Odds And Ends Around The Bakken -- November 26, 2021

Nine Point takes this well off line:

• 24546, IA/485, Nine Point Energy/Triangle Petroleum, Dwyer 150-101-35-26-1H, Rawson, t5/13; cum 42K 8/13; cum 184K 7/21; goes off line 7/21; neighboring wells on same pad are also being taken off line: #26231 and #26230;

Is EOG taking this well off line?

• 21406, 1,355, EOG, Liberty 25-0107H, Parshall, t4/13; cum 469K 10/20; cum 493K 9/21; recent production:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	9-2021	11	807	722	840	1710	1589	0
BAKKEN	8-2021	31	3000	3000	2296	4953	4577	0
BAKKEN	7-2021	21	1736	1679	1653	2931	2682	0
BAKKEN	6-2021	28	1135	1168	1127	2344	2004	0
BAKKEN	5-2021	31	1671	1665	1379	3332	2956	0

This is a lousy well. Does CLR have something in mind for this well?

• 24935, 216, CLR, Tangsrud 7-1H3, Hayland, t10/13; cum 48K 9/19; cum 51K 9/21;

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	9-2021	7	154	197	1310	419	332	4
BAKKEN	8-2021	21	458	390	558	899	661	7
BAKKEN	7-2021	1	28	38	4	19	7	0
BAKKEN	6-2021	14	80	114	79	297	134	1
BAKKEN	5-2021	25	153	126	34	545	255	9
BAKKEN	4-2021	30	137	124	3	738	430	1

Coming off line for a reason? The well:

• 24981, 2,559, BR, CCU Four Aces 44-21TFH, Corral Creek, t11/13; cum 235K 9/19; cum 260K 92/1; 
  

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	9-2021	2	96	95	214	95	71	23
BAKKEN	8-2021	3	88	156	62	95	94	0
BAKKEN	7-2021	31	1671	1646	1309	1610	1242	359
BAKKEN	6-2021	30	1675	1688	1329	1808	1607	192
BAKKEN	5-2021	31	1425	1393	1712	1490	1348	136

A Closer Look At A String Of Kraken TFH Wells In The Sanish --June 3, 2020

Many years ago, Lynn Helms opined that all things being equal, Three Forks wells might be better than middle Bakken wells.

Up until now, 90% of the Sanish oil field wells were middle Bakken wells. New permits suggest operators are moving toward half-and-half: new permits in Tier 1 areas are half middle Bakken, and half Three Forks wells.

I don't believe I have ever posted a multi-well pad with all TFH wells. If not, here is the first example:

The wells:

• 36757, 794, Kraken Arrow A 15-22 4TFH, 60 stages, 15.3 million lbs; Sanish, t12/19; cum 108K 4/20; 
• 36756, 732, Kraken Ethan 15-22 3TFH, Sanish, t12/19; cum 82K 4/20;
• 36755, 1,531, Kraken, Penny 15-22 2TFH, Sanish, t12/19; cum 97K 3420;
• 36754, 1,322, Kraken, Candace 15-22 1TFH, Sanish, t12/19; cum 97K 4/20;

Production:

36757, 60 stages, 15.3 million lbs:

Pool	Date	Days	BBLS Oil	Runs	BBLS Water	MCF Prod	MCF Sold	Vent/Flare
BAKKEN	4-2020	30	43308	43395	55496	0	0	0
BAKKEN	3-2020	31	43282	43171	88510	42200	16508	25321
BAKKEN	2-2020	2	786	786	6985	825	794	7
BAKKEN	1-2020	0	0	0	0	0	0	0
BAKKEN	12-2019	31	20877	20687	39475	15303	5473	9396

From the file report (#36767):

• a ten-foot target between 20' and 30' below the top of the Three forks 
• a "toe-down, three-string, double section lateral"
• the build took a bit longer than usual due to a mud motor failure; no big deal;
• the lateral portion: from the evening of October 4, 2019, to TD, early morning, just after midnight, October 8, 2019, without incident (about 3.5 days)
• gas: 
• upper Bakken shale: 1842 units
• middle Bakken: 413 units
• lower Bakken: 2006 units
• Three Forks: 1334 units
• sections 15/22-154-92

From the NDIC map, the wells go to the south, intersecting the following, producing wells:
In same drilling unit:

• 16953, Kraken, Fladeland, off line;
• 22855, Kraken, Kathy, off line;
• 21525, Kraken, Helen, off line;
• 18302, Kraken, Fladeland, off line;
• 21001, Kraken, Debbie, off line;
• 17102, Kraken, Fladeland, off line;
• 21318, Kraken, Lance, has just returned to production; 28 days in 4/20: 1051 bbls; in line;
• 28841, Kraken, Lance, has just returned to production; 30 days in 4/20: 925 bbls; in line;
• 28842, Kraken, Danae TTT, has just returned to production; 21 days in 4/20; in line;
• 28843, Kraken, Dakota TTT, has just returned to production; 30 days in 4/20; 1255 bbls; in line;

parallel, to the east:

• 24994, Whiting, Carkuff; off line 8/19; remains off line 4/20;

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.

Random Comparison Of A Middle Bakken Well Paired With A Three Forks 2nd Bench Well -- July 4, 2018

Disclaimer: in a note like with a lot of numbers, and done quickly, and not triple-checked, there are likely to be factual and typographical errors. Feel free to fact check and comment.

Except for frack data, this page will not be updated. The Hess EN-VP and R- wells are tracked here.

Note: the USGS survey of the Bakken/Three Forks reported in 2013, did not take into account the lower benches of the Three Forks; the USGS had limited data from the upper bench of the Three Forks at that time; the USGS is re-assessing the Bakken/Three Forks; anticipated date of release of that survey: 2019.

This is a nice comparison of a middle Bakken well and a Three Forks 2nd bench side-by-side by a veteran driller in the Williston Basin:

July 3, 2018: DUCs reported as completed:

• 33731, 1,631, Hess, EN-VP and R-154-94-2536H-11, Alkali Creek, Three Forks 2nd bench, TVD = 10,903 feet; spud date, January 2, 2018; cease drilling, January 13, 2018,  API - 33-061-04084, fracked 4/13/18 - 4/18/18, 6.4 million lbs water; 86.7% water, 12.9% sand; and 4/18/18 - 4/23/18, 6.75 million gallons, 87.1% water; 12.49% sand;  t5/18; cum --
• 33732, 2,078, EN-VP and R-154-94-2536H-12, middle Bakken, TVD = 10,727 feet, spud date, January 16, 2018; cease drilling, January 25, 2018, Alkali Creek; API 33-061-04085, fracked 4/9/18 - 4/13/18; 5.7 million gallons of water; 84.8% water; 14.9% sand, t5/18; cum -- 

The frack data is from FracFocus. There were two separate fracks for #33731, but only one reported by Frack Focus for #33732 (I double-checked FracFocus). Once the NDIC reports the frack data, we will know more.

The above may be a bit difficult to decipher, so here is it again.

#33732:

• a middle Bakken well
• from spud to total depth: January 16, 2018, to January 25, 2018; about 9 days; it looks like they started drilling this one before its neighbor reached TD (see below)
• TVD = 10,727 feet
• fracked, 4/9/18 - 4/13/18
• 5.7 million gallons of water (a relatively small frack; a typical frack in the middle Bakken these days is 10 million gallons of water for a long lateral)
• water: 84.8% by weight
• sand: 14.9% by weight

#33731:

• a Three Forks second bench well
• from spud to total depth: January 2, 2018, to January 13, 2018; about about 11 days
• TVD = 10,903 feet -- 176 feet deeper than the middle Bakken well
• fracked
• 4/13/18 - 4/18/18
• 6.4 million gallons water
• water: 86.7% by weight
• sand: 12.9% by weight
• 4/18/18 - 4/23/18
• 6.75 million gallons of water 
• water: 87.1% by weight
• sand: 12.49% by weight
• total of the two fracks
• 13.15 million gallons of water (a relatively large frack; a typical frack in the middle Bakken these days is 10 million gallons of water for a long lateral; not enough data to comment about average amount of water for a Three Forks, 2nd bench well)

Other wells in the graphic:

• 33730: 2,056;  t4/18; middle Bakken; 9 days to TD; 60 stages; 8.3 million lbs, large, medium
• 33729: 1,506, t5/18; Three Forks 2nd bench, 13 days to TD;  60 stages; 8 million lbs; large, medium

