Background: we entered "Bakken 4.0" in March, 2020. My hunch is that fracking / completion strategies will change -- some operators will change immediately; others will take a little longer.
very low percentage of fresh water, supplemented with produced water;
- 6.1 - 7.0 million gallons of water; 58.7% and 70.2% water by mass; link here;
- 7.0 million gallons of water; 70% water by mass; Antelope-Sanish; link here;
- several examples; link here;
- 6 - 8 million gallons of water; 65% water by mass; link here; "National Park" wells in Eagle Nest oil field;
- 6 - 8 million gallons of water; 65% water by mass; Enerplus Cloudy pad; tracked here;
- 12 - 14 million gallons of water; 92% to 94% water by mass; the Oasis Joplin wells in Banks oil field;
- 19 million gallons of water; 92% water by mass; another Joplin well in the Banks oil field;
- 11.6 million gallons of water; another with almost 19 million gallons of water; both with water about 93% by mass; two of several Bobby wells in Squires; north of Williston, not a particularly great field;
- 18 million gallons of water; 93.4% water by mass; the XTO Cole wells in Siverston oil field;
- 17.9 million gallons of water; 90.4% water by mass; an XTO Arlys well in Siverston oil field;
- 24 million gallons of water; 93% by mass; a USA well in Charlson oil field;
- 15.4 million gallons of water; 92.5% water by mass; a USA well in Phelps Bay;
small - medium fracks
- Clarks Creek, Antelope-Sanish: 5.6 million gallons of water; 85% water by mass;
- 33 stages; 5.1 million lbs: #31639;
- 37 stages; only 4.3 million lbs; very small; #30232; also, #30233;
- 30 stages; 10 million lbs for Three Forks and middle Bakken;
- Tioga field: 11 million gallons of water, middle Bakken;
- decreased stages (23); small amount water; very small amount friction reducer;
- WPX, Rubia: 5.2 million gallons of water; small frack; huge well;
- WPX: Badger, Squaw Creek: 5.1 million gallons of water; 83% water by mass;
medium - large fracks
- Oliver oil field, Hobart well: 10.2 million gallons of water;
Nine Point Energy:
- frack data not yet available from the NDIC:
- from FracFocus, moderate fracks with 7 - 8 million gallons of water:
- huge wells, Antelope-Sanish;
I was unimpressed with the initial production for the Whiting well that came off the confidential list today, especially for Big Bend oil field, but then I saw the number of stages -- only 35 stages and a moderate frack, 7.4 million lbs.
The question becomes:The well:
- when oil is trending toward $0/bbl (no typo), is it more economical to max out the frack to get highest IP possible and then choke back for a year; or is it more economical to minimize initial production using a smaller frack and then coming back (years later?) when prices are better?
Completion strategies beginning in 2018 are tracked here.
- Other questions:
- does choking back cause more problems for the "durability" of a well?
- what affect on the well is caused by choking back for a year or longer?
- fracking is now said to account for upwards of 2/3rds of total cost of a new well; if much of that is due to cost of sand (transportation, etc), does it make sense to use smaller frack, better technology?
- 36323, 563, Whiting, Oppeboen 14-5HU, Big Bend, t10/19; cum 62K 1/20; 1K month; 35 stages; 7.4 million lbs; fracked 8/1/19 - 8/7/19; 6.5 million gallons; 87.7% water by mass (on the low side, by percentage);
- wow, look how fast they drilled this well
- spud: June 3, 2019
- cease drilling: June 11, 2019
- logging services began at 1930 hours, June 5, 2019
- the curve was landed at 0850, June 8, 2019
- lateral began at 0550, June 9, 2019
- drill rates averaged 400 ft/hour