Hess Will Report Three Huge EN-Joyce Wells -- July 11, 2021

Remember how "everyone" says the daughter wells will never do as well as the parent wells. 

Read on. 

The Hess EN-Joyce wells in the Manitou oil field are tracked here. 

A reader recently alerted me to these wells telling me that they should be huge, and that they should be coming off the confidential list shortly. 

The wells were drilled quickly, and completed quickly; the fracks appear to be "moderate" fracks for the Bakken. 

They remain confidential, but runs are being reported:

• 37977, conf, Hess, EN-Joyce-LE-156-94-1721H-6, Manitou, from the permit, sections 16/17/20 & 21-156-94; 844 FSL 749 FWL; 33-061-04835; fracked 4/7/21 - 4/11/21; 10.7 million gallons of water; 85.2% water by mass; note four days for the frack; generally, I expect a seven- to 10-day frack; to come off confidential list, 10/24/21;
  

Date	Oil Runs	MCF Sold
5-2021	51160	58241
4-2021	18287	25524

• 37978, conf, Hess, EN-Joyce-LE-156-94-1721H-5, Manitou, from the permit, sections 16/17/20 & 21-156-94; 844 FSL 782 FWL; 33-061-04836; fracked 4/1/21 - 4/8/21; 11 million gallons of water; 85.5% water by mass; to come off confidential list, 10/29/21;

Date	Oil Runs	MCF Sold
5-2021	63032	102218
4-2021	5259	776

• 37979, conf, Hess, EN-Joyce-LE-156-94-1721H-4, Manitou, from the permit, sections 16/17/20 & 21-156-94; 844 FSL 815 FWL; 33-061-04837; fracked 4/1/21 - 4/8/21; 11 million gallons of water; 85.5% water by mass; to come off confidential list, 11/7/21;

• spud: March 3, 2021
• cease drilling: March 13, 2021
• logging services began at 8,164' at 12:42 p.m.CST, March 5, 2021
• KOP, 10,407', reached at 1:59 p.m. CST on March 6, 2021
• KOP, 10,407', reached at 4:51 a.m. CST on March 6, 2021
• drilling the curve began: 1: 59 p.m. CST, March 6, 2021
• total depth of the curve reached at 10,988; measured depth / 10,272.5' TVD at 9:10 p.m. on March 6, 2021;
• TD reached at 6:15 p.m. CST, March 13, 2021

Date	Oil Runs	MCF Sold
5-2021	47307	27719

The other Hess EN-Joyce wells:

• 17887, the parent well, off-line; never did well; will be interesting to see if it comes back on line; IA/165, Hess, EN-Joyce-156-94-1720H-1, Manitou, t6/09; cum 91K 7/20; remains off line 5/21;
  
• 27313, not an EN-Joyce well, but sited on same pad as the "original" EN-Joyce pad; also drilled back in 2014; not a particularly good well; remains on line; never came off line, 781, Hess, EN-Eva-156-94-1621H-1, Manitou, t9/14; cum 121K 5/21;
• 27314, drilled back in 2014, not a particularly good well; remains on line; never came off line, 349, Hess, EN-Joyce-LE-156-94-1721H-1, Manitou, t9/14; cum 121K 5/21;
  
• 27315, drilled back in 2014, not a particularly good well; remains on line; was taken off line for only two months; appears to be coming back on line 5/21; 142, Hess, EN-Joyce-LE-156-94-1721H-2, Manitou, t8/14; cum 149K 5/21;
  
• 27316, drilled back in 2014, not a particularly good well; was taken off line 7/20 and remains off line, 4/21; 490, Hess, EN-Joyce-LE-156-94-1721H-3, Manitou, taken off line 7/20; returning to production, 5/21; cum 130K 7/20;
  

Parent / Child Wells -- Random Note -- October 11, 2019

Well, look at this.

Regular readers of the blog know that I am inappropriately excited about the "halo" effect -- that jump in production seen in Bakken wells when they are brought back on line after being off line for a few weeks or a few months while neighboring wells are fracked. In some cases (rarely) the "parent" well is off-line for less than a month.

