Purpose of the blog: to see some innovative drilling by Slawson. Other operators may be doing the same thing, but if so, I've not seen any examples (to the best of my recollection). I've talked before about some of the innovative things Slawson is doing in the Bakken.
Disclaimer: in a long note like this, there will typographical and factual errors. The purpose of the post is to give me an idea of what Slawson is doing in the Bakken. Errors will be corrected when found but errors should not detract from the purpose of the post.
Comment: I particularly enjoyed the common sense solution to a problem encountered by Slawson (see below).
Slawson dual laterals -- transferred White Butte:
Screenshot from October 22, 2019 -- Slawson dual-laterals.
29471,
1,423, Wolf 2-4MLH, Big Bend, t3/15;
cum 289K 8/19; a good well, not a great well;
- lateral #2, middle Bakken: 17 stages; 1.8 million lbs (no typo); 15,095' measured depth;
- lateral #1, middle Bakken: 21 stages; 3.0 million lbs (no typo); 14,570' measured depth;
19993,
IA/1,242, no production since 8/18; Hunter 2-8-17H, Big Bend, t11/11;
cum 285K 8/18;
- a good well, but off line for the past year, concerning; local oil spill discovered 6/22/19; frack data, middle Bakken, 10/25/11, 28 stages; 2.6 million lbs; open hole;
30074,
981 (two sundry forms; see below; 981/238), Slawson, Howo 2-4-33MLH, Big Bend, t4/15;
cum 521K 7/19;
- huge well; came off line 7/19; remains off line 8/19;
- lateral 2, IP = 238: middle Bakken, 31 stages; 4.5 million lbs; 4/18/15;
- lateral 1, IP = 981: middle Bakken, 25 stages; 4.7 million lbs; 7/25/16;
- both laterals completed during same time period, March 18, 2015;
- spud date, February 10, 2015
- vertical, big rig, began on/about February 17, 2017
- the curve was begun February 19, 2015, and completed February 21, 2015
- lateral 1: completed March 4
- lateral 2: began, March 8, 2015; completed March 18, 2015, although in the "conclusion," the geologist states the well was completed march 8, 2015 (which makes more sense); challenges with completing the lateral
30540,
SI/NC, Slawson, Jeriyote 8-5-32MLH, Big Bend, no production data,
- FracFocus shows the well fracked 10/2/2019 - 10/11/2019; 11.4 million gallons of water (a big frack); 91% water by mass; sand, 8.7% by mass; only one lateral on the initial permit, but a sundry form in autumn, 2018, with a request for an additional lateral;
- lateral 1 BHL: 200' FNL & 1320' FEL, 32-152-92
- lateral 2 BHL: 200' FNL & 2640' FEL, 32-152-92
- so, the "big frack" if divided between two laterals, relatively modest fracks
30763,
SI/NC, Slawson, Hunter 5-8-17MLH, Big Bend, no production data, was to be a dual lateral;
- then February 20, 2016, permit was canceled for economic reasons (sundry form); sundry form, August 17, 2018, request for name change to Hunter 5-8-17MLH;
- then, of all things, a Jun 23, 2019, sundry form, "Slawson is submitting a drill plan change for a 3rd lateral due to technical issues on previous two laterals. Please see attached plan ...."
- to sort this out, I'll wait for the frack data
30764,
PNC, Slawson, Hunter 10-8-17
TF2H, Big Bend,
- sundry form, received October 23, 2014, mentions that #18792 was drilled with a Triple Combo open hole log suite
- sundry form, received February 2, 2016, permit canceled for economic reasons
32276,
link here or see below the fold:
*******************************************
Re-Posting
A Slawson Dual Lateral
Three Forks
First Bench / Second Bench
The well:
- 32276, 433, Slawson, Gobbler Federal 4-26-35MLH, Big Bend, t6/19; cum 8K 8/19;
The graphics:
Frack data:
- western lateral, first bench, Three Forks: 46 stages; 9.62 million lbs;
- eastern lateral, second bench, Three Forks: 46 stages; 9.78 million lbs;
From the well file:
- spud date: July 28, 2018 (small rig)
- cease drilling: September 5, 2018
- first bench:
- 20,708' TD
- 10,196.20' TVD
- 11,54796' VS
- second bench:
- 20,900' MD
- 10,241.89 TVD
- 11,602.89 VS
- dates:
- spudded July 28, 2019
- lateral 1 reached TD on August 25, 2018
- lateral 2 began at 10,659' MD on August 31, 2018, and reached TD on September 5, 2018
- drilling hours:
- vertical: drilled in 59.5 hours in two runs
- curve: drilled in 15.7 hours in two runs
- lateral 1, first bench, 55.82 drilling hours in a single run; 100% in zone;
- lateral 2, second bench, 80.1 drilling hours in a single run; 100% in zone; gas between 246 and 5,895 units;
