Replies to This Discussion

Permalink Reply by tc on May 6, 2013 at 16:39

I think the operators are having drilling issues, but that is to be expected with a new unconventional formation.  Mark P over on the Eagle Ford forum says a common mistake is that people think that all shales are the same, when the truth is that there are variability even within the same "name" shale.  If the TMS formation won't support long laterals then the operators will rethink the lateral length, but I think we need 50-100 wells before that is determined.

Permalink Reply by Bernell McGehee on May 6, 2013 at 17:10

Makes sense to me.

I'm also wondering if EnCana may wish to adopt the approach that Goodrich did in drilling through the rubble zone and then putting in casing through the zone.

Based strictly on the Crosby well, you have to wonder if being under the rubble zone isn't more productive.

Permalink Reply by Andrew on May 8, 2013 at 2:01

I got the sense that the hybrid frac design used on the Crosby had a lot to do with the well's success. I haven't heard much about the lateral placement, on this well since the results came out. Although, the extra steps Goodrich is taking to ensure wellbore stability in that rubble zone may be so expensive that management doesn't want to draw too much attention to it.

Permalink Reply by tc on May 8, 2013 at 2:28

On the CC Goodrich talked about drilling in the TMS and if they land above the rubble zone and not drill at the bottom of the formation they can "bore" drill instead if "slide" drill and complete the lateral much faster.  In the Eagle Ford they can drill up to 4,000 feet of lateral a day, while in the TMS they are currently much, much slower.  GDP's management chuckled at an analyst complaining that all the wells are trying new methods and he can't compare apples to apples.

Permalink Reply by Andrew on May 7, 2013 at 2:00

Bernell,

The vast majority of the "laterals" drilled in Louisiana have been in the Haynesville Shale. Skip may know better than me, but my experience with wells there is that the wellbore will both land and end extremely close to the minimum setback distance from the neighboring unit (330'). I don't think the mineral owner would have much of a leg to stand on if the laterals come up short to due to mechanical problems.

Permalink Reply by Two Dogs, Pirate on May 7, 2013 at 3:24

At least they drilled a horizontal instead of a vertical to HBP the unit.

Permalink Reply by Andrew on May 17, 2013 at 4:09

Bernell,

I agree with your logic re: spacing. I just posted the email from MS OGB to give the current state of affairs (which, I believe, is that the state is waiting to see how things develop before making any field or reservoir-wide spacing rules).

Permalink Reply by Steve on May 17, 2013 at 5:56

With 29,000 barrels of fluid per stage this means there is over 500,000 barrels of primarily water to regurgitate. Even if they only get 50% of it back, this could take a while if they have only recovered 4% in a month plus. Looks like they may have used too much water. I am guessing we may have seen the max rate at 730 BOE - IMO. Rumor is that the Ash 1 still has a fish in the line and is producing at a trickle (mostly water), at least so far. Hope we have better luck on the 2 new Anderson wells.

Permalink Reply by Judy Floyd Brown on June 11, 2013 at 2:40

I haven't been out to the well lately but my son-in-law went Sunday. He said there is a "rig" back out there that looks like the "fishing rig" they were using a while back. There was about 3 weeks where there was no "rig" on site. What could they be using that for now?

Permalink Reply by Skip Peel - Mineral Consultant on June 11, 2013 at 2:47

The sequence for completion operations is normally the drilling rig reaches Total Depth and sets the final casing string then leaves.  Some time later the frac crew arrives and takes one to two weeks to stimulate all the stages in the lateral.  They then leave and the well pad sits empty until the operator is ready to flow the well.  Then a small work over rig, usually a coil tubing rig, comes in to drill out the plugs between the perforated intervals in the lateral and hook the well to the pipeline.

Permalink Reply by Judy Floyd Brown on June 11, 2013 at 3:07

All of those steps have been completed. Except for drilling all of the plugs. They couldn't finish cause the drill blade ( or whatever you call it) broke off in the well. They " fished" for it for weeks and couldn't get it out. They then decided to flow the well. They removed the completion rigs etc. the flow wasn't so good. After a few weeks they now have a "rig" back on site. Just wondering what is up.

Permalink Reply by Rock Man on June 11, 2013 at 3:10

May be resuming operations to get fish out of hole so that they can drill out rest of plugs and get the entire hole open and flowing.

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