Specific Gravity -- Bakken 101 -- With Apologies To Wille Nelson -- July 15, 2023

Locator: 45143WILLIENELSON
Locator: 45143B.
Locator: 45143SG.
Locator: 45143API

For Willie Nelson's bus:

The specific gravity of Three Forks Second Bench oil in the Antelope-Sanish is: 0.82.289.

The specific gravity of diesel is between 0.82 and 0.88.

Without further ado:

This Is Another Second Bench Three Forks Well -- April 27, 2021

Record IPs in the Bakken: tracked here.

The Daniel USA well is on the MRO Chauncy-Winona pad and is tracked here.

The well:

• 36221, drl/A, MRO, Daniel USA 11-2TFH-2B, Sanish-Antelope, first production, 1/21; t--; cum 122K in less than two months; 33-053-08982; 84,000 bbls over 25 days extrapolates to 100,806 bbls of crude oil over 30 days, and, of course, there's a bit of natural gas, also.
  

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
SANISH	2-2021	26	37780	38063	20542	51002	48236	2646
SANISH	1-2021	25	84005	83278	50812	121157	91845	29058
SANISH	12-2020	2	188	184	426	1195	0	1185

The geologist's report is yet to be scanned in. Spacing unit: 1280 acres. 

FracFocus:

• fracked 11/22/20 - 12/2/20;
• 8 million gallons of water;
• 52.7% fresh water by mass;
• 30.9% produced water by mass;

Oops! MRO Does It Again! Record IPs -- March 23, 2021

Locator: 23000MRO.

Record IPs at this site. 

Updates

Later, 10:45 p.m. CT: with regard to these staggering numbers, a reader who follows this very closely, wrote:

I just noticed that the top of that MRO TF well was almost 12,000 feet down. 

A few things to consider going forward ...

How thick is this targeted horizon? (Well reports/geologists usually describe the zone's thickness). 

Most likely no additional casing will need to be run, but if depths start to approach 13,000 feet (third/fourth benches?), then higher pressures might necessitate the 'telescoping' of casing. 

This would pose significant additional cost.

The higher formation pressures (found at deeper depths) usually greatly boost overall recoveries of the hydrocarbons. 

This would validate Lynn Helms' long ago statement that the Three Forks production may ultimately surpass that of the Bakken.

Fracturing the rock in the TF must be substantially different than frac'ing  the middle Bakken. 

It would be reasonable to speculate that the operators - now, apparently being led by MRO and CLR - would have held back in pursuing the deeper TF benches as the learning curve would understandably be somewhat financially daunting.

All in all, as these deeper TF wells come online with high production profiles, increasing activity should emerge from other operators.

 Original Post

Re-posting. Look at these incredible initial production numbers. 

The wells:

• 37089, drl-->drl/NC-->5,502, MRO, Jonah USA 11-2H, first production, 1/21; t1/21; cum 53K 1/21; 53K over 17 days extrapolates to 93,500 bbls over 30 days; cum 399K 5/23;
  
• 36221, drl/NC-->6,420, MRO, Daniel USA 11-2TFH-2B, 33-053-08982, Antelope, first production, 1/21; t1/21; cum 84K 1/21; initial production, 84K over 25 days extrapolates to 100,800 bbls crude oil over 30 days; fracked 11/22/20 - 12/2/20; 8 million gallons of water; 52% fresh water by mass; 30% produced water by mass; 437K 5/23;
  
• 36222, drl-->drl/NC-->7,0083, MRO, Morsette USA11-2H, first production, 1/21; t1/21; cum 58K 1/21; cum 370K 5/23;
  
• 36223, drl-->drl/NC-->7,146, MRO, Sherman USA 21-2TFH, first production, 1/21; t12/20; cum 84K 1/21; cum 440K 5/23;
  
• 36224, drl-->drl/NC-->12/20, MRO, Valarie USA 21-2H, first production, 12/20; t--; cum 91K 1/21; cum 346K 5/23;
  
• 33412, 6,509, MRO, Winona USA 21-2TFH-2B, t4/18; cum 583K 12/20; Three Forks B2; 45 stages; 10 million lbs, 73,742 bbls + 100,353 mcf (16,722 boe) = 90,465 bod in less than four months; off line 3/20; back on line 8/20; nice return to production; off line 1/21; cum 716K 5/23;
  
