CLR Surprises With A Pair Of Huge Wells Near The Canadian Border -- October 19, 2025

Locator: 49446B.

The sister wells on a two-well pad, coming off confidential list this next week: 

• 41823, conf, CLR, Kleist 4-35HSL, Upland, section line well:

Date	Oil Runs	MCF Sold
8-2025	41467	37273
7-2025	7404	7240

• 41622, conf, CLR, Kleist 3-35H, Upland, 

Date	Oil Runs	MCF Sold
8-2025	41075	38857
7-2025	10545	10988

According to AI:

Permits: 

Three-section / three-mile horizontals / laterals.

The maps:

A Three-Year-Old WPX Well Has Produced More Than 600K Bbls Crude Oil Cumulative -- October 12, 2023

Locator: 45752B.

At the time this well came off confidential list it was a DUC. Now, the update. The well, drilled three. years ago, has produced 630K bbls crude oil cumulative. See this note. This is among a group of 3-mile, super-long laterals.

• 37134, drl/NC-->F/A, WPX, Nokota 24-13-12HB, Squaw Creek, t--; cum 628K 8/23; still "F";
  

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	8-2023	31	4752	4684	5774	26484	26320	0
BAKKEN	7-2023	31	4514	4543	5505	21827	21662	1
BAKKEN	6-2023	20	3122	3149	4451	14913	14806	2
BAKKEN	5-2023	31	5088	5072	6156	24203	24037	4
BAKKEN	4-2023	30	4689	4646	5828	24774	24469	147
BAKKEN	3-2023	31	4857	4935	6363	27836	27608	65
BAKKEN	2-2023	28	5161	5162	6062	27356	27015	193
BAKKEN	1-2023	31	5754	5729	6727	29582	29266	153
BAKKEN	12-2022	31	6847	6790	8120	30987	30633	190
BAKKEN	11-2022	30	4342	4307	5483	20209	19184	923
BAKKEN	10-2022	31	6704	6752	7925	31052	30672	219
BAKKEN	9-2022	30	7478	7503	7911	32065	31635	273
BAKKEN	8-2022	31	8117	8163	8543	32848	32173	516
BAKKEN	7-2022	31	7236	7230	8005	28991	28604	236
BAKKEN	6-2022	30	9297	9229	9523	30922	30752	14
BAKKEN	5-2022	31	6524	6582	8201	19094	18982	0
BAKKEN	4-2022	30	8092	8019	8566	35608	35472	0
BAKKEN	3-2022	31	9483	9540	9316	35453	35297	0
BAKKEN	2-2022	28	9773	9638	9494	36362	36215	0
BAKKEN	1-2022	31	11408	11550	11054	38626	38464	0
BAKKEN	12-2021	31	13456	13411	15631	40504	36849	3493
BAKKEN	11-2021	30	7700	7924	7716	31929	31835	0
BAKKEN	10-2021	31	17008	16923	14632	53013	52851	0
BAKKEN	9-2021	30	16567	16489	13640	43622	34306	9175
BAKKEN	8-2021	31	14834	14910	15075	33554	29699	3711
BAKKEN	7-2021	31	13182	13185	11789	36622	36496	0
BAKKEN	6-2021	30	22109	22136	17568	52375	41828	8032
BAKKEN	5-2021	31	26142	26211	20108	61929	44087	14883
BAKKEN	4-2021	30	31921	31893	22168	53189	49621	0
BAKKEN	3-2021	31	41412	41373	26830	54582	49894	97
BAKKEN	2-2021	24	30537	30454	20670	40248	32166	4696
BAKKEN	1-2021	29	39777	39846	31805	52426	35692	12333
BAKKEN	12-2020	31	70137	69948	48429	92442	65453	19322
BAKKEN	11-2020	30	80474	80740	58188	106063	60245	37051
BAKKEN	10-2020	13	69136	68691	47438	91121	44375	39282

About Those Overlapping 3840-Acre Spacing Units -- February 24, 2023

In case you missed it, the big story in the NDIC hearing dockets for March, 2023: all the 3840-acre spacing units, and there were a lot of them. I finally got tired of listing all the sections in those 3840-acre spacing cases, but if go back and look at those 3840-acre units you will see what's going on.

Anyone want to guess why 3840?

Hint: they are 2x3 units -- two sections by three sections. Six sections x 640 acres/section = 3840 acres.

