/27/18, PRESENT OPERATIONS, RUNNING 4 1/2" PRODUCTION CASING>>>

Why would anybody run casing down a dry hole, then commence to hauling off liquids of some type?

Likewise, why would anyone not case a good well and leave those liquids down hole?

Permalink Reply by Skip Peel - Mineral Consultant on May 17, 2018 at 2:53

Because it's not a dry hole.  See my previous reply.

Permalink Reply by Skip Peel - Mineral Consultant on May 17, 2018 at 3:37

A little color on the subject of Shut In wells regardless of the specific code number.  Several years back the industry started reporting wells that were drilled but not completed as Code 31.  These wells were what we once designated as WOC (Waiting On Completion)  which would fall under Status Code 01.  There is some advantage for the industry related to this status and I think it is negating the need for regular reporting of well status.  It appears that once placed in Status 31 or 33 for that matter, the well is in a suspended reporting status.  This is one of many examples of the industry gaming the system and the fact that DNR/OOC largely allows for such fudging until called to account.  Below are some CHK HA wells that are Status 31.  They are all infill Haynesville Shale wells which are definitely not dry holes, they just haven't been completed or reported as such.  Below that list is a link to a recent discussion posted by Dion that goes into greater detail regarding the industry's misuse of shut in status.

	250290	HA RA SUW;GEPH30&19&18-16-15HC	001-ALT	31			17017360820000	C441	4780	06-JUN-17	031-16N-15W
	250458	HA RA SU82;CADPAR19&18-15-15HC	001-ALT	31			17017361190000	C441	1464	28-AUG-17	019-15N-15W
	250459	HA RA SU82;CADPAR19&18-15-15HC	002-ALT	31			17017361200000	C441	1464	28-AUG-17	019-15N-15W
	250471	HA RA SUAA;WOOL 4&9-15-14 HC	001-ALT	31			17017361220000	C441	2360	05-SEP-17	004-15N-14W
	250472	HA RA SUAA;WOOL 4&9-15-14 HC	002-ALT	31			17017361230000	C441	2360	05-SEP-17	004-15N-14W
	250473	HA RA SUAA;WOOL 4&9-15-14 HC	003-ALT	31			17017361240000	C441	2360	05-SEP-17	004-15N-14W
	250474	HA RA SUAA;SIBLEY 4&9-15-14 HC	001-ALT	31			17031265350000	C441	2360	05-SEP-17	004-15N-14W
	250595	HA RA SUPP;NGLSH 12&13-12-13HC	001-ALT	31			17031265670000	C441	7651	02-NOV-17	001-12N-13W
	250596	HA RA SUPP;NGLSH 12&13-12-13HC	002-ALT	31			17031265680000	C441	7651	02-NOV-17	001-12N-13W

 

Push to Clear the Books of Chronic Shut-in Wells

http://gohaynesvilleshale.com/forum/topics/push-to-clear-the-books-...

Permalink Reply by Rock Man on May 17, 2018 at 3:54

Side comment on casing and "liquids down hole"

At this point in the play in La, operators have no way of knowing just how much oil is trapped in the AC section. Only running casing and frac'ing and testing will answer that question

Part of risk issues on chasing unconventional plays. 

Permalink Reply by Skip Peel - Mineral Consultant on May 17, 2018 at 3:59

IMO, It has turned into a test well.  Blackbrush will wring as much science as they can out of it and then P&A.

Permalink Reply by Rock Man on May 17, 2018 at 4:01

100% in agreement on that concept. Despite lack of financial "payout", technical info and science and test results is "priceless"

Operators (including myself) do that all the time

Permalink Reply by Skip Peel - Mineral Consultant on May 17, 2018 at 4:08

My knowledge of completion designs is limited but all of us in the Brown Dense group got a lesson from Southwestern regarding completion ops on their horizontal wells in Union Parish.  SWN would use a different frac formula on individual stages in the same well starting at the toe and working back to the heel allowing significant flow back time for each.  That approach took a lot of time and made for a lot of impatient spectators, not to mention expensive wells.  Unfortunately the results never found the key to an economic well design.

Permalink Reply by Craig Wascom on May 17, 2018 at 4:08

That’s why I keep saying you don’t want to be first. I would be happy for them to get to me in about 18 months.

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