I tag posts discussing this phenomenon as "halo" or "jump in production." I noted the phenomenon almost a decade ago but had not seen validation from a credible source.

[The very first post that was tagged with the halo effect was dated August 19, 2010. Link here: http://themilliondollarway.blogspot.com/2010/08/another-first-for-north-dakota_19.html.]

I did receive a phone call from an analyst at the largest fracking company in the Bakken at that time about six years ago asking me about my observations. The analyst said his company was referring to these as "parent/child" wells. I did not post the specifics of that phone call at that time assuming that some of the information I had been told was proprietary.

[I was in Belmont, MA, when I received the phone call. I was last in Belmont, MA, in 2013: that's why I know that the phone call was at least six years ago.]

I continue to look for validation from credible sources. About a month ago, maybe two or three months ago, I started getting hints of validation from Whiting. I think I have posted some of that, but I can't recall for sure.

Break, break.

It's my observation that the parent / child interaction in the Bakken is "positive." Either there is no effect, a subtle effect, or a huge positive effect, but I have not seen any suggestion that the parent / child interaction is "bad news" in the Bakken.

On the other hand, however, there have been numerous stories in the popular press that this is not the case in other shale plays. There are concerns, particularly in the Permian, that new wells (or "children" wells) are having an adverse effect on older wells ("parent" wells).

Break, break.

Tonight, in the process of looking for something else, I ran across this slide in a recent Whiting presentation.

The link: https://event.webcasts.com/viewer/event.jsp?ei=1260399&tp_key=d761d52d8c.

Slide #9.

Screenshot:

Note: "Parent / child well activity [in the Bakken] is positive vs experience in other shale plays."

By the way, that one slide above has many, many other interesting data points. 

This Is Absolutely, Positively, Not Happening InThe Bakken -- September 20, 2019

The note below is pretty much complete; there may be some fine tweaking but consider it done.

**************************

Off The Radar Scope: Rigs Do Matter 

This is interesting. I had not thought of this. Because there is so little national news regarding the Bakken and because the Permian is getting all the press, a lot of folks outside the region mistakenly think the Bakken has completely slowed down. An operator looking for capital among investors (east coast, west coast) were surprised to hear that the Bakken was still very, very active. Potential investors were surprised to hear that North Dakota was producing as much oil with 50 - 60 rigs as the state was producing (actually more) than when there were 200 rigs in the Bakken (lousy grammar on my part).

So: the number of rigs does matter when it comes to "demonstrating" activity (and perhaps investor interest). That driller, by the way, suggests that North Dakota would likely produce upwards of 2 million bopd in about three years. If the takeaway capacity was sufficient and the price "right," I think we could be at 2 million bopd now.

In addition, see first comment:

Regarding the linked articles below: Basic concept, not news. Poorly explained (some mistakes).

Also, despite the shift to closer spacing [in the Bakken?], we are still not seeing a dropoff in performance. Obviously there must be other aspects that are improving and the net result is okay, on average.

***********************************

The Note

The world's top oil basin is running out of space -- link here.
Permian "child" wells may cut oil recovery up to 20%, bank says -- Bloomberg.

I'm in a rush right now so I will have to come back to this, but this is so not happening in the Bakken.

First of all, it's an old story regarding the Permian, previously posted on the blog, but both Bloomberg and oilprice make it sound like something new.

From the linked articles:

But whatever. It's not happening in the Bakken.

I don't have the statistical analysis, but I have the anecdotal evidence to make that statement. But Whiting does. Exhibit A:

I don't know the Permian at all. I follow it a little bit and have noted a few things. Most important(ly): it appears unconventional / shale basins are not all alike.

I am inappropriately exuberant about the Bakken, so everything that follows, take with a grain of salt. This is my worldview of the Bakken vs other shale plays, particularly the Eagle Ford and the Permian.

First, I think the Bakken is still going to be the best of the three plays (Bakken, Permian, Eagle Ford) in these categories:

• effect the Bakken will have on the state economy compared to that of the Permian/Eagle Ford and the Texas economy
• the amount of money that will be returned to mom-and-pop mineral owners in North Dakota on a per capita basis compared to those in Texas
• crude oil production per well

Now, with regard to the linked articles above, that "child" wells are a challenge in the Permian. It appears to be quite the opposite in the North Dakota Bakken (I can't speak to the Bakken in Montana and/or Saskatchewan).

