16986 -- An Update -- January 16, 2025

Locator: 44695B.

Many years ago, probably in 2014, I placed a note to remind myself to check on this well at a later day. I followed up with another note to check again in December, 2023, because there was nothing to report. I completely forgot to check up on it in December, 2023, so I finally got around to checking it tonight. To say the least, it's confusing to me.

Here's the original post and the well:

May 6, 2021: EOG's application -- stripper well determination.

• 16986, INJP/1,347, EOG, Parshall 20-03H, s1/08; t 5/08; AL; cum 309K 1/22; short horizontal.
  

Gas injection, began in 2014:

• 16986, INJP/1,347, EOG, Parshall 20-03H, s1/08; t 5/08; AL; cum 275K 11/17; short horizontal. 

For quite some time, that well has been inactive. In 2023, the NDIC apparently wanted EOG to either abandon the well or start production, again.

There's a sundry form, dated April, 2024, that EOG was getting ready to put new wells on the pad.

Checking the pad tonight, the parent well:

• 16986, IA/INJP/1,347, EOG, Parshall 20-03H, s1/08; t 5/08; AL; cum 309K 1/22; short horizontal; minimal production in September, 2024, and then back off line, t5/08; cum 318K 9/24; now inactive;two new wells, both drl/A status:

The two new daughter wells:

• 39846, drl/A, EOG, Parshall 172-0312H, t8/23; cum 237K 11/24;

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	11-2024	30	10250	10176	5000	12799	12655	144
BAKKEN	10-2024	28	9832	9869	5372	10865	10796	69
BAKKEN	9-2024	27	9268	9216	4791	10509	10352	69
BAKKEN	8-2024	31	12127	12253	6252	11923	11732	90
BAKKEN	7-2024	31	13734	13758	6133	11951	11738	213
BAKKEN	6-2024	30	13924	13925	6142	11004	10809	195
BAKKEN	5-2024	31	14447	14515	6562	10241	10043	198
BAKKEN	4-2024	30	14618	14518	6654	9524	9326	198
BAKKEN	3-2024	30	12812	12733	6739	7486	7305	181
BAKKEN	2-2024	28	9769	9823	6697	5737	5678	59
BAKKEN	1-2024	31	12725	12739	4580	7550	7482	68
BAKKEN	12-2023	31	15306	15277	7369	8302	8240	62
BAKKEN	11-2023	30	16058	16163	9225	7833	7769	64
BAKKEN	10-2023	31	25626	25690	14002	12003	11905	98
BAKKEN	9-2023	30	30573	30479	24464	15611	15487	124
BAKKEN	8-2023	31	15658	15346	11426	7700	7644	56

• 39847, drl/A, EOG, Parshall 173-0312H, t8/23; cum 232K 11/24;

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	11-2024	30	8429	8389	7180	9375	9268	107
BAKKEN	10-2024	31	9747	9801	7880	10334	10272	62
BAKKEN	9-2024	30	9997	9918	8095	10071	10001	66
BAKKEN	8-2024	31	11321	11426	8643	9852	9772	75
BAKKEN	7-2024	31	12185	12215	9277	10510	10415	95
BAKKEN	6-2024	30	12752	12792	9542	9985	9900	85
BAKKEN	5-2024	31	15035	14940	10892	10548	10451	97
BAKKEN	4-2024	23	8812	8926	8470	5421	5365	56
BAKKEN	3-2024	31	15787	15854	12014	9313	9229	84
BAKKEN	2-2024	29	20128	20090	14654	11786	11699	87
BAKKEN	1-2024	31	18683	18666	20117	11065	10985	80
BAKKEN	12-2023	31	20325	20281	25313	11010	10942	68
BAKKEN	11-2023	30	20929	20909	25515	10196	10125	71
BAKKEN	10-2023	31	21660	21554	31180	10140	10063	77
BAKKEN	9-2023	21	13779	13850	22043	7342	7291	51
BAKKEN	8-2023	11	12757	12503	17739	6783	6741	42

The first thing I noticed, other than the fact these were nice wells, was the chronologic number of the two new wells but the parent well is still inactive despite the fact that the two new daughter wells have been producing since August, 2023. 