• 33413, 8,475, MRO, Chauncey USA 31-2H, Antelope-Sanish, t3/18; cum 478K 10/20; back on line 8/20; production okay; off line 11/20; remains off line 1/21; cum 534K 5/23;
  
• 33414, 5,524, MRO, Wilbur USA 31-2TFH, Antelope-Sanish, t4/18; cum 427K 10/20; did not come off line; but then off line 11/20; remains off line 1/21; cum 491K 5/23;
  
• 33415, 7,572, MRO, June USA 31-2H, Antelope-Sanish, t3/18; cum 564K 10/20; did not come off line; but then came off line 11/20; remains off line 1/21; cum 654K 5/23;
  
• 33416, 4,892, MRO, Miles USA 41-2TFH-2B, Antelope-Sanish, t4/18; cum 364K 10/20; did not come off line; but then came off line 11/20; remains off line 1/21; cum 417K 5/23;
  

One example of initial production:

• 36221:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
SANISH	1-2021	25	84005	83278	50812	121157	91845	29058
SANISH	12-2020	2	188	184	426	1195	0	1185

The XTO Bobcat Federal Wells, Bear Creek

The Bobcat Federal wells are tracked here. 

 The wells:

• 34356, 1,305, XTO, Bobcat Federal 14X-35A, Bear Creek, t6/19; cum 470K 6/20; F; for early production: link here; 
• 34358, 30 (no typo), XTO, Bobcat Federal 14X-35EXH, Bear Creek, 60 stages, 12.0 million lbs, t5/19; cum 413K 6/20; for early production: link here;

Look at those numbers.

Drilled/completed/tested in May / June of 2019.

A year later: almost 500 million bbls. 

It should be noted that these wells are "extended" long laterals -- three sections long -- which, explains, to some extent, the large amount of water, but, still, a huge amount of water. 

From a reader:

When you first posted the numbers of the XTO wells on August 22, I was struck by several numbers, especially the amount of frac water pumped (830,000 bbls and 585,000 barrels) as well as the exceptionally  long 'flowback/produced water' time frame and amounts recovered.

While I will immediately  follow with a somewhat clumsy, detailed explanation of what XTO has accomplished with these two completions, suffice to say that XTO has developed a way to pump VAST amounts of high pressure fluid underground in a CONTROLLED fashion.

Furthermore, the chemistry of these new fluids/water allows extended underground retention without damaging the formation.  

(In years past, fluid imbibing (softening) of the rock and/or leaving a production-inhibiting coating/skin necessitated a relatively quick removal of the frac fluid in the weeks immediately  following the fracturing). 

This extended period - several months - of maintaining the induced water underground enables the higher hydraulic pressure to push more oil into the wellbore.

Will follow up with explanation of the significance of effectively pumping ~35 million gallons underground.

Seven wells on that pad:

• 34355, 176, XTO, Bobcat Federal 14X-35E2, Bear Creek, t4/19; cum 169K 7/20;
  
• 34356, above,
• 34357, 10 (no typo), XTO, Bobcat Federal 14X-35AXB, Bear Creek, t5/19; cum 318K 7/20;
• 34358, above,
• 34559, 83, XTO, Bobcat Federal 11X-2F2-S, Bear Creek, t5/19; cum 108K 7/20; 20 stages; 4 million lbs; Three Forks 2;
  
• 34359, 456, XTO, Bobcat Federal 11X-2A-S, Bear Creek, t4/19; cum 84K 7/20; middle Bakken; 20 stages; 6 million lbs proppant;
  
• 34360, 83, XTO, Bobcat Federal 11X-2E-S, Bear Creek, t5/19; cum 45K 7/20; Three Forks, 20 stages, 4 million lbs;

*******************************************
Movie Night
Sunset Boulevard.

Middle Bakken: Great; First Bench: Better; Second Bench: Best -- March 21, 2020

These three wells were drilled from the same pad by the same company: the deepest well, a Three Forks 2nd bench well, about two months older; used significantly less proppant (14 million lbs vs 21 million lbs) and has produced twice the amount of oil as the middle Bakken well; and almost 60% more than the Three Forks first bench well.