• 28916, 1,230, t3/15; middle Bakken; 35 stages; 3.5 million lbs; large, small; drilling rig, October 20, 2014; cease drilling, December, 2014; bump in production;
• 28915, 1,194, t3/15; Three Forks NOS, 35 stages; 3.5 million lbs; large, small; drilling rig, November 17, 2014; cease drilling, December 18, 2018
• 28914, 1,647, t3/15; middle Bakken; 35 stages; 3.5 million lbs; large, small; drilling rig, November 9, 2014; cease drilling, December 8, 2014; 
• 28913, 1,711, t2/15; Three Forks NOS, 35 stages; 3.5 million lbs; large, small; drilling rig, November 17, 2014; cease drilling, December 1, 2014; 

• 31283, 1,421, t11/16; middle Bakken; 53 stages; 3.7 million lbs; large, small; off-line as of 1/18; drilling rig, August 20, 2016; cease drilling, August 31, 2016; 
• 31282, 1,346, t11/16; Three Forks NOS; off-line as of 3/18; 57 stages, 3.9 million lbs; large, small; drilling rig, August 1, 2016; cease drilling, August 16, 2016; 
• 31281, 746, t11/16; middle Bakken; 57 stages; 4 million lbs; large, small; off-line as of 4/18; drilling rig, July 20, 2016; cease drilling, July 29, 2016;
• 31280, 1,612, t10/16; Three Forks NOS,  53 stages; 3.7 million lbs; large, medium; nice jump in production after off-line for less than one month (4/18); spud date, July 7, 2016; cease drilling, July 16, 2016

Reminder: NDGS Has An Update On Three Forks, Second Bench -- February 11, 2018

A reader recently sent a short comment regarding the Three Forks, second bench. Just a reminder: Geo News has an update of the second bench in the January, 2018, issue. See this link.

You can download the semi-annual (January, July) newsletter at this link.

Also this reminder: Vern Whitten's most recent Bakken portfolio is at this link; it is now among the top ten visited posts at the present time.

I Wonder Why, Dion and the Belmonts

Geologic Update Of The Three Forks -- January 25, 2018

For newbies: I'm starting to see more and more Three Forks first bench wells being reported, but still the mix is probably about 90% middle Bakken wells/production and 10% Three Forks first bench 9%. The other 1%: second and third bench.

Also for newbies, previously posted, September 26, 2013; these would be upper Three Forks/first bench wells: Three Forks wells in northeastern McKenzie County five times better than middle Bakken wells -- Lynn Helms.

There is a fourth bench, according to the commercial oil industry, but apparently the academic community sees three benches in the Three Forks, calling the second bench, the middle Three Forks. Or more likely, the lower Three Forks will be comprised of the 3rd and 4th benches.

The middle Bakken is book-ended by the upper Bakken and the lower Bakken, neither of which are significant oil producers, but rather the source rock for the producing payzones.

On the other hand, the Three Forks has four benches: the first bench, fairly well demarcated and a definite payzone; a second bench, now referred to by the academic community as as the middle Three Forks; and a third bench and fourth bench, of which relatively little is known.

That is preamble for this. DMR.ND.GOV has a link to a study of the middle Three Forks, the second bench. It will download as a pdf.  The article is written by Tiothy O. Neshieim. Data points (and this will get quite long):

Part I:

• the study area was pretty much centered between Watford City and Stanley
• wells #26990 and #22388 were in the center of the study area
• oil saturations were typically 25 - 50%; extending from the Bakken down through the base of the middle Three Forks (2nd bench)
• beginning in 2012, various operators began testing the middle to lower portions of the Three Forks formation (2nd, 3rd, and 4th benches)
• the prospective Three Forks reservoir horizons were informally subdivided into four benches, numbered 1 to 4 in descending order
• prior to 2012, most drilling was focused on the middle Bakken
• beginning in early 2015, the NDIC began tracking Three Forks wells
• since then, 180 wells have been drilled and completed in the middle to lower Three Forks formation;  the middle to lower Three Forks have cumulatively produced nearly 20 million bbls of oil ot date (this does not include the upper Three Forks, the 1st bench, which may be more prolific than the middle Bakken in some areas of North Dakota)
• the majority of those middle to lower Three Forks wells targeted the middle Three Forks (2nd bench) -- again, note, we are talking about the middle to lower Three Forks formation, not the first bench which is often referred to as the upper Three Forks
• a significant number of additional, pre-2015 middle to lower Three Forks horizontal wells are also present, but status and cumulative production volumes have yet to bet determined
• currently there is limited geological information available regarding the middle to lower Three Forks
• resource assessments of the Three Forks have ranged from 2 to 4 billion bbls of recoverable oil, but these assessments have been limited to the upper Three Forks [by the way, 2 to 4 billion bbls as an estimate of recoverable oil is so conservative as to be laughable]
• this study reports the preliminary findings of a recently initiated study on the origin and distribution of oil saturations within the middle Three Forks
• the author also examines oil saturations and hydrocarbon production in thee lower Three Forks (3rd and 4th benches)
• hydrocarbons present with the Three Forks are believed to be sourced from the overlying lower Bakken shale, which is considered to be a world class petroleum source rock