It looks like I will have to come back to the parent well and check it again in a few months.

Whiting's Multi-Well Pad (Permits) in the Sanish -- The Bakken, North Dakota, USA

Locator: 9999B.

In today's daily activity report, NDIC reports permits for a Whiting 3-well pad in the Sanish oil field.

Whiting has provided graphics of how they planned to drill their cash cow, the Sanish oil field, in their corporate presentations over the past year. They have never shown a multi-well pad in those graphics, unless they have shown this in a new corporate presentation that I have not seen.

A multi-well pad in the Sanish is rare, but this is not the first.

Whiting is already putting five to six wells in some sections (1280-acre spacing) but this is a rare multi-well pad for them in the Sanish.

I was surprised to hear today that folks are still unaware that there are areas in the Bakken in which there are more than one or two wells in a section. Whiting has been putting in four to six wells in individual sections (1280-acre spacing) for quite some time now.

The permits for this multi-well pad are:

• 22173, 1,180, Whiting, Carl Kannianen 22-32TFX, section 32-154-91; t9/12; cum 182K 3/17;
• 22174, 3,126, Whiting, Kannianen 22-32XH, section 32-154-91; t9/12; cum 354K 3/17;
• 22175, 1,249, Whiting, Kannianen 22-32TFX, section 32-154-91; t9/12; cum 198K 3/17;

These three will be on one pad; the pad will lie on a northwest to southeast line.

There are already two horizontals in this section:

• 18298,  3,422, Whiting, Kannianen 44-33H, Sanish; t1/10; cum 664K 3/17; 10K/month in May 2012; the well was taken off-line in September, 2011, and did not produce again until 11/11 when it was active for 2 days, producing 960 bbls in November, 2011; when active it produces 15,000 bbls/month
• 19174, 2,090, Whiting, Kannianen 43-33H, Sanish; s7/10; t10/10; cum 365K 3/17; 1,300 bbls in May, 2012; the well was taken off-line in September, 2011, and did not produce until 11/11 when it produced 754 bbls over 9 days; prior to that, it was producing 12,000 bbls/month

************* There is another Whiting 3-well pad in the Sanish, very similar nomenclature:

• 21988, A , Whiting, Tiisto 44-7TFX, section 7-154-91; t5/12; cum 150K 3/17;
• 21989, 2,480, Whiting, Tiisto 44-7XH, section 7-154-91; t5/12; cum 346K 3/17;
• 21990, 688, Whiting, Tiisto 43-7TFX, section 7-154-91; t4/12; cum 133K 3/17;

Seven (7) New Permits -- Another 100,000 Bbl-Well at Six Months -- Minimal Sand Frac --The Bakken, North Dakota, USA; December 15, 2011

Daily activity report, December 15, 2011 --

Seven (7) new permits --

• Operators: Dakota-3 (3), Whiting, OXY USA, North Plains, CLR
• Fields: Arnegard, Willmen, Van Hook, Truax, and Viking

That Arnegard field well is a Whiting well, right in the bull's eye of the Bakken.

Reported elsewhere were the wells released from the confidential list today. Three were not fracked/completed; they did not report an IP. The fracking backlog continues.

Two wells on DRL status reported IPs today, including another good Hess well:

• 19841, 930, Hess, Solberg 15-8H, Bakken, Williams County; t9/11; cum 135K 4/17;

Dakota-3 is using slightly different nomenclature in naming their wells; these three will be on the same pad (see this post for an update, ten years later):

• 22071, LOC-->conf-->drl (1/13) -- TATD, WPX/Dakota-3, State of ND 10-3HY, Van Hook
• 22072, 1,664, WPX/Dakota-3, State of ND 10-3HC, Van Hook, t5/13; cum 349K 3/17;
• 22073, 1,227, WPX/Dakota-3, State of ND 10-3HZ, Van Hook, t5/13; cum 290K 3/17;

Any history in that area? Yup:

• 18735, 1,936, Dakota-3, State of ND 10-3H, Van Hook, Bakken, s12/10; t4/11; cum 502K 3/17; 126K bbls in less than seven months; 25 stages; 282K pounds of sand

Note the amount of sand used in this frac: 282K (unless it's a typo); generally operators are using 2 - 4 million pounds of sand, with or without ceramics.

