The CLR Hendrickson Wells Have Been Updated -- March 25, 2018

Random look at the huge jump in production in one of the CLR Hendrickson wells. The well:

• 18224, 1,099, CLR, Hendrickson 1-36H, Elm Tree, t12/09; cum 755K 4/20; off-line as of 2/17 as more Hendrickson wells are completed; came back on-line 4/17; huge jump in production; FracFocus -- no evidence of re-frac; no sundry form suggesting this well was re-fracked but the huge jump in production suggests that it must have been re-fracked

BAKKEN	8-2017	31	18525	18942	13926	28888	25086	3567
BAKKEN	7-2017	31	12330	12168	13382	19280	17650	1430
BAKKEN	6-2017	30	16936	16845	17495	25895	24705	950
BAKKEN	5-2017	31	22186	22338	22567	39103	25885	12971
BAKKEN	4-2017	20	16275	15840	28381	22993	16226	6611
BAKKEN	3-2017	0	0	0	0	0	0	0
BAKKEN	2-2017	0	0	0	0	0	0	0
BAKKEN	1-2017	0	0	0	0	0	0	0
BAKKEN	12-2016	0	0	0	0	0	0	0
BAKKEN	11-2016	2	6	413	165	2	0	0
BAKKEN	10-2016	18	2274	2044	250	1971	1838	42
BAKKEN	9-2016	24	2179	2210	243	3522	3085	69

The Hendrickson wells are tracked here. Production data has been updated; an updated graphic has been posted.

Random Case Study Of WPX Wells In Reunion Oil Field -- March 26, 2018

Updates

November 15, 2018: production update for #19246:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	9-2018	30	3399	3385	1458	4811	4286	0
BAKKEN	8-2018	31	3604	3586	1642	5021	4464	0
BAKKEN	7-2018	31	4339	4406	2072	5585	3462	1262
BAKKEN	6-2018	28	4228	4220	3316	5441	2204	2423
BAKKEN	5-2018	27	1102	1123	359	1419	483	437
BAKKEN	4-2018	30	1327	1344	534	1712	1188	0
BAKKEN	3-2018	31	1679	1558	654	2161	86	1498
BAKKEN	2-2018	4	123	140	306	241	8	0
BAKKEN	1-2018	1	1	0	2	231	0	0
BAKKEN	12-2017	8	299	342	179	624	457	0
BAKKEN	11-2017	30	1145	1105	280	2034	1657	0
BAKKEN	10-2017	31	1527	1558	382	2027	1465	0

 

Original Post

 

Incredibly nice well comes off line:

• 19246, 1,425, WPX, Wells 32-29H, Reunion Bay, t3/11; cum 546K 1/18; 

Recent production:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	1-2018	1	1	0	2	231	0	0
BAKKEN	12-2017	8	299	342	179	624	457	0
BAKKEN	11-2017	30	1145	1105	280	2034	1657	0
BAKKEN	10-2017	31	1527	1558	382	2027	1465	0
BAKKEN	9-2017	28	1343	1316	492	1729	1051	164
BAKKEN	8-2017	31	2471	2505	438	3180	2384	137
BAKKEN	7-2017	31	2986	2989	465	3843	2747	379
BAKKEN	6-2017	30	3017	2978	524	3883	2318	857
BAKKEN	5-2017	31	3474	3486	619	4470	2787	914

For wells like this -- 3K/month after seven (7) years of production and a cumulative of over one-half million bbls of oil -- and then taken off-line -- one suspects some activity in the area -- 

The graphic:

From the graphic: two things to key in on.