Part II:

• the second bench is the middle Three Forks, author
• contains similar rock types to the prolific upper Three Forks (1st bench)

Part III:

• middle Three Forks (2nd bench) oil saturations
• 50+ wells studied
• the middle Three Forks can be further divided into three areas based on oil sats and water sats
• 1st tier area, highest oil saturations: northeastern McKenzie to southeastern Dunn and southwestern Mountrail counties; almost identical to the upper Three Forks, the 1st bench
• a larger 2nd tier: lesser oil sats but still significant
• 3rd tier: water sats increase; oil sats decrease to less than 10%
• 1st tier: correlates with where the lower Bakken shale exists; 20' thick; has reached the greatest level of thermal maturity with respect to oil generation
• 2nd tier: correlates with thinner lower Bakken shale; less thermally mature, but still with the peak oil generation window
• oil saturations of the middle Three Forks appear to be primarily a function of thickness and thermal maturity of the lower Bakken shale
• wells drilled in middle Three Forks to date have mostly been in Tier 1 areas

From the article:

 

How Charts Can Be Confusing Or Misleading -- September 19, 2016

Be sure to note the y-axis in these two graphs, taken from Richard Zeits' article over at SeekingAlpha today:

********************************* 
Emmy Ratings Flirt With All-Time Low Audience

Link here. It doesn't help when the event becomes a political fundraiser for Hillary Clinton, though I doubt that had much effect on overall viewership.

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

A Note For The Granddaughters

Astrophysics 101 In The Year 2020
The Nine Numbers of the Cosmos
Michael Rowan-Robinson
c. 1999
DDS 523.1 ROW 

This is kind of cool. I won't finish this note today; the reason will become obvious.

Michael Rowan-Robinson's The Nine Numbers of the Cosmos was published in 1999. Rowan-Robinson focused on nine numbers which he thought were "the major aspects our knowledge of the observable universe. [He was] only trying to characterize what we know about the large-scale universe. Even if all the quantities discussed in this book were known with immense precision, we would still not be able to predict the details of how stars and planets form, how life arises, or what is in your fridge."

In the last chapter the author then summarizes his estimates for each of the nine numbers and tries to predict how accurately they will be known in 2015. It will be interesting to see how close he came.

Today, just the nine numbers and his predictions. At a later day, I will see how close he came.

1. The density of baryonic matter (_b): 0.03 ± 0.006, a 20% accuracy
2. The anisotropy of the universe, ΔT/T: 1 part in 100,000, to n accuracy of 25%
3. The Hubble constant, H₀: 65 km s⁻¹ Mpc⁻¹, with an uncertainty of 12%
4. The age of the universe, t0: 12 billion years with a total uncertainty of 2 billion years either way, a 20% reduction from the value of 15 billion years which was believed only a few years ago
5. The temperature of the microwave background, T0: 2.728 degrees Kelvin to an accuracy of 0.1%
6. The density of cold dark matter, (_cdm): enormous uncertainty; currently in the range of 0 - 0.97; currently favored values are in the range of 0.2 - 0.4, and values lower than 0.1 seem unlikely; in 2015, the author says we should  know _cdm and _tot  to an accuracy of 1%
7. The tilt, the string tension, or the density of hot dark matter, _cdm: currently believed to be about 0.2. The recent discovery of muon neutrino oscillations tells us the value is greater than or equal to about 0.001
8. The cosmological constant, Λ: currently another largely unknown number, lying anywhere in the range of 0. to 0.7
9. The star formation history of the universe, Q, the ratio of the age of the universe to the exponential timescale; currently, the value is in the range of 3 - 6; the author expects that by 2015, we will know this function to an accuracy of 20%

Our granddaughters will likely be able to "skip" years of uncertainty with regard to these values, and begin Physics 101 in college -- their freshman year -- with very accurate numbers for these constants, allowing them to move more quickly in physics than my colleagues were able.