Wow, there are some good wells out there.

KOG Links and News -- Negotiating for Fourth Rig -- Dedicated Fracking Crew -- Bakken, North Dakota, USA

Locator: 10010KOG

 

Updates

January 26, 2025: production data updated. 

May 27, 2021: KOG is long gone.

August 13, 2011: I updated the status of some wells below.

Original Post

InPlay: I think this link will break over time. Here are the high points:

• KOG negotiating to contract a fourth rig for delivery in 4Q11 (KOG has 2 rigs, currently)
• KOG executed a two-year agreement for dedicated frack crew 14 days/month
• KOG's area of mutual interest with XOM reiterated
• KOG records IP rate of 3,042: #19651, Koala 9-5-6-12H3, 22 stages, first well on the pad
• t4/11; cum 395K 3/21; needs to be re-fracked; cum 419K 11/24;
  
• KOG increased its borrowing from borrowing base from $50 million to $75 million; KOG has $200 million under this revolving line of credit facility

KOG's press release: interim operational update (if the link is broken, I am sure you can find it at KOG's website)

KOG's earnings results are scheduled for May 5, 2011.

Operations, Wildcats -- 2-well pad

• 19301, 2,526, Whiting/Koala 9-5-6-5H (KOG-operated, 95% working interest), middle Bakken, short lateral, 24 stages,  t4/11; cum 282K 5/17; cum 335K 3/21; cum 356K 11/24;
  
• 19651, 1,919, Whiting/Koala 9-5-6-12H3 (KOG-operated, 95% working interest), Three Forks, short lateral, 22 stages, t4/11; cum 317K 5/17; cum 395K 3/21; cum 419K 11/24;
• These two wells were "part of an on-going effort to evaluate communication between MB and TF formations"

Operations, Established Field, Mandaree oil field -- two 4-well pads

• 18517, 1,595, WPX/Whiting/KOG, Two Shields Butte 2-24-12-2H, t9/11; cum 468K 5/17; cum 593K 3/21; cum 632K 11/24;
  
• 19825, AB/2,698, Whiting/KOG, Skunk Creek 2-24-25-15H, t9/11; cum 475K 5/17; cum 564K 3/21; cum 594K 3/24;
• 19826, 2,845, WPX/Whiting/KOG, Two Shields Butte 2-24-12-1H3, t9/11; cum 431K 5/17; cum 528K 3/21; cum 584K 11/24;
  
• 19827, 515, WPX/Whiting/KOG, Skunk Creek 2-24-25-16H, t10/11; cum 273K 5/17; cum 349K 3/21; cum 394K 11/24;
  

In same section, farther west, an Orion belt:

• 18518, IA/2,736, WPX/Whiting/KOG, Two Shields Butte 3-24-12-4H, t4/14; cum 322K 5/17; cum 484 K 3/21; cum 496K 9/24;
  
• 20257, 2,475, WPX/Whiting/KOG, Two Shields Butte 3-24-12-3H, t4/14; cum 272K 5/17; cum 403K 3/21; cum 412K 11/24;
  
• 20258, 2,399, WPX/Whiting/KOG, Skunk Creek 3-24-25-13H, t4/14; cum 262K 5/17; cum 367K 3/21; cum 407K 11/24; recently off line; small jump in production after being off line 16 months or so;
  
• 20259, 1,579, WPX/Whiting/KOG, Skunk Creek 3-24-25-14H, t4/14; cum 139K 5/17; cum 233K 3/21; cum 273K 11/24;