See the map at this post, as an example. 

Oasis will site six wells at one of the "top three sections" and will site six wells at one end of the "bottom three sections. It's unlikely they will site the twelve wells in the middle of the river, so six wells will be sited in section 25 and six wells will be sited in section 36. The horizontals will be drilled east-to-west, with the horizontals (at least for the northern horizontals) being mostly under water.

But the big thing is this: we're going to start seeing a lot more extended long laterals; three-mile long laterals; three-section laterals. It will be interesting to track their completions (# of stages, amount of water; amount of proppant; number of days to reach total depth; and so on). 

There is an existing tag for extended long laterals.

Another Look At Kraken Wells In Burg Oil Field -- January 2, 2023

Readers need to take another look at this post from December 28, 2022 -- last Friday. 

I completely missed it. A reader caught it and pointed it out to me this evening.

I missed it; my bad. I am getting too complacent; not lazy, I'm working as hard as ever, but I am getting complacent. I should not have missed this. Wells in this area are not generally this good.

So, what's going on? As the reader said me, I'm "comparing apples to oranges."

#38509 is an extra-long (or extended long) lateral -- instead of the usual two-section (two-mile, or 20,000-foot horizontal) it a three-section (three-mile, 26,000-foot horizontal (TD). 

So, it's a third longer than the "usual" Bakken well, and that explains the great production in this part of North Dakota, well north of Williston.

The well:

• 38509, F/A, Kraken, Jenna 4-33-28 3H, Burg, t--; cum 257K 11/22; 240K x $70 = $17 million at the wellhead:

There are four wells on this pad; three run north; one runs south. All four are extended-length laterals.

The other three:

• 38510, F/A, Kraken, Jenna LE 4-33-28 1TFH, Burg, t--; cum 180K 11/22;
  38511, F/A, Kraken, Alamo 3-24-27 2H, Burg, t--; cum 201K 11/22;
  38558, F/A, Kraken, Maddie LW 10-15-22 1H, Burg, t--; cum 167K 11/22;
  38512, PNC,
  

By the way, the nomenclature:

• 38509, Jenna 4-33-28 3H -- although sited in (the far northeast corner of section 9) the horizontal is perforated in all of sections 4, 33, and 28 (running north);
• 38510, Jenna LE 4-38-28 -- this is a section line well, the horizontal perforated in sections 4, 33, and 28; running north; as a section line well, the number of sections affected is double. So, in this case this well is spaced for six sections.
• 38558, this is a section line well (on the west side); the horizontal perforated in sections 10, 15, and 22; running south; as a section line well, the number of sections affected is double. So, in this case this well is spaced for six sections.

I looked at data for one frack.

• #38509: 15.3 million lbs of proppant, and 90 stages.
  

The reader thinks Kraken will drill a number of super-extended laterals; the reader counts at least ten such locations in this area. 

So, if one sees a 1920-acre standup or 1920-acre laydown spacing unit, one needs to think of the possibility of a three-section (extended long or super-long) lateral.

A huge thanks to the reader for catching this. 

Again, I'm embarrassed I didn't catch this. 

Lynn Helms said he expected to see a lot of 3-section horizontals. He almost sounded like it might become the norm where operators have the ability to put together three-section drilling units.

Update On Whiting's Expansion Plans In The Bakken -- February 9, 2022

Link here. Huge thanks to the reader who sent me the graphic and the article.

This deal was previously but more details were published in this article.

The article begins:  

Whiting Petroleum Corp. has two agreements in hand to expand its operated leasehold in the Bakken Shale, and it has raised its capital budget for 2022. 

More:

The assets span 14,563 net acres and should contribute about 4,500 boe/d net production (67% oil), the company said. The smaller transaction closed in late 2021 and the larger one is slated to close by the end of March.

The assets include 32 net undrilled locations, which Whiting plans to develop in the “near term,” management said.

Whiting also announced capital expenditure guidance of $360-400 million for 2022. 

The company plans to have two drilling rigs and one completions crew operating in the Williston for most of the year. The rigs would operate in North Dakota’s Mountrail, McKenzie and Williams counties.

“While the company has had success with three-mile laterals in its Sanish field, Whiting plans to drill additional three-mile laterals further west in McKenzie County, North Dakota during the year, which will help improve economics on additional inventory,” management said. “As oil prices have rebounded, the company is seeing increased non-operated activity from other operators and expects this trend to continue.”

