Comparing Two Side-by-Side CLR Wells -- Bakken, North Dakota, USA

Elsewhere, they are discussing the Genevieve wells in Hamlet field drilled by Continental Resources.

I'm still learning the fine points of interpreting well files (some of which are not completed in the first place).

So, here's a first look at the two Genevieve wells. As noted, these are in Hamlet field, up north, in Divide County, not the core Bakken as generally accepted.

1. Looking at the GIS map server, they parallel each other, probably about 800 feet separation laterally, base on the map. They are both long laterals, running pretty much straight north-south.

2. From their names, and from the NDIC pool, one cannot determine exactly which formation the wells target. Both have a simple "H" designation; the NDIC says both are in the Bakken pool.

3. 20540, 377, Genevieve 2-27H, TD - 18,863 feet, targeted the middle Bakken, at 9,082 feet; 24 frac stages, and ~ 3 million pounds of proppant (about 2 million pounds sand;  < 1 million pounds ceramic -- numbers rounded); no acid reported.  S4/11; T7/11; cumulative 12K (but only 36 days of production); not yet on a pump.

4. 18598, 549, Genevieve 1-27H, TD - 18,708 feet (note the difference of 155 feet), targeted the Three Forks at 9,175 feet; pump; number of frac stages not reported on SFN 2468; ~ 2 million pounds of proppand (note the difference; about 650,000 pounds of ceramic); no acid reported; S2/20; T4/10; cumulative 64K -- about 16 months)

5. Slightly more ceramic proppant used in the middle Bakken well; lower IP in the middle Bakken compared to the TF. Three Forks about 100 feet deeper than the middle Bakken in this area. Again, some numbers rounded.

6. Note the time interval between spudding and testing: well within the six-month confidential period suggesting that CLR's five dedicated frack teams are keeping up with the drilling, at least here.

7. So, about 500 feet lateral separation and 100 feet horizontal separation; two formations in same spacing unit (1280-acre unit. Good enough wells to justify 500-foot spacing in both formations, which would mean 6 - 8 wells in this spacing unit eventually.

8. In addition to these wells, I looked at six (6) other wells in the immediate area. They were all CLR long horizontals, all had IPs in the 400 - 700 range. It appears all will hit 100,000 bbls cumulative in about 18 months. I use the 100,000 bbl milestone to track when wells should pay for themselves at the wellhead.