It certainly appears the operators have figured out the "Goldilocks" density, although even that will change / improve over time.

It appears that in Tier 1, middle Bakken, six wells in 1280-acre spacing will be the norm.

It appears that in Tier 1, first bench Three Forks, six wells in 1280-acre spacing will also be the norm.

All other tiers and all other Bakken formations, the jury is still out.

To see examples of well density in the Bakken, click on the follow tags:

• density projects;
• 24-well array; 
• 28-well density;
• 64-well density;

Years ago I noticed the positive impact that "child" wells had on their parents and on their sibs. I have blogged about that often. An analyst / research student working for Halliburton telephoned me years ago to discuss this with me (he called me; I didn't call him).

I devoted an entire site to these "wells of interest." At the index to that site, one can see all the examples of the positive impact of "child" wells. I think at one time they were called "daughter" wells, but I don't recall for sure. The list of wells has gotten so long, I've pretty much quit doing that. Whether I've "proved" the point or not to others bothers me not at all. I believe what I see.

The Bakken is a bit easier about which to generalize. For the most part, when we talking about the Bakken now (2014 - 2018) we are talking about one formation, about 20 to 40 feet thick, pretty much being fracked about the same by all operators.

I have no clue about the Permian but it's my understanding the unconventional target formations in the Permian are many and they are thick. So, when I see a Bloomberg article with so much generalization it makes me wonder. If I were following the Permian or interested in the Permian I would want to know a lot more specifics.

They used to talk about the Bakken development being like a baseball game and early on we were only in the first inning. No one makes that analogy any more but I would guess we might be in the third inning.

The Permian? Easily the first inning, maybe the bottom of the first inning. But that's it. Based on what little I know about the Permian it sounds like there is a lot to learn. My hunch is that the operators have gone after the absolutely easiest stuff to lift.

Oh, a random note: in the Bloomberg article they talked about "dry" wells in the Permian. That's interesting. Hitting a dry well in the Permian has to be concerning. There are no "dry" wells in the Bakken. We've talked about that before. Yes, some wells are reported as "dry" but that's because of a failure of the well itself, usually a failure in the cementing / casing process. But if the well is completed in the Bakken it will strike oil.

It may not be an "economic" well but we've discussed that also. But it won't be dry.

I have yet to see more than a handful of recent middle Bakken wells abandoned due to low oil production.

MRO Wells In Section 12-150-93 Appear To All Be Back On Line -- Some Huge Wells; Many Reporting Nice Jumps In Production -- August 5, 2019

Newbies: as you look scroll through this post, recall the hand wringing about parent-daughter interference in the Permian. The data below is not atypical for the Bakken, but some fields are much better than others with regard to this phenomenon. Hard to sort out how much has to do with location / oil field, and how much has to do with the operator / completion strategies. Everything I've seen suggests the Bakken operators have a good handle on this issue. Could be wrong.

The well:

• April 2, 2019: see this post. #33668; #18514; #33431; #23176; and, #21458; and, this post. As of 4/19, older wells still off line; as of 6/19, it appears all wells back on line.

One typical example:

• 21458, 1,597, MRO, Tara Jo USA 34-12H, Reunion Bay, t1/13; cum 474K 6/19; six years old with jump in production, cum 532K 7/21;
  

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	6-2019	30	6066	6256	4503	7466	673	6277
BAKKEN	5-2019	22	5528	5316	5803	6915	3465	3014
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	1	1	383	0	2	0	1
BAKKEN	10-2018	28	2479	2422	748	3535	2470	764
BAKKEN	9-2018	30	2769	2848	822	4075	2713	1026
BAKKEN	8-2018	31	2683	2343	832	3869	2002	1528
BAKKEN	7-2018	31	3056	3240	933	4353	3528	466

Another example, this well over nine years old, drilled in the early days of the boom, huge jump in production, over 9,000 bbls in 14 days when it came back on line:

