Replies to This Discussion

Permalink Reply by Rock Man on May 2, 2018 at 5:14

Let's stay cautiously optimistic on future drilling. There are no result yet on the frac job - way too early for them to have any solid data.
Getting new units prepared for possible drilling in a good parallel effort to their flow back and testing program.

Permalink Reply by Rock Man on May 5, 2018 at 11:34

Any observations as to what is happening on this location????????????

Permalink Reply by John Matherne on May 8, 2018 at 6:15

The E&P company is leasing aggressively in the area. The well has its issues.

Permalink Reply by Joe Aldridge on May 8, 2018 at 7:46

John, how much are they paying? And what kind of issues?

Permalink Reply by John Matherne on May 8, 2018 at 8:01

Don't know what they are offering but got the info from a good source. Lateral length and frac was very short (1200'). May try and refract with a different rig later.

Permalink Reply by Skip Peel - Mineral Consultant on May 8, 2018 at 9:07

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	APPLICATION DATE	EXPIRATION DATE	WORK PERMIT TYPE	WORK PERMIT STATUS	WORK PERMIT STATUS_DATE	TOTAL DEPTH			TEST SAND	WORK DESCRIPTION
	04/12/2018	04/13/2019	PERFORATE	APPROVED	04/13/2018	16026			AUSTIN CHALK	FRAC WELL BOTTOM PERF: 15930', TOP PERF 14720' 9 STAGES 427,500 LBS/STAGE FRAC DATE: 4/16/2018

Permalink Reply by Skip Peel - Mineral Consultant on May 8, 2018 at 9:18

The proppant load is ~3180# per linear foot of perforated lateral.  Nine stages each ~134.4 feet in length.  The problem here is the short lateral.  A re-frac won't change that.

Permalink Reply by Rock Man on May 8, 2018 at 9:44

Agree that re-frac won't help - plus frac'ing down 4.5" casing had a negative impact on pumping pressure. Actually surprised that put away this much proppant without sanding out.

But this should give some scalable information as to test results - suggest that everyone look at this as O&G volumes per 1000' of lateral (or 1.2 factor) - multiple by 4 to 5 to get an idea of longer lateral potential test volumes.

The short (134') frac stages was a good move - better focus for stimulation.

Now the waiting game for test results!

Permalink Reply by John Matherne on May 8, 2018 at 10:11

With another lateral could be what was indicated.

Permalink Reply by Joe Aldridge on May 8, 2018 at 12:49

Hey Guys, I said this earlier this is NOT a frack. This is a sand pack. It looks to me like they have good natural fractures and they took advantage of that. Why would you drill on and mud up the formation if you find what you are looking for. 

As for as another lateral is concerned. I don't think that is a good idea. They have 9 additional units to drill. There is no reason to do another lateral in this well. At least at this time..Let's see what the production of this well looks like.

I'm still projecting 2,000+ bbls

Permalink Reply by Rock Man on May 8, 2018 at 12:57

Joe - this is a fracture stimulation / not a frac pack / sand pack as you indicate.

Every bit of terminology used for this completion points to "fracture stimulation". And probably a perf and plug approach.

Where do you see info that points to this being a "frac pack or sand pack"?

Odds are they increased MW to control mud gas while drilling. Probable lack of rotating head on drilling rig precluded drilling with high gas content and diverting mud gas to flare stack.

The play here is to fracture stimulate the matrix reservoir - not to suck the reservoir fluids from any natural fractures. Odds are they used diverters to shut off natural fractures if present in each stage and force the stimulation into non naturally fractured matrix reservoir.

Permalink Reply by Rock Man on May 8, 2018 at 13:00

Operator may opt to drill a new lateral (from a brand new surface location) in the opposing direction, but as Joe has indicated, operator would be better suited to spread their drilling dollars around to other areas / units.

With the re-entry of this old wellbore and then drilling a small diameter, short lateral, the results of this well can probably be termed "a good show" if they get some decent O&G volumes during post frac flow back period.

Operator would basically be hoping to prove that frac'ing the AC in this area (with these reservoir characteristics) is a viable approach.

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