Months of production/BOE cumulative

• 35108, Three Forks first bench: about 7.75 months; 297,332 boe; best month: 36,639 bo
  
• 35080, middle Bakken: exactly 7 months; 243,608 boe; best month: 40,993 bo;
  
• 35081, Three Forks, second bench, 9.5 months; 464,916 boe; best month: 69,314 bo;
  

Disclaimer: in long notes like these, there will be content and typographical errors. If this is important to you, go to the source. 

These three three-lateral Carson Peak wells on this pad swing north to capture most of section 26, and then swing south through section 35, and then terminate near the south line of section 2. 

These are the three Carson Peak wells. Note: the typical length of a "standard" Bakken well is 19,000 - 21,000 (maybe, 22,000) feet. The Morris wells, for example that swing north from this pad measure about 19,000 feet MD.

Note the depths on these wells. The vertical depths (TVDs) vary by less than 40 - 100 feet between middle Bakken wells and Three Forks wells in general across the Bakken. The intervening shale seams are 10 - 30 feet thick; the targeted seams are about 40 feet thick.

Depths:

• 35080, 2,076, CLR, Carson Peak 7-35H, middle Bakken, Oakdale, t6/19; cum 207K; TD: 25,248 feet; 
• 35108, 1,824, CLR, Carson Peak 6-35H1, Three Forks 1st bench, Oakdale, t5/19; cum 252K; TD: 26,152 feet; 
• 35081, 3,556, CLR, Carson Peak 6-35H2, Three Forks 2nd bench, Oakdale, t5/19; cum 398K; TD: 25,320 feet;

Frack data:

• 35080, middle Bakken: 53 stages; 20.62 million lbs
• 35018, Three Forks, 1st bench: 54 stages; 20.67 million lbs;
• 35081, Three Forks, 2nd bench: 52 stages; 14.21 million lbs;

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

Production Profile Of Selected Wells

The wells:

• 35081
• Note: Three Forks second bench
• Note: the relatively small amount of water returned compared to the huge amount of oil returned.
• Note: 44K over 15 days extrapolates to 88K over one 30-day month.
• Frack: 52 stages; 14.2 million lbs
• Notes from the file report below the production profile:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	1-2020	31	23032	23092	7788	24143	22847	1115
BAKKEN	12-2019	31	26059	26081	9732	28697	26872	1531
BAKKEN	11-2019	30	27355	27329	10179	28958	24346	4290
BAKKEN	10-2019	31	30614	30589	11237	26902	14596	11993
BAKKEN	9-2019	30	28746	28769	11167	29551	23283	5952
BAKKEN	8-2019	31	40595	40627	15962	40748	33763	6632
BAKKEN	7-2019	31	55133	55135	22459	54834	47377	7043
BAKKEN	6-2019	30	50686	50838	22437	46191	34900	10757
BAKKEN	5-2019	31	69314	69374	33087	74737	66074	7832
BAKKEN	4-2019	15	44172	43755	17281	47768	41933	5379
BAKKEN	3-2019	0	0	0	0	0	0	0
BAKKEN	2-2019	0	0	0	0	0	0	0
BAKKEN	1-2019	5	1896	1896	3138	1424	0	1424

From the file report:

• target: Three Forks, second bench
• Oakdale/Rocket play 
• spud: September 9, 2018
• TD: October 17, 2018
• TD: a very deep, 25,320 feet (typical Bakken wells, 19,000 to 22,000 feet)
• almost a true three section lateral; two full sections and 75% or so of the first section where the well is sited;
• drilling operations began on September 9, 2018; H&P 535;
• geological services began September 11, 2018, at 9,060 feet;
• vertical operations completed with one planned trip and another for the curve assembly
• KOP: 10,929';
• curve drilled with a single drilling assembly; kicked off late on the morning of September 12, 2018,
• note about the Bakken shale collapse issues in this region - previously posted; shallow entrance/exit angle; no collapse issues;
• drilled out of the shoe on October 12, 2018
• lateral: completed in three runs;
• gas readings varied widely; 
• gas buster brought on line at 12,056' MD after gas readings spiked to nearly 3,000 units
• again, just after after 15,500' MD, readings often exceeded 3,000 units
• at 21,500' MD, gas began building again; 3,500 - 4,000 units; faded to around 2,500 - 3,000 units through the last 1,300'  of the well;
• depths:
• upper Bakken shale: 11,224' TVD
• middle Bakken member: 11,238' TVD (forty feet seam)
• lower Bakken member: 11,278' TVD
• Three Forks formation top: 11,295' TVD (first bench -- 43 feet seam)
• internal 1 shale top of the Three Forks: 11,338' TVD (15 feet of shale)
• Three Forks second bench: 11,353' 
• ideal target: 15.5' thick; began 6.5' below the internal 1 shale base, extended 22' below the same reference point;

Based on limited data, just as the CDC bases coronavirus case fatality rates on limited data, suggests the second bench Three Forks is going to be twice as good as the middle Bakken, and upwards of 60% better than the first bench.

