Thursday, January 9, 2020

Kraken Bigfoot Wells: Three-Section, Extended Long Laterals, 90 - 105 Stages; 15 - 23 Million Lbs Proppant

The original note regarding the Kraken Bigfoot wells is here, but that page will no longer be updated. The Kraken Bigfoot wells will now be tracked here.

Halo effect: see this post for wells positively impacted by the Bigfoot wells

The Kraken Bigfoot wells came off confidential list, January 9, 2020.

The wells, triple-section; extended long laterals; 1920-acre spacing except for the section line well (3,840-acre spacing / 6 sections):
  • 36013, 1,564, Kraken, Bigfoot 23-11 4TFH, 90 stages; 23.07 million lbs; Sanish, t7/19; cum 265K 3/20; a 41K month;
  • 36012, 1,748, Kraken, Bigfoot 23-11 3H, 105 stages; 15.44 million lbs; Sanish, t7/19; cum 282K 3/20; a 53K month;
  • 36011, 902, Kraken Bigfoot23-11 2TFH, 90 stages; 23.07 million lbs;Sanish, t7/19; cum 206K 3/20; a 31K month;
  • 36010, 860, Kraken, Bigfoot 23-11 LW 1H, 105 stages, 15.44 million lbs, Sanish, t7/19; cum 252K 3/20; a 46K month; spacing: 3840-acre; 
The four wells above run from the south to the north, through three sections. The nine wells are producing wells and are in close proximity to the Bigfoot wells. In seven cases, the laterals parallel the Bigfoot wells for at least one section, generally two sections.
  • 17812, 660, Kraken, Anderson 11-14H, Sanish, t6/09; cum 353K 3/20; huge jump in production;
  • 21381, 1,150, Kraken, Dinwoodie 11-14H, Sanish, t1/12; cum 277K 3/20; huge jump in production;
  • 28025, 442, Kraken, Donnie 11-14H, Sanish, t9/14; cum 277K 3/20; no demonstrable change after Bigfoot wells fracked;
  • 22429, 743, Kraken, Reynold 11-14H, Sanish, t6/12; cum 270K 3/20; nice jump in production;
  • 30612, IA/461, Sinclair, Uran 5-15H, Sanish, t5/17; cum 270K 3/20;
  • 31470, 602, Sinclair, Uran 6-15TFH, Sanish, t8/19; cum 44K 3/20;
  • 22853, 687, Kraken, Isaac 11-23, Sanish, t7/12; cum 150K 3/20; small but definite jump in production.
These two wells are not parallel to the new Bigfoot wells:
  • 22563, the lateral is 90-degrees to the new Bigfoot wells, 704, Kraken, Hukkanen 11-23, Sanish, t6/12; cum 171K 3/20;
  • 16953, the lateral is 45-degreess to the new Bigfoot wells, IA/440, Kraken, Fladeland 11-15, Sanish, t4/09; cum 259K 9/19; off line 10/19; remains off line3/20;
The graphics:




Production data and further information for these wells posted here.

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Production
  • 36013, Three Forks:
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN11-201929376233777740207596241574740162
BAKKEN10-201930409024117354144625751507545636
BAKKEN9-201929403514046062644604051359646594
BAKKEN8-201928372173675059065369942147815320
BAKKEN7-201917150521478424198149613014750
  • 36012, middle Bakken:
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN11-201930379813820027619553261948931498
BAKKEN10-201930484444885336045598501775339977
BAKKEN9-201930535715370252246576431834539075
BAKKEN8-201929486754809955506488692759121078
BAKKEN7-201917216252123926285217114321483
  • 36011, Three Forks:
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN11-201929304413054566720323541086818779
BAKKEN10-201929305913075976275313981028619710
BAKKEN9-20192628330280457599523400823514967
BAKKEN8-2019277456743259580749440053297
BAKKEN7-20191469866861225197021146839
  • 36011, middle Bakken:
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN11-201930459144605048415631091753541626
BAKKEN10-201929439344410052577581421529040948
BAKKEN9-201929358563534174013472221100136006
BAKKEN8-2019315361619433715223101193
BAKKEN7-20191464506335193806392136218

4 comments:

  1. I'm in some Whiting wells the next section over that haven't produced these many barrels seven years. Looks like there is some knowledge to be gained from Kraken here. Pretty nuts.

    ReplyDelete
    Replies
    1. The Kraken Bigfoot wells were three sections long (three miles long) vs the standard two-section (two-mile) long horizontals. In addition, Kraken used a huge amount of proppant. But having said that, operators are getting better and better at completions. As I've said many, many times, all those wells drilled before 2014 need to be re-fracked. EOG, under Mark Papa, said it would simply be easier and less expensive to simply re-drill brand new wells next to all those old wells.

      There is so much work left to be done in the Bakken.

      Delete
  2. It appears as if the formula is beginning to be learned by more and more of the operators.

    Let the good times roll.

    ReplyDelete
    Replies
    1. It's still location, location, location. But completion strategies make a huge difference, it appears. And all those old wells need to be re-fracked. Lots of work left to be done in the Bakken.

      Delete

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