Whiting expects production to average 91,000-95,000 boe/d for the year, including 52,000-55,000 b/d of oil output.

“The 2022 budget was designed with higher working interests and slightly greater activity,” management said. Whiting “encountered a delay on a five-well pad in January that will impact the timing of production until later in the year.”

Management said even though it “has shifted operations to the Sanish field, the company’s continued focus on sustainability through increasing its high gas capture percentage will result in production volumes not entirely replacing those lost by the delay.” The firm noted that low double-digit inflation has been built into its projections for the year.

EOG With First Permits In The Bakken So Far In Calendar Year 2021 -- May 25, 2021

These are the first EOG permits so far in calendar year 2021 in the Bakken.

One has to ask why? 

Note the chronologic numbers (in purple). We talked about this years ago during the early days of the boom. 

LR = "long reach"; longer than the standard two-section horizontal; generally three sections; although a couple may go 3.5 sections so as not to leave orphaned oil behind;

Two new permits, #38324 - #38325, inclusive:

• Operator: EOG
• Field: Parshall (Mountrail)
• Comments: EOG has permits for two Liberty LR wells, both sited in NENW 23-151-91
• one will be sited 750' FNL and 2380 FWL; Liberty LR 119-2320H, 3.5-mile-lateral
  
• the other will be sited 700' FNL and 2380 ' FWL; Liberty LR 56-2317H, 3.5-mile-lateral; section line well;
  

Currently sited in that section:

• 19720, 510, EOG, Liberty LR 14-23H, Parshall, t4/11; cum 310K 3/21;

• 30593, loc, EOG, Liberty LR 29-2321H, Parshall, 3.0-mile-lateral;
• 30594, loc, EOG, Liberty LR 108-2321H, Parshall, 3.0-mile-lateral;
• 30595, loc, EOG, Liberty LR 30-2321H, Parshall, 3.0-mile-lateral;

• 19721, 1,063, EOG, Liberty LR 19-23H, Parshall, t3/11; cum 404K 3/21; 3.0-mile-lateral;
• 18971, 894, EOG, Liberty LR 09-23H, Parshall, t9/10; cum 258K 3/21; spacing: E2 (half section) (320 acres)
  

The graphics;

***************************
Summer Fun

Nice To See -- SHD's Golden Well In Deep Water Creek Is Back On Line -- November 1, 2020

The well:

• 19296, 2,388, SHD Oil & Gas, Golden 22-31H, Deep Water Creek Bay, 62 stages, 15 million lbs sand, spacing ICO, F, t3/15; cum 782K 9/20; a singleton; still producing 5,000 bbls 11/19; only fourteen days, 4/20; remains off line 8/20; back on line for 5 days, 9/20; this is an extended long lateral (3 sections; almost three miles long); it's the only well from that pad; under the water; recent production:
  

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	9-2020	5	860	709	1497	350	19	331
BAKKEN	8-2020	0	0	0	0	0	0	0
BAKKEN	7-2020	0	0	0	0	0	0	0
BAKKEN	6-2020	0	0	0	0	0	0	0
BAKKEN	5-2020	0	0	0	0	0	0	0
BAKKEN	4-2020	14	1822	1786	2410	1050	0	1050
BAKKEN	3-2020	27	3852	4037	6241	2732	0	2732
BAKKEN	2-2020	29	5427	5554	7085	3888	0	3888
BAKKEN	1-2020	27	3678	3493	4300	2706	0	2706
BAKKEN	12-2019	31	5120	5424	5585	3484	0	3484
BAKKEN	11-2019	28	4387	4404	6069	2564	0	2101
BAKKEN	10-2019	31	6557	6414	12482	3348	0	3348
BAKKEN	9-2019	28	5658	5507	8070	4905	0	4905
BAKKEN	8-2019	31	7204	7037	9177	565	0	565
BAKKEN	7-2019	31	6956	7812	10668	6075	0	6075

WPX Nokota Wells In Squaw Creek

The wells:

• 37135, drl/NC-->drl/A, , WPX, Nokota 24-13-12HX, Three Forks, Squaw Creek, no production data, 
  