There Won't Be Any More -- Nothing About The Bakken -- YouTube Fugue -- June 19, 2019

Okay, not quite true.

I said "nothing about the Bakken" in the subject line. But here's a Bakken note.

The XTO Bobcat Federal wells are tracked here. They are still SI/NC (DUCs) but some older wells in the immediate area that were taken off line are now coming back on line suggesting that perhaps the Bobcat Federal wells have been fracked. There is nothing at FracFocus yet. But it gave me a chance to look at this well:

• 34355, SI/NC, XTO, Bobcat Federal 14X-35E2, 33-025-03404, Bear Creek. This is a Three Forks, second bench well, extended reach (3-section);

From the file report:

• depths:
• upper Bakken shale penetrated at 10,996' TVD  (shale seam: 16' thick)
• middle Bakken penetrated at  11,012' TVD (middle Bakken dolomite: 37' thick)
• lower Bakken shale penetrated at 11,049' TVD  (shale seam: 19' thick) 
• Three Forks, first bench, penetrated at 11,068' TVD (dolomite: 39' thick)
• Three Forks, second bench, penetrated at 11,107' TVD 
• description:
• the uppermost section of the second bench is composed of brown shale, tan to light brown shaly dolomite and slighly pink dolomite, which is often referred to as the "Chocolate Shale" 
• below the "Chocolate Shale / Dolomite" making up the upper third of the second bench, the target zone is composed of light gray-brown to pink, to very light brown dolomite interbedded with multicolored dark gray to blue-gray, to rare green-gry argillaceous dolomite
• porosity / geology:
• the best porosity and associated oil staining was observed in a 4' dolomite in the upper half of the target zone approx 2' to 6' high of target center
• structure maps predicted the formation would stay flat
• results:
• the resultant target exposure was approx 80% within the target zone
• the target up-dip was 0.03 degrees, with formation rising 7' over roughly 15,618' MD
• total depth: 26,945 feet
• gas units:
• highest gas show: 1,190 units
• average gas: 175 units
• the lower amounts in gas readings is likely the result of tight porosity and distance from the Bakken source, resulting in gas taking long to infiltrate into the open wellbore
• drilling:
• spud date: March 11, 2018
• re-entry date: May 27, 2018
• TD: June 13, 2018

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

The Concert Page

I can count on one hand the number of "big-name" concerts I've attended. The golden age of concerts, at least for me, was in the 1960s and 1970's: Liberace (Vegas); Charlie Rich (southern California); Bob Dylan (San Antonio) -- that was about it. The price of tickets has definitely spoiled the opportunity. Live entertainment -- from Hamilton to Garth Brooks is now for the elite.

I remember going to the Greek Theater, Griffith Park, Los Angeles, on perhaps more than one occasion, but I don't remember the "act."

The best concerts were at the Hostfest in Minot: Charlie Pride; Myron Floren; Williams & Ree; the Ringling 5; Willie Nelson; others I've long forgotten. All "free."

I've seen more musicals in London than concerts in the US. A huge shout-out to the US Air Force for sending us to Europe for thirteen continuous years; four of those years were near London. Then later I returned to northern England for multiple deployments over several years. I never did see The Rocky Horror Picture Show. But I digress.

I was reminded of these things early this morning (see YouTube Fugue): After midnight I start with a random song on YouTube.com which leads me to another and then another. Later, sometimes hours later, I end up somewhere not knowing how I got there. Often I am in a fugue state. I am sure I am not alone.

This morning, shortly after midnight, up popped Charlie Rich:

There Won't Be Any More, Charlie Rich

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

On Another Note

I used to enjoy YouTube more but the constant interruption of ads destroys the "mood," for lack of a better word. It breaks the non-drug induced fugue state.