Over the course of the next few days, I will post current values for these nine numbers of the cosmos and see how far we've come in 15 years.

Random Update of CLR's Development of the Three Forks Formation in The Killdeer Area: Provided By a Reader; Did Stimulating a New Well Increase Production at a Neighboring Well?

A reader sent the following information in as a comment. Some folks don't read the comments, but this is an excellent piece of work and needs broader reader exposure, so I am re-posting it here.

One of the reasons it has been difficult to follow development of the Three Forks is because the names of the well may not indicate it is a Three Forks well, though that seems to be changing. (Whiting does a great job with the "TF" and "PH" designation, for example.) The next challenge will be identifying 2nd, 3rd, and 4th benches of the Three Forks. I don't know if CLR's goal to re-define the stratigraphic limits of the Bakken Pool will get to that degree of granularity; if it did, the information might show up in the file reports. Otherwise, our only recourse may be the corporate presentations. 

The following: Continental's effort to develop the TF in the Killdeer area. From west of Killdeer (Roadrunner) to the North Killdeer Mountains a swath about 4 or 5 miles wide the reader found 26 wells producing from the TF.


Continental Three Forks Well Production Through August 2012
From west of Killdeer to North Killdeer Mountains
File Number -- Name -- IP (bbls oil) -- Production Completion Date

• 16943 Bice 1-29H 516 121,257 5/9/2008
• 17153 Skachenko 1-31H 456 111,800 11/20/2008
• 17201 Mittlestadt 1-20H 956 165,118 11/2/2008
• 17211 Gale 1-32H 240 91,431 8/16/2008
• 17372 Dolezal 1-5H 426 95,762 8/27/2009
• 17398 Kukla 1-21H 603 247,500 5/18/2009
• 18351 Clover 1-3H 1,125 201,168 2/9/2010
• 17530 Hartman 1-28H 780 157,777 8/11/2010
• 18636 Bang 2-33T 633 106,078 4/26/2010
• 18796 Roadrunner 1-15H 761 155,030 8/13/2010
• 18859 Carson Peak 3-35H 680 274,945 4/10/2011
• 18860 Morris 2-26H 517 127,687 4/7/2011
• 19012 Bonneville 2-23H 365 82,290 12/5/2010
• 19013 Bridger 2-14H 399 97,680 12/4/2010
• 19020 Meadowlark 3-6H 744 60,921 4/24/2011
• 19023 Skachenko 2-31H 726 76,845 4/24/2011
• 19156 Brandvik 2-25H 282 162,272 10/1/2010
• 19968 Pletan 2-18H 757 107,378 7/18/2011
• 20208 Hawkinson 2-27H 960 166,619 9/7/2011
• 20212 Whitman 3-34H 482 64,165 9/6/2011
• 20547 Kukla 2-16H 744 45,108 3/8/2012
• 20548 Candee 2-29H 356 55,313 3/28/2012
• 20806 Dvirnak 2-7H 744 85,606 11/21/2011
• 20809 Pletan 4-18H 1,294 65,939 11/18/2011
• 21583 Roadrunner 3-15H 1,087 20,140 6/26/2012
• 21584 Clover 3-10H 1,081 39,139 6/26/2012

Total: 2,984,970 bbls.

Just short of 3 million barrels.

On a side note go to the Mittlestat 1-20H (17201) well file and you can see that for 7 months prior to June the well did not exceed 2,000 barrels per month. 30 days in June 1,771. Then,  wow: 31 days in July 12,548; then 31 days in August 6,997.

No indication of any down time for clean out or refrac therefore the only thing it appears to me going on the area was the completion of the (21569) Mittlestat 2-20H which comes off confidential this week. Somehow the frac job from the second well must have stimulated the first well. Without plugging it from migrating sand.

I am now curious to see if the second well might be a lower bench TF well. Across the gravel road to the south is the Bice 1-29H and the 2-29H. The second Bice well was drilled into the MB and maybe had some impact on production from the first but I don't think very much, not 6- or 7-fold. It was shut down during the completion and frac of Bice 2 to do some testing for communication between formations.