• 37133, drl/A, WPX, Nokota 24-13-12HA, Squaw Creek, no production data,
  
• 37134, drl/A, WPX, Nokota 24-13-12HB, Squaw Creek, no production data,
• 37328, drl/A, WPX, Nokota 24-13-12HQ, Squaw Creek, no production data,
• the well to watch:
• 21217, IA/686, WPX, Linseth 13-12HW, Squaw Creek, t9/12; cum 142K 7/20; off line 8/20; four wells alongside this well that will be fracked;
  

Comments:

• #37135:
• spud, April 12, 2020; completed to MD of 26,498' on June 8, 2020. The target stipulated by WPX geologist was 15' below the top of the Three Forks. 
• 5.6 miles west of Mandaree in Dunn County
• curve section began and started on April 16, 2020
• 14' thick target, 15' below the top of the Three Forks formation
•  target: first bench Three Forks B (unit 6 facies  Y)

Five other wells in this immediate area to watch: these are extended long laterals, three-sections long, running from the south to the north:

• 36819, drl/A, WPX, Omaha Woman 24-13-12HY, Squaw Creek, no production data,
• 36820, drl/A, WPX, Omaha Woman 24-13-12HC, Squaw Creek, no production data,
• 36864, drl/A, WPX, Omaha Woman 24-13-12HD, Squaw Creek, no production data,
• 36821, drl/A, WPX, Omaha Woman 24-13-12HZ, Squaw Creek, no production data,
• 37309, drl/A, WPX, Omaha Woman 24-13-12HIL, a section line well, Squaw Creek, no production data,

Why I Love To Blog, Reason #1 -- Now I Know What All The Excitement Was About -- Updating Nine Point Energy' Wells In Eightmile -- May 30, 2020

This is really, really cool, on so many levels. I actually missed this story for several days, maybe weeks, but with time on my hands today, I decided to take a look. 

At the sidebar at the right, there is an app that posts the top ten trending posts. Most top trending posts are recent posts, but when an "old" post rises to the top, it's time to take a look.

See this post. The original post was January 28, 2020. At that time, the most recent production data was for the month 11/19. At that time all completed wells were producing.

It is strange to see a post this old to be trending among the top ten. So, let's take a look.

Well, well, well. What do we see? The producing wells at the time of the original post are now all off line; and, the wells that were on "drl" status are now producing and have moved to the conf list. And finally the wells that were producing a small amount back in November, 2019, are now into full production.

So, now we know. The mom-and-pop mineral rights owners were checking into see what was going on. They must have received their royalty checks. Whoo-hoo!

There are so many story lines here:

• first, of course, the royalty checks for small mineral owners;
• second, once the price oil "comes back," the checks will be bigger;
• third, this opens up an entire new area for E&P;
• fourth, hopefully Nine Point Energy can hang through this downturn; they've been through this once before;  
• fifth, the tenacity, the persistence, the git 'er done attitude of oil men and women; and, 
• probably a lot more.

By the way,  a huge apology for failing to get this posted. I completely missed it. I'm sure a lot of mineral owners were upset with my delay in getting this posted. I learned a lesson.

The wells:

• 34783, 1,004, Nine Point Energy, Missouri 152-103-4-2-1H, Eightmile, t11/18; cum 190K 11/19; a 24K month; now, 221K 3/20; only seven days 3/20; remains off line 4/20;
  
• 34784, 1,098, Nine Point Energy, Missouri 152-103-4-2-2H, Eightmile, t11/18; cum 207K 11/19; a 30K month; off line 11/19; remains off line 4/20;
  
• 34785, 1,083, Nine Point Energy, Missouri 152-103-4-2-3H, Eightmile, t11/18; cum 241K 11/19; a 24K month; off line 11/19; remains off line 4/20;

• 34786, drl-->conf, Nine Point Energy, Missouri 152-103-4-2-4H, Eightmile, 

  Date	Oil Runs	MCF Sold
  4-2020	11917	2886
  3-2020	739	0

• 34787, drl-->conf, Nine Point Energy, Missouri 152-103-4-2-5H, Eightmile,
  

  Date	Oil Runs	MCF Sold
  4-2020	16907	6850
  3-2020	697	466

• 34788, drl, drl-->conf, Nine Point Energy, Missouri 152-103-4-2-6H, Eightmile,

  Date	Oil Runs	MCF Sold
  4-2020	16535	7390
  3-2020	35	13

• 36157, 895, Nine Point Energy, S Missouri 152-103-9-11-12H, Eightmile, t12/19; cum 105K 4/20;
  