Now, it's Alexa. I love Alexa. Truly amazing. Free, except for the initial $25 outlay or whatever is now for the donut-sized / donut-shaped Echo. For $8 / month, literally every song available.

XTO Soon To Frack The Bobcat Federal Wells In Bear Creek -- February 12, 2019

The Bobcat Federal Wells

 

The parent well, link here, with full produciton:

• 18294, 341, XTO, Werre Trust 44X-34H, Bear Creek, t3/10; cum 582K 5/20; cum 661K 2/23;

The wells:

• 34360, 83, XTO, Bobcat Federal 11X-2E-S, Bear Creek, t5/19; cum 94K 4/21; cum 113K 10/21;
  
• 34359, 456, XTO, Bobcat Federal 11X-2A-S, Bear Creek, t5/19; cum 137K 4/21; cum 154K 10/21;
  
• 34358, 30 (sic), XTO, Bobcat Federal 14X-35EXH, Bear Creek, t5/19; cum 413K 6/20; cum 567K 5/21; cum 611K 10/21;
  
• 34357, 10, XTO, Bobcat Federal 14X-35AXB, Bear Creek, t5/19; cum 513K 4/21; cum 596K 10/21;
  
• 34356, 1,305, XTO, Bobcat Federal 14X-35A, Bear Creek, t6/19; cum 470K 6/20; cum 631K 5/21; 672K 10/21;
  
• 34355, 176, XTO, Bobcat Federal 14X-35E2, Bear Creek, t4/19; cum 253K 4/21; cum 285K 10/21;
  

Production Profiles:

• 34356:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	2-2021	27	10856	10823	11892	27026	17671	9302
BAKKEN	1-2021	31	15339	15256	16935	31172	19552	11563
BAKKEN	12-2020	20	8997	8954	11981	15219	8886	6304
BAKKEN	11-2020	21	11251	11397	12288	32941	16846	16033
BAKKEN	10-2020	29	16185	16542	17621	32139	24474	7574
BAKKEN	9-2020	30	18789	18517	20426	42468	35122	7243
BAKKEN	8-2020	31	22212	22229	22789	53821	50971	2763
BAKKEN	7-2020	31	23716	23674	22565	49581	48152	1360
BAKKEN	6-2020	30	22313	22329	20590	40445	39882	506
BAKKEN	5-2020	31	33876	33639	26381	58630	57241	1308
BAKKEN	4-2020	15	15486	15579	14393	22704	22031	636
BAKKEN	3-2020	31	23359	23519	21742	32622	32562	0
BAKKEN	2-2020	29	27465	27659	27062	37700	35749	1880
BAKKEN	1-2020	31	30916	30700	29218	43080	42087	902
BAKKEN	12-2019	31	36427	36767	33162	49116	48798	235
BAKKEN	11-2019	30	37908	38138	37200	51225	46198	4924
BAKKEN	10-2019	31	39754	40181	42565	53412	52750	471
BAKKEN	9-2019	30	47937	47842	41474	62276	62089	0
BAKKEN	8-2019	31	61872	61998	70491	91824	90462	1166
BAKKEN	7-2019	31	69550	70075	61117	92325	26911	65371
BAKKEN	6-2019	13	22011	20641	15944	33308	19243	14043

Updates

September 26, 2020: update here with comment from reader.

September 2, 2019: This is one well in in the immediate area that has just returned to production:

• 18112, 442, XTO, Porcupine Ridge 14-35H, Bear Creek, t4/10; cum 269K 3/20; 285K 10/21;

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	6-2019	30	2145	1954	8140	3261	1449	1627
BAKKEN	5-2019	31	4159	4163	12431	6322	2374	3763
BAKKEN	4-2019	7	1007	824	4747	1530	0	1493
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	0	0	0	0	0	0	0
BAKKEN	7-2018	29	1222	1361	865	1900	1309	414
BAKKEN	6-2018	30	1274	1371	1003	2003	1419	399

June 19, 2019: it was noted that some wells in the immediate area are starting to come back on line suggesting that the Bobcat Federal wells have been completed? Nothing at FracFocus yet, so maybe not, but we'll keep watching.