• 18514, 672, MRO, Howard USA 11-1H, Reunion Bay, t6/10; cum 541K 6/19; cum 596K 7/21;
  

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	6-2019	30	5177	5175	3374	4646	4173	168
BAKKEN	5-2019	31	6914	6947	5510	5600	5089	110
BAKKEN	4-2019	30	7947	7897	8218	5888	5353	73
BAKKEN	3-2019	11	2366	2442	2741	427	295	0
BAKKEN	2-2019	14	9012	8957	3785	8622	0	8079
BAKKEN	1-2019	6	1337	1297	4832	1309	0	1224
BAKKEN	12-2018	0	0	0	0	0	0	0
BAKKEN	11-2018	0	0	0	0	0	0	0
BAKKEN	10-2018	14	1127	1702	288	1385	606	638
BAKKEN	9-2018	28	2271	2321	455	2689	2355	36
BAKKEN	8-2018	31	2564	2392	554	3071	2472	263

One of the two daughter wells:

• 33668, 3,278, MRO, Fannie USA 21-1H, Reunion Bay, t2/19; cum 164K 6/19; cum 365K 7/21;
  

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	6-2019	30	27596	27602	16944	38143	34036	2177
BAKKEN	5-2019	31	40184	40283	18783	45312	41413	1158
BAKKEN	4-2019	30	35426	35364	27266	31668	28646	623
BAKKEN	3-2019	29	30217	30294	31773	28173	16645	9466
BAKKEN	2-2019	18	30600	30278	32558	23321	0	21264
BAKKEN	1-2019	2	0	0	150	30	0	30

Reason #1 Why I Love To Blog -- Reader Feedback -- Another Well With 50-Fold Increase In Production -- July 26, 2019

I never would have caught this one. A huge "thank you" to the reader who sent this to me.

The well:

• 17325, 130, Oasis, Thorlaksen 11-14H, 10 stages, 1.35 million lbs, Gros Ventre, t1/09; cum 52K 5/19;

FracFocus: no data suggesting a re-frack. Last NDIC sundry form back in 2013. This well was off line for about one month.

Jump in production: 10,206 bbls over 30 days / 200 bbls / 30 days = 51-fold increase in production.

Recent production, 8,846 bbls over 26 days extrapolates to 10,207 bbls over 30 days:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	5-2019	26	8846	8665	5096	5883	5633	0
BAKKEN	4-2019	4	1	0	363	40	0	0
BAKKEN	3-2019	20	144	311	126	332	132	200
BAKKEN	2-2019	28	129	0	312	466	186	0
BAKKEN	1-2019	31	198	294	273	590	280	0
BAKKEN	12-2018	31	176	0	82	1014	704	0
BAKKEN	11-2018	30	193	322	204	537	237	0
BAKKEN	10-2018	30	188	0	245	576	276	0
BAKKEN	9-2018	30	179	532	197	557	257	0
BAKKEN	8-2018	31	228	0	561	597	287	0
BAKKEN	7-2018	31	188	316	182	358	48	0
BAKKEN	6-2018	30	175	0	234	377	77	0
BAKKEN	5-2018	30	191	323	389	570	270	0
BAKKEN	4-2018	30	199	0	110	619	319	0

 The graphic:

Wells in this graphic:

• 35624, conf, Liberty Resources Management Company, LLC, Gliko 159-93-23-25-1MBHX, runs to the southeast: 

Date	Oil Runs	MCF Sold
5-2019	21957	0

• 35623, conf, Liberty Resources Management Company, LLC, Garnes 159-03-14-2-1MBHX, runs to the north:

Date	Oil Runs	MCF Sold
5-2019	17201	0
4-2019	629	0

• 36052, loc, Liberty Resources Management Company, LLC, Dolores 159-93-22-34-3TFHX, Gros Ventre,

• 36053, loc, Liberty Resources Management Company, LLC, Orris 159-93-15-3-4MBHX, Gros Ventre,

Production Jumps 55-Fold; An Old CLR Lansing Well In Banks Oil Field -- July 26, 2019

Production jumps 55-fold, 9,000 bbls over 31 days in 12/18, from 163 bbls over 31 days in 8/18 -- just four months later. The well was originally drilled / fracked back in 2010. This well had a 55-fold jump in production when it was already eight years old. And it will continue to produce for 30 more years.