  

  Date	Oil Runs	MCF Sold
  3-2020	17389	0
  2-2020	15701	0
  1-2020	26216	0
  12-2019	30245	0
  11-2019	19	0



• 36156, 1,018, Nine Point Energy, S Missouri 152-103-9-11-11H, 80 stages; 13 million lbs; some ceramic; proposed 1600 acres (sections 10, 11 &E2/9-152-103); TD = 24,263 feet; lateral drilled in 64 hours; length of lateral, 12,840 feet; curve, 820 feet drilled in 13 hours; vertical (big rig), 1,700 feet drilled in 17 hours; gas: averaged 1,233 units in the lateral; maxed out at 7,013 units; Eightmile, t12/19; cum 106K 4/20;
  
  

  Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
  BAKKEN	3-2020	31	23032	22538	61899	25306	0	25306
  BAKKEN	2-2020	24	10121	10304	32366	11323	0	11323
  BAKKEN	1-2020	31	20653	20661	60923	15769	0	15769
  BAKKEN	12-2019	30	25642	25921	76274	26702	0	26702
  BAKKEN	11-2019	9	7582	6950	48719	2373	0	2373



• 36155, 983, Nine Point Energy, S Missouri 152-103-9-11-110H, 80 stages; 13 million lbs; some ceramic; proposed 1600 acres (sections 10, 11 &E2/9-152-103); TD = 24,263 feet; Eightmile, t11/19; cum 118K 4/20;
  
  

  Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
  BAKKEN	3-2020	28	19982	19612	55898	26359	0	26359
  BAKKEN	2-2020	27	12408	12512	36613	13415	0	13415
  BAKKEN	1-2020	31	18163	18253	56928	24050	0	24050
  BAKKEN	12-2019	31	28579	29697	72341	32286	0	32286
  BAKKEN	11-2019	24	18117	16605	58555	11698	0	11698

• 37259, drl, Nine Point Energy, S Missouri 152-103-4-11-9H, Eightmile,
• 37258, rig-on-site (January, 2020)-->drl, Nine Point Energy, S Missouri 152-103-4-11-8H, Eightmile, 

The graphics:

June 10, 2020:

May 30, 2020:

 

The Enerplus Patriot Pad Wells Have Been Updated -- May 18, 2020

Production data for the Enerplus Patriot pad wells has been updated several times. I finally got my act together on this pad. The production data and the wells will be updated at this post.

These are extended long laterals, or super-long laterals or 3-section laterals, whatever one wants to call them. These are incredibly good wells. One is approaching 700,000 bbls of oil, cumulative since 2014.

Note: three of the four wells are 3-section laterals; one of the four is a standard two-section lateral. Based on cumulative production, one can guess as to the standard two-section lateral.

What's Going On Out In Eightmile? Nine Point Energy Active -- January 28, 2020

Updates

September 21, 2020:

• 34788, drl/A, Nine Point Energy, Missouri 152-103-4-2-6H, Eightmile, no production data,
• 34787, drl/A, Nine Point Energy, Missouri 152-103-4-2-5H, Eightmile, no production data,
• 34786, drl/A, Nine Point Energy, Missouri 152-103-4-2-2H, Eightmile, producing, 54K over 4.5 months; see this post;
  

May 30, 2020: these wells have been updated here; at a later date this post will be updated but I want folks to see what this looked like back in November, and compare to that to the update at the link. Updated graphic:

Original Post

Eightmile oil field is southwest of Williston, heading out toward Montana, north of the river. I would consider this immediate area Tier 2, maybe Tier 3, based on historic activity. But all of a sudden, a bit of activity.

The wells:

• 34783, 1,004, Nine Point Energy, Missouri 152-103-4-2-1H, Eightmile, t11/18; cum 221K 3/20; a 24K month; off line 3/20; remains off line 4/20;
• 34784, 1,098, Nine Point Energy, Missouri 152-103-4-2-2H, Eightmile, t11/18; cum 207K 11/19; a 30K month; off line 11/19; remains off line 4/20;
• 34785, 1,083, Nine Point Energy, Missouri 152-103-4-2-3H, Eightmile, t11/18; cum 242K 11/19; a 24K month; off line 11/19; remains off line 4/20;
  

