This Is Simply Another Example Of All The Work That Is Left To Be Done In The Bakken -- November 10, 2019

Another shout-out to the roughnecks. 

This is an incredible story. So many story lines. Note the "new" production data, and then think about full-cycle costs; half-cycle costs; costs during a downturn in the oil sector; etc., etc. 

All of a sudden that CLR Cedar Coulee case in the September, 2019, hearing dockets starts to make sense.

First, look at this post from earlier today: OMG! CLR Did It Again! The CLR Carus Wells -- Cedar Coulee -- Section 28-147-96.

The phenomenal Carus wells are sited in section 28-147-96 and run north into section 21-147-96.

From the September, 2019, hearing dockets, this case (not a permit):

28056, CLR, Cedar Coulee-Bakken, on an existing 2560-acre unit, sections 20/29/32-147-96; and, section 5-146-96; 22 wells; Dunn County

This 2560-acre unit is a four-section stand-up directly west of the Carus wells. There are already six wells in those four sections, but they are 1280-acre spaced wells.

So, let's look at #16648 again; there was something that caught my eye. The NDIC map suggests this old well has a second lateral which is not often seen in an old well in the Bakken (or any Bakken well for that matter unless there was a problem with the first lateral).

The well:

• 16648, 508, CLR, Carus 13-28H, Cedar Coulee, t8/07; cum 411K 9/19;

From the file report:

• permit: a Burlington Resources well with a different name: Carus 24-28H
• back in 2007, it was spud, drilled to depth; IP of 508; Oakdale field; open hole frack with 1 million lbs sand;
• in January, 2008, the well was transferred to CLR (still Carus 24-28H)
• sundry forms continue to show this as file #16648, Carus 24-28H
• stripper well determination, June 17, 2016, by CLR
• name change to Carus 13-28H, October 16, 2018
• November 10, 2018: CLR sundry form that is plans to re-enter this well
• the Carus 13-28H is a re-entry horizontal
• it was originally spud June 10, 2007
• the re-entry was completed November 28, 2018
• so this is lateral #2 which I believe runs straight north and is west of lateral 1, the original horizontal
• side-tracking (the second lateral) began on November 24, 2018; total depth was reached November 28, 2018
• frack data is not yet posted at the NDIC site
• FracFocus says the well was fracked, 2/20/19 - 3/6/19; a huge frack: 11.6 million gallons of water; 88.9% water by mass; 10.6% sand by mass;

Recent production:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	9-2019	29	26143	26021	32423	32299	31805	165
BAKKEN	8-2019	31	40586	40539	54740	48579	47682	478
BAKKEN	7-2019	30	42528	42338	60150	53111	45791	6925
BAKKEN	6-2019	0	0	0	0	0	0	0
BAKKEN	5-2019	4	208	194	6350	2469	0	2428
BAKKEN	4-2019	0	0	0	0	0	0	0
BAKKEN	3-2019	0	0	0	0	0	0	0
BAKKEN	2-2019	0	0	0	0	0	0	0
BAKKEN	1-2019	0	0	0	0	0	0	0
BAKKEN	12-2018	0	0	0	0	0	0	0
BAKKEN	11-2018	7	121	430	20	202	71	50
BAKKEN	10-2018	31	637	579	107	1044	6	619
BAKKEN	9-2018	30	620	755	83	1040	25	610

Re-entry or new well: this brings us back to a discussion back in the early days of the Bakken boom. Mark Papa, CEO of EOG at the time, said it would be easier to drill a brand-new neighboring well than to re-enter/frack an older/existing well. The jury is still out on that, of course, but I have seen no (?) examples of an operator drilling a new well right next to an existing well, and plugging the older, existing well. I have seen many re-entry wells. I have also seen many re-fracked wells. And finally, I have seen so many older wells with a jump in production despite no new frack simply due to new neighboring wells being fracked that I no longer bother to track them, except by exception. I now lump all of these together as "advantaged oil" which is not quite the correct definition as used by BP and others, but I like it for the Bakken. Makes my life easier.

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This was the original production back in 2007 after the first frack:

BAKKEN	3-2008	31	7022	7082	167	111	111	0
BAKKEN	2-2008	29	7504	7419	227	4200	4200	0
BAKKEN	1-2008	31	9206	9299	378	7633	7633	0
BAKKEN	12-2007	31	8448	8431	305	7059	7059	0
BAKKEN	11-2007	30	8773	8617	249	8107	8107	0
BAKKEN	10-2007	31	11772	11829	564	10697	10697	0
BAKKEN	9-2007	30	14220	14180	858	623	623	0
BAKKEN	8-2007	31	10833	10729	2252	0	0	0

Second Frack For A Bruin Antelope-Sanish Well -- November 3, 2019

Again, another example of what the Bakken is capable of. This is simply not supposed to happen, but in the Bakken it happens with regularity. Absolutely incredible. 

Full production profile for this well at this post. This well was drilled back in 2013; fracked then; re-fracked in late 2018; was off line from April, 2016, until January, 2019, off line for almost three years.

By the way, #24731 in the same area is another huge Bruin well with 619,000 bbls cumulative. 

The well:

• 24739, conf-->loc-->DRL/IA->A, Bruin/HRC, Fort Berthold 152-94-15B-22-5H, Antelope-Sanish, 5K first month; cum 92K 2/14; no indication this well has been fracked yet, but I assume it has (2/14); cum 471K 9/19;

Drilled back in 2013; fracked then; re-fracked in late 2018; was off line from April, 2016, until January, 2019, almost three years -- this is the production data after the second frack, and well after the second frack:

Second frack:

• 24739, 2,668, Bruin, Fort Berthold 152-94-15B-22-5H, 2-section spacing; Antelope-Sanish, 54 stages; 8.9million lbs, t12/18; cum 471K 9/19;

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
SANISH	9-2019	30	9781	9873	3644	32525	27612	4196
SANISH	8-2019	31	12290	12479	4814	54228	45039	8310
SANISH	7-2019	31	15416	15318	6795	60623	29085	30795
SANISH	6-2019	30	18174	18222	7577	62340	23449	38181
SANISH	5-2019	31	22307	22237	9210	60529	26685	33150
SANISH	4-2019	30	29761	29741	15918	79260	32013	46546
SANISH	3-2019	26	37610	38091	16837	81914	41253	40013
SANISH	2-2019	28	42504	42149	30362	82673	57994	23544
SANISH	1-2019	17	21841	21242	26488	31271	10121	20739
SANISH	12-2018	0	0	0	0	0	0	0
SANISH	11-2018	0	0	0	0	0	0	0
SANISH	10-2018	0	0	0	0	0	0	0