David, You see that 5 and 32/29 are both permitted and Brigham now wants a 1280 adding 32 to 5, that means 2 1280's with both/different companies involved in Section 32. Is this going on anywhere else in Mountrail?
On Sep 30, 8:25 am, David <[EMAIL PROTECTED]> wrote: > I honestly don't see any issue with this. If companies want to do two > mile laterals and believe that such an approach is working, which this > spacing permits, so be it. It looks to me like the plan is to > ultimately drill at least two wells per 1280 acre spacing, so in the > end they have well counts similar to one well per section spacings, > but with the longer laterals. Granted that the royalty payments get > divided up among mineral owners on both sections, and there may be > year long time lag before the second well is drilled, but this should > tend to smooth out royalties over time for every mineral owner. > > On Sep 30, 10:51 am, go-devil <[EMAIL PROTECTED]> wrote: > > > > > David, Larry, Teegue, > > I see in a Hearing reports for Oct. 08 that Brigham is pushing for 22 > > various 1280 Spacings, > > I know Hess permitted a 1280 combining Section 32 and 29 of 156/92. > > In Brighams request it asks for 1280 spacing on Section 32 of 156/92 > > with Section 5 of 155/92. > > Any ideas as to the outcome here? > > > On Sep 30, 4:47 am, David <[EMAIL PROTECTED]> wrote: > > > > Yesterday's 9/28/08 daily activity report was especially interesting > > > because it includes initial production information (ip) for a large > > > number of wells by many different drillers in the state including > > > several EOG wells just off confidential. > > > Linkhttps://www.dmr.nd.gov/oilgas/dailyindex.asp > > > > Of the wells listed the first place goes to EOG drilled Austin 26 in > > > SE Austin with an official ip of 3070 bopd. > > > > The silver medallian goes to EOG's School 16 on the south side of > > > Parshall TWP bringing in an official ip of 1721 bopd. > > > > On the other end we now know for sure that, sadly, Behm's Edwards 1 > > > was not a producer. > > > > We have producing wells coming in as low as 17 and 30 bopd. I wonder > > > how many of the wells coming in at 100 bopd or less will still be in > > > production a year from now..It takes 3-4 bopd I think just to cover > > > the costs of pump operation already in place. > > > > Can anyone tell me exactly what is going on with 17058 Shell Creek > > > State 1 01 drlled as a second well in 1 152 90 (Parshall TWP up by the > > > primary already producing "Long" well in that section). I know it was > > > scheduled to be a test well of some sort.The report says they drilled > > > to 13,459 ft into the Winnepeg formation, but apparently has not been > > > put into production. > > > > For those of you with EOG holes drilled awaiting the pooling hearing > > > for your section, a bunch of these are scheduled to take place on > > > October 23rd in Bismarck. Check the Oct 23rd hearing dockets page on > > > the dmr site, as this was just posted yesterday > > > . > > > Figure a minimum of 2-3 months from the hearing date to when a royalty > > > check shows up in your mailbox. :-) > > > > Those of you with a pooling hearing scheduled October 23rd should > > > receive legal papers within a few days I would think telling you the > > > official hearing has been scheduled and you can show up if in Bismarck > > > you are unhappy with the pooling scheme (not that it would do any > > > good, LOL).You can also listen in on the hearing live via the Web > > > starting at 9 AM on the scheduled hearing day. Most of this is routine > > > and if no owners are present to complain about something, the hearing > > > goes smoothly and very quickly. But occasionally someone wanders in to > > > raise an interesting issue. > > > After the hearing, the last step is for the title owners to do one > > > final check on who owns the mineral interest in each section, to make > > > absolutely certain there are no errors when the checks are cut. The > > > companies take extraordinary steps to assure the accuracy when they > > > get nearly to the check cutting stage, and that is why this seems to > > > take a little longer than it otherwise might. By the time you get your > > > first check,your well will likely have been producing for sale for > > > nearly 6 months. > > > The first check usually includes royalty payments for the first 2-3 > > > months of production combined.- Hide quoted text - > > > - Show quoted text -- Hide quoted text - > > - Show quoted text - --~--~---------~--~----~------------~-------~--~----~ You received this message because you are subscribed to the Google Groups "Bakken Shale Discussion" group. To post to this group, send email to [email protected] To unsubscribe from this group, send email to [EMAIL PROTECTED] For more options, visit this group at http://groups.google.com/group/bakken-shale-discussion?hl=en -~----------~----~----~----~------~----~------~--~---