First, #28590:

• 28590, 1,258, WPX. Victor Elk 32-29HB, Reunion Bay, t1/15; cum 313K 1/18; look at the jump in production 1/18; FracFocus does not show any re-frack but that could be due to the fact that paperwork not yet received; no sundry form to suggest any plan to re-frack (this well will be interesting to follow -- to see if re-fracked or not); it was recently off-line for all of 22 days; look at recent production:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	1-2018	27	16599	16784	7564	18375	12960	3396
BAKKEN	12-2017	12	1399	1353	1112	1509	801	406
BAKKEN	11-2017	30	4854	4949	2194	5373	3135	1334
BAKKEN	10-2017	22	3509	3274	1701	3884	1926	1241
BAKKEN	9-2017	30	4655	4814	2603	5153	1527	2741
BAKKEN	8-2017	31	4857	4719	2905	5377	3705	754
BAKKEN	7-2017	31	4983	5122	2734	5516	3761	824
BAKKEN	6-2017	30	4362	4313	2576	4830	2125	1854
BAKKEN	5-2017	18	2958	3028	2154	3275	1757	877
BAKKEN	4-2017	30	4761	4705	3333	5271	2910	1492
BAKKEN	3-2017	31	4798	5032	3684	5311	3590	810
BAKKEN	2-2017	28	5992	5927	5498	6632	5245	386

The second thing to key in on: the three wells on confidential status -- #32671, #32672, #32673. All three have been fracked based on production data on the confidential scout tickets:

• 32671, 10K produced after well completed; number of days of production not known;
• 32672, 18K produced after well completed; number of days of production not known;
• 32673, 19K produced after well completed; number of days of production not known;

These are going to be very nice wells. My hunch: 150K+ in first six months.

Now, let's see if FracFocus has anything: yes, they have all been fracked, see dates of frack below --

• 33-025-03139, 12/172017/ - 1/4/2018;
• 33-025-03140, 12/162017/ - 1/4/2018;
• 33-025-03141, 12/172017/ - 1/4/2018;

I'm not going to go through all three because completion strategies are generally similar on neighboring wells fracked at the same time. I looked at two frack reports and the frack reports are almost identical (at FracFocus). Wow, these are small fracks, less than 6 million gallons of water.

33-025-03140: 

• 5,418,936 gallons of water
• 45,221,021 pounds of water 
• water was 87.43% by mass
• 87.43% of ? = 45.221 million lbs
• 51,722,545 total pounds
• sand: 11.75%
• 11.75% of  51,722,545 total pounds = 6077399 lbs of sand
• my estimates seem to come in low, so my hunch is that about 8 million lbs of sand used in the frack; a relatively small frack by today's standards; or maybe "moderate" would be better adjective. Whatever.

So, we learned or noted several things from this exercise simply by noting that a great well had recently come off-line and the obvious question was why? What did we learn or note?

• yes, indeed, there has been recent activity in this area that is not shown by the NDIC map
• three wells have been completed and will report out in the near future (that data is available over at the NDIC but it's irrelevant to me, so I won't look it  up)
• we observed a neighboring well that was taken off-line for 18 days and when it came back on-line production jumped from 4,000 bbls / month to 18,000 bbls / month
• generally a well is taken off-line for a longer period of time if it is going to be re-fracked, suggesting this well was not re-fracked; on the other hand, the jump in production was so great, it's hard to believe it was not re-fracked -- perhaps a mini-re-frack? but I would expect FracFocus to have that data -- it does not
• the amount of water used was incredibly low -- only 5.5 million gallons of water; a typical EOG well in a different field would have used 10 million gallons 
• the amount of sand on a percentage basis was higher than what I normally see; I normally see about 8% sand by mass; this frack used almost 12% by mass
• FracFocus does not identify the size of the sand used; we will have to wait for the operator's report

We will learn a lot more when the wells come off the confidential list.
 
Also noted: #29737 was taken off line for 20 days in December, 2017, and 17 days in January, 2018. It will be another month before we see if that well was affected. #29737 is 211 feet east of #19246.

Nice Jump In Production -- CLR Quale Well In Antelope Oil Field -- March 25, 2018

FracFocus has no data to suggest this well was re-fracked.

Three Forks well; 30 stages; 2.9 million lbs; 1/2/2012

Well changed from flowing to pump; November 1, 2012. Paperwork received by NDIC August 22, 2017.

No other sundry forms of note between 2012 and 2017.

Nothing to suggest any re-frack.