• 34786, drl, Nine Point Energy, Missouri 152-103-4-2-4H, Eightmile,

  Date	Oil Runs	MCF Sold
  4-2020	11917	2886
  3-2020	739	0

• 34787, drl, Nine Point Energy, Missouri 152-103-4-2-5H, Eightmile,

  Date	Oil Runs	MCF Sold
  4-2020	16907	6850
  3-2020	697	466

• 34788, drl, Nine Point Energy, Missouri 152-103-4-2-6H, Eightmile,

  Date	Oil Runs	MCF Sold
  4-2020	16535	7390
  3-2020	35	13

• 36157, 895, Nine Point Energy, S Missouri 152-103-9-11-12H, Eightmile, t12/19; cum 105K 4/20;
• 36156, 1,018, Nine Point Energy, S Missouri 152-103-9-11-11H, Eightmile, producing, 7K in first report; unknown number of days; t12/19; cum 106K 4/20;
• 36155, 983, Nine Point Energy, S Missouri 152-103-9-11-110H, Eightmile, producing, 17K in first report; unknown number of days; t11/19; cum 118K 4/20;

• 37259, drl, Nine Point Energy, S Missouri 152-103-9-11-9H, Eightmile,
• 37258, rig-on-site (January, 2020), Nine Point Energy, S Missouri 152-103-9-11-8H, Eightmile,

Graphics:

Might These Be Extended Long Laterals? -- November 30, 2019

I'm getting ahead of my headlights.

This may be inaccurate.

If this important to you, go to the source; don't rely on this note.

This is based on the map and four wells on confidential status. Because these four wells are on confidential status, I do not for sure where the horizontals will run but based on several data points, it appears these four wells will be extended long laterals running north. These wells will come off the confidential list January 9, 2020.

The wells:

• 36010, conf, Kraken, Bigfoot 23-11 LW 1H, Sanish:

Date	Oil Runs	MCF Sold
9-2019	35341	11001
8-2019	1619	310
7-2019	6335	13

• 36011, conf, Kraken, Bigfoot 23-11 2TFH, Sanish:

Date	Oil Runs	MCF Sold
9-2019	28045	8235
8-2019	7432	4005
7-2019	6861	14

• 36012, conf, Kraken, Bigfoot 23-11 3H, Sanish:

Date	Oil Runs	MCF Sold
9-2019	53702	18345
8-2019	48099	27591
7-2019	21239	43

• 36013, conf, Kraken, Bigfoot 23-11 4TFH, Sanish:

Date	Oil Runs	MCF Sold
9-2019	40460	13596
8-2019	36750	21478
7-2019	14784	30

The graphic:

In addition, section 23-153-92, the sourthernmost section of the 3-section drilling unit, is also a 640-acre drilling unit with three producing wells (short laterals, of course), and Kraken is asking to put a fourth 640-acre well in that section (December, 2019, dockets, case #28175.

Those wells, all short laterals:

• 16935, 780, Kraken, Frandson 11-23H, Sanish, t6/08; cum 195K 9/19;

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	9-2019	13	1030	732	1743	1187	0	1121
BAKKEN	8-2019	0	0	0	0	0	0	0
BAKKEN	7-2019	0	0	0	0	0	0	0
BAKKEN	6-2019	0	0	0	0	0	0	0
BAKKEN	5-2019	4	253	274	70	291	54	216
BAKKEN	4-2019	27	575	724	242	663	346	152

• 22563, 704, Kraken, Hukkanen 11-23H, Sanish, t6/012; cum 155K 9/19;

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	9-2019	14	1466	669	1273	1777	0	1705
BAKKEN	8-2019	1	162	237	0	196	0	196
BAKKEN	7-2019	0	0	0	0	0	0	0
BAKKEN	6-2019	0	0	0	0	0	0	0
BAKKEN	5-2019	1	48	0	5	59	25	28
BAKKEN	4-2019	27	623	748	195	755	463	127
BAKKEN	3-2019	31	688	708	185	893	676	0

• 22853, 687, Kraken, Isaac 11-23H, Sanish, t7/012; cum 134K 9/19;

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	9-2019	8	207	0	1323	216	0	177
BAKKEN	8-2019	0	0	0	0	0	0	0
BAKKEN	7-2019	1	500	469	18	521	0	517
BAKKEN	6-2019	0	0	0	0	0	0	0
BAKKEN	5-2019	1	35	0	5	37	26	5
BAKKEN	4-2019	28	613	534	260	639	294	177