This is one well in in the immediate area that has just returned to production:

• 18112, 442, XTO, Porcupine Ridge 14-35H, Bear Creek, t4/10; cum 269K 3/20;

Recent production:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	4-2019	7	1007	824	4747	1530	0	1493
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	0	0	0	0	0	0	0
BAKKEN	7-2018	29	1247	1386	865	1925	1309	439
BAKKEN	6-2018	30	1295	1392	1003	2032	1419	428
BAKKEN	5-2018	30	1455	1394	1134	2261	1520	556

If that 1,007 bbls over 7 days can be extrapolated over 30 days, it's going to be quite a well. 

Original Post 

The XTO Bobcat Federal wells are in the process of being fracked (or will soon be fracked):

• 34355, 176, XTO, Bobcat Federal 14X-35AXB, Bear Creek;  33-025-03404, t4/19; cum 169K 7/20;
• 34356, 1,305, XTO, Bobcat Federal 14X-35A, Bear Creek;  33-025-03405, t6/19; cum 470K 6/20; F; see this post;
  
• 34357, 10 (no typo), XTO, Bobcat Federal ...;  33-025-03406, t5/19; cum 180K 3/20;
• 34358, 30 (no typo), XTO, Bobcat Federal 14X-35EXH, Bear Creek,  33-025-03407, 60 stages; 12.0 million lbs; t5/19; cum 413K 6/20; see this post;
• 34559, 83 (no typo), XTO, Bobcat Federal 11X-2F2-S; Three Forks second bench;   33-025-03444, t5/19; cum 46K 9/19; 20 stages; 6 million lbs;
  
• 34359, 456, XTO, Bobcat Federal 11X-2A-S;  33-025-03408, t5/19; cum 84K 7/20; middle Bakken; 20 stages; 6 million lbs proppants;
• 34360, 83, XTO, Bobcat Federal 11X-2E-S, Bear Creek, t5/19; cum 45K 7/20; Three Forks, 20 stages, 4 million lbs;
  

All neighboring wells have been taken off line-- they have been off-line for about six months.

The graphic:

Another Nice Example Of The Life-Cycle Of A Bakken Well -- Slawson's Jughead #17864 -- September 25, 2018

The well:

• 17864, 1,255, Slawson, Jughead 1-26H, Big Bend, t6/10; cum 315K 8/17; 

Production after 8/17:

BAKKEN	4-2018	30	4480	3990	3263	4058	2807	627
BAKKEN	3-2018	26	3552	3885	3557	2683	180	2000
BAKKEN	2-2018	28	4662	4598	5554	3541	0	2896
BAKKEN	1-2018	25	5109	4865	10564	3876	0	3213
BAKKEN	12-2017	12	1282	1532	869	1365	1163	6
BAKKEN	11-2017	30	3149	3000	2009	2920	2355	78
BAKKEN	10-2017	31	3313	3605	3129	2823	1857	458
BAKKEN	9-2017	30	2210	1572	4267	1954	1436	127

Production prior to 8/16, just before coming off-line for about year; not re-fracked:

BAKKEN	8-2016	10	1115	1294	264	1028	978	0
BAKKEN	7-2016	28	2444	2353	719	2041	1901	0
BAKKEN	6-2016	30	597	792	201	601	409	42
BAKKEN	5-2016	31	469	225	106	512	321	36
BAKKEN	4-2016	30	447	495	119	487	312	25
BAKKEN	3-2016	31	507	558	108	410	255	0
BAKKEN	2-2016	29	358	227	69	337	192	0

Neighboring well was fracked/completed/tested: 2/17 --; note the jump in production a year later, 8/18 --

• 30235, 439, Slawson, Jugard Federal 5-26-35TFH, t2/17; cum 248K 8/18

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	8-2018	31	24191	24342	26025	21593	17463	1324
BAKKEN	7-2018	31	26028	26024	20954	20864	4576	13277
BAKKEN	6-2018	30	26776	26839	20124	21090	0	18009
BAKKEN	5-2018	31	29786	29609	27544	23479	0	20061
BAKKEN	4-2018	30	28716	28440	23478	22573	21	19266
BAKKEN	3-2018	26	21047	21214	26644	17677	12354	2905

Two neighboring wells from the south, note the geologic targets:

• 33949, 74 (no typo), Slawson, Jugard Federal 4-35-26TFH, Big Bend, t1/18; cum 94K 8/18;
• 33948, conf, Slawson, Jugard Federal 10-35-36TF2H,