The well:

• 19232, 1,423, CLR, Quale 1-1H, Antelope, Sanish pool, t2/12; cum 470K 1/18; 

Production profile from mid-2014 to mid-2015:

Pool	Month	Days	BBLs  Oil	Runs	BBLs Water	MCF Prod	MCF SOLD	Flare
SANISH	5-2015	31	6844	6865	4028	6601	6265	88
SANISH	4-2015	29	10297	10648	6170	9362	9138	0
SANISH	3-2015	31	15346	15066	8247	15631	15383	0
SANISH	2-2015	28	10152	10485	6035	11069	10849	0
SANISH	1-2015	25	11394	10881	7898	12912	12715	0
SANISH	12-2014	0	0	0	0	0	0	0
SANISH	11-2014	20	1908	2329	353	2860	2754	0
SANISH	10-2014	31	4391	4578	972	6789	6541	0
SANISH	9-2014	30	4273	3824	913	3154	2926	0
SANISH	8-2014	31	4690	4660	1083	6680	6432	0
SANISH	7-2014	31	4525	4627	912	5363	5363	0
SANISH	6-2014	30	4566	4469	925	5313	3973	1340
SANISH	5-2014	31	5212	5285	1025	5877	3722	2155

The graphic:

Fracked, according to FracFocus, 12/14/2014 - 12/28/2104:

• 28930, 1,132, CLR, Quale Federal 2-1H, Antelope, Sanish pool, 30 states; 3.5 million lbs;  t2/15; cum 346K 1/18; 

Many, many story lines.

Week 12: March 18, 2018 -- March 24, 2018

By the end of the week, the Dow had tanked, and WTI traded above $65. Congress passed and the president signed a $1.3 trillion omnibus spending bill.

In the energy sector, it was relatively quiet, and so was the Bakken.

Operations
Production data for a great well has been "corrected" -- still a great well but not as good as originally reported
NOG looking to make new acquisitions
An old EOG short lateral coming up on 600,000 bbls of crude oil cumulative
Top North Dakota energy stories from ndenergy.org

Fracking
Varying amounts of proppant being used across the Bakken
Random update of an MRO mini re-frack in Antelope oil field
Frack using 20 million lbs sand 

Pipeline
US Army Corps of Engineers miss DAPL deadline

Bakken 101
A case study, two Slawson wells

Bakken economy
Williston voters reject school bond
North Dakota pols eager to spend Legacy Fund money
Steffes to expand Dickinson manufacturing facility

Commentary
The myths of shale -- Richard Zeits
Bakken reality check 

151-94-17; Antelope-Sanish; EOG

Case 19211, NDIC hearing dockets, W/2, 17-151-94, Antelope-Sanish, EOG, 6 wells on a 320-acre spacing unit.

See this post.

Updates

December 8, 2019: 10-well pad to the north; three wells drilled to depth and in section 17; other seven locations on this pad are permitted, but no further activity:

• 34584, 806, Enerplus, Crocodile 151-94-17A-20H- TF, t1/19; cum 251K 10/19;
• 34583, 639, Enerplus, Alligator 151-94-17A-20H, t1/19; cum 241K 10/19;
• 34582, 309, Enerplus, Komodo 151-94-17A-20H- TF, t1/19; cum 247K 10/19;
• 34581, loc, Enerplus, Anole ..
• 34580, loc, Enerplus, Frilled ..
• 34579, loc, Enerplus, Basilisk ...
• 34578, loc, Enerplus, Gecko ...
• 34577, loc, Enerplus, Cayman ..
• 34576, loc, Enerplus, Lizard ...
• 34575, loc, Enerplus, Tegu ..

May 19, 2019: as of1/19, both of these wells, the only wells in this drilling unit, went inactive and remain inactive as of 3/19; 

Original Post

Update: no additional drilling has been accomplished. There are only two short laterals in this section:

• 20307, in the west half, 1,328, EOG, Clarks Creek 103-17H, Antelope, Sanish pool, t11/11; cum 153K 12/18; only 1,000 bbls/month;
  
• 19693, in the east half, 722, Enerplus, Danks 17-44H, Antelope, Sanish pool, t7/11; cum 234K 12/18; only 1,000 bbls/month;