Updates
August 7, 2019: production data update; otherwise no changes; there appears to be no change in the map at the NDIC.
July 25, 2016: these wells were updated this date; note that SI/NC wells have now become TATD. Screenshot as of this date:
November 26, 2015: in addition to the four wells (two 2-well pads) noted in the original post, there are now eight more wells, all short laterals in this section:
- 25319, 1,969, Oasis, Christa 5393 12-9B, ICO, t7/13; cum 138K 6/19; down to 800 bopm;
- 25320, 2,009, Oasis, Kray 5393 12-9T, ICO, t7/13; cum 231K 6/19; nice well; 2,000 bopm;
- 29342, SI/NC-->TATD, Oasis, Helix 5393 41-4 3B, 2/15; 12/16;
- 29343, SI/NC, Oasis, Helix 5393 41-4 4T2, 2/15; 12/16;
- 29344, TATD, Oasis, Helix 5393 41-4 5T, 7/16; 12/16;
- 29345, SI/NC-->TATD, Oasis, Helix 5393 41-4 6T3, 1/15; 12/16;
- 29346, SI/NC-->TATD, Oasis, Helix 5393 41-4 7B, 1/15; 12/16;
- 29347, SI/NC-->TATD, Oasis, Helix 5393 41-4 8T2, 1/15; 12/16;
Original Post
Disclaimer: this post has not been edited or thought about much. It is not ready for "prime time" but regular readers know the routine. I assume there are errors that will need corrections, and, of course, most of it is opinion.
This should get some folks talking, from the February NDIC hearing docket:
- 21849, Oasis, Sanish-Bakken, 21 horizontal wells on a 640-acre unit, 4-153-93, Mountrail,
This section (4-153-93) and the section directly south (9-153-93) are the only two sections still spaced as 640-acre drilling units in this immediate area: "everything else" in the immediate area is 1280-acre unit spacing.
Currently in section 4-153-93 (two two-well pads)
- 24760, 1,654, Oasis, Knox 5393 44-4T, t7/13; cum 141K 6/19; down to 600 bopm;
- 24761, 1,957, Oasis, Gloria 5393 44-4B, t7/13; cum 163K 6/19; down to 800 bopm;
- 21767, 1,246, Oasis, Helix 5393 43-4H, t2/12; cum 200K 6/19; down to around 500 bopm;
- 25025, 1,164, Oasis, Folda 5393 43-4T, t7/13; cum 153K 6/19; down to less than 1,000 bopm;
Some random comments follow:
- Four Bakken formations: middle Bakken, TF1, TF2, TF3 = 6 wells in MB; 5 wells in each of the other three.
- Except that it sounds incredible (21 wells in 640-acre spacing), the density is the same as being tested by CLR and KOG on 1280-acre spacing units.
- Regardless of how many wells one drills in a specific area (aka "well density), the fact is, operators are not going to drill wells if they are not economical. My hunch is that operators in the Bakken won't drill a well if they don't expect a EUR of at least 450,000 bbls.
- EOR is about the only "thing" left to do when one gets to 30-acre spacing (20 wells/640 acres).
- 21 wells x 450,000 bbls x $50 / 640 acres = $740,000 / acre; and that's just primary production. That does not include EOR.
- The jury is still out, but there are operators suggesting that fracking a new well near an existing well improves the production from the existing well. I said that from the beginning. So, we'll see.
- By the time they get to these 17 new wells, the operator will have had several years of experience; by the time they get to these 17 new wells, the operator will have had the opportunity to study "best completion methods" available.
- Think of the cost savings.
- One rig, 17 wells; about 17 months. Full-time employment for a lot of folks for almost two years, and if it works, then do the same thing in the 640-acre drilling unit to the immediate south.
- 17 wells x $8 million = $140 million.
- This section is two miles west of the incredible Whiting Sanish.