Another well, a bit further to the west, also showed a jump in production, but it was only a 3-fold jump in production. 

The well:

• 19126, 76 (no typo), CLR, Lansing 1-25H, Banks, t11/10; cum 412K 5/19;

Recent production:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	5-2019	27	2824	2839	2043	8274	7910	0
BAKKEN	4-2019	30	3514	3402	2373	9208	8123	680
BAKKEN	3-2019	31	3782	3814	2642	8415	7667	330
BAKKEN	2-2019	28	3156	3258	2471	6413	6052	0
BAKKEN	1-2019	31	4240	4222	3462	7187	6548	220
BAKKEN	12-2018	31	8995	9124	10298	10671	9156	1105
BAKKEN	11-2018	12	3338	2959	8663	3605	3308	135
BAKKEN	10-2018	10	47	0	346	145	15	7
BAKKEN	9-2018	30	129	265	733	649	152	92
BAKKEN	8-2018	31	163	0	757	675	256	0
BAKKEN	7-2018	31	148	323	602	636	217	0
BAKKEN	6-2018	30	135	0	624	620	210	5
BAKKEN	5-2018	31	154	290	736	196	196	0
BAKKEN	4-2018	28	210	0	1240	80	80	0
BAKKEN	3-2018	0	0	0	0	0	0	0
BAKKEN	2-2018	0	0	0	0	0	0	0
BAKKEN	1-2018	0	0	0	0	0	0	0
BAKKEN	12-2017	0	0	0	0	0	0	0
BAKKEN	11-2017	28	1567	1608	1069	4629	4629	0
BAKKEN	10-2017	31	1703	1953	1133	5362	5362	0

The graphic:

CLR To Report A Huge Morris Well Today -- July 11, 2019

CLR will report a huge Morris well later today. The Morris well is part of the huge Morris/Carson peak complex in Oakdale oil field. The wells are tracked here; the page has not been updated in quite some time.

The well:

• 35082, conf, CLR, Morris 8-26H1, Oakdale:

Date	Oil Runs	MCF Sold
5-2019	36924	36468
4-2019	36078	35051
1-2019	730	0

The "H1" designation suggests this is a Three Forks well.

The graphics:

 

Let's take a look at this well, which is of the most interest:

• 17334, 811, CLR, Morris 1-23H, a middle Bakken well, API: 33-025-00777, Oakdale, t11/08; cum 298K 5/19; the last sundry form was for work completed November 30, 2013; no FracFocus data to suggest this well was re-fracked; folks are complaining about the parent-child interference problem in the Permian; not so in the Bakken. At least not those receiving royalties from #17334 unless one wants to complain about the amount of time this well has been off line.

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	5-2019	31	13311	13146	9526	14171	13428	358
BAKKEN	4-2019	15	5835	5645	5911	5728	5336	236
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	0	0	0	0	0	0	0
BAKKEN	10-2018	0	0	0	0	0	0	0
BAKKEN	9-2018	0	0	0	0	0	0	0
BAKKEN	8-2018	31	1142	1380	203	1499	1123	0
BAKKEN	7-2018	31	1123	1164	185	1402	927	58
BAKKEN	6-2018	30	1085	899	187	1260	861	0

By the way, as long as we're at it, look at this well in the same area:

• 18859, 680, CLR, Carson Peak 3-35H, a middle Bakken well, 33-025-01076, Oakdale, t5/11; cum 697K 5/19: no FracFocus data to suggest this well was re-fracked, most recent sundry for work completed, dated March 22, 2013:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	5-2019	31	13400	13201	15019	13830	6805	6619
BAKKEN	4-2019	28	13423	13017	10085	13523	10959	2202
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	0	0	0	0	0	0	0
BAKKEN	10-2018	6	518	703	50	565	506	0
BAKKEN	9-2018	30	3615	3721	378	3721	3259	76