Sunday, November 17, 2019

On Track For About 1,500 New Oil And Gas Permits For North Dakota For CY19-- November 17, 2019

As of November 16, 2019, it is projected that there will be a total of about 1,466 new oil and gas permits for North Dakota (99% Bakken permits) for calendar year 2019 based on current permit activity. With permitting possibly slowing down over the holidays, final tally may be around 1,450.

Permit activity for 2019 are tracked here.

************************************
North Dakota Budget

This is "old" news -- reported back in August, 2019, but I can't remember if I posted the data.

Here it is, from this site. Data points:
  • North Dakota's 2017 - 2019 budget cycle ended June 30, 2019
  • revenues collected was 5.4% ahead of its general fund revenue forecast
  • general fund exceeded the March, 2019, legislative revenue forecast by nearly $250 million
  • "largely thanks to a larger-than-expected transfer of Legacy Fund earnings and more robust collections of sales and income taxes"
  • more than $455 million in Legacy Fund earnings were transferred to the state's general fund in July, 2019
  • previously reported: state representatives are asking the public how to spend all this money
I suspect November, 2019, Legacy Fund deposits will be reported this next week. Link here.

*********************************
Life on Earth

I get a kick out of the space probes looking for water. It's pretty much universally agreed that life requires water. Period. Dot.

Earth has water. Big deal.

What's impressive is how much water it has. No one ever seems to mention that. Scientists would be thrilled to find an ounce of water on Mars to prove life could exist there (or did exist there). And yet, no one ever mentions how much water there is on earth in these kinds of discussions.

Just saying.

This Could Be The Top Non-Energy Story Coming Out Of The Bakken This Next Week -- November 17, 2019

This might just be the top non-energy story coming of the Bakken this next week. This is really, really cool.

You have to have lived, worked, or traveled through Williston some years ago to really know how big this story is.

First of all, you need to know where the "old" Williston Pizza Hut was located and how big it was.

Now, imagine a "small" coffee shop moving into that huge location. I think that building is bigger than any Starbucks I have been in except for the two-story Starbucks on Harvard Square, Cambridge, MA. I could be way wrong; I have lousy feeling for estimating areas of restaurants. Nonetheless, a big location for a coffee shop.

From The Williston Herald:
After months of hard work, one of Williston’s favorite coffee shops has finally opened up their newest location, taking over the former Pizza Hut location.

Voted Best Coffee Shop for 2019’s Best of the Bakken Awards, Meg-A-Latte opened its doors opened at 5 a.m. on Friday, Nov. 15 at the new location, which showcases a bevy of new features, including an expanded menu, drive-thru and more space for patrons to sit and enjoy their signature beverages.

Much more at the link.

But then look at this:
One of the aspects customers seemed to be enjoying most, aside from the coffee and snacks, was the coffee shop’s loft area, a second-floor sitting area reminiscent of a rustic living room, where patrons can sit and gaze out the windows along Million Dollar Way
What about her "old location"? Wow this woman never quits:
Wold said that store will soon be undergoing its own remodel as Lounge 33, a 21 and over wine, beer and espresso lounge. Wold said she hopes to have Lounge 33 open by Christmas.
Facebook site here. Note her employees.

Trip Advisor: ranked #5 among 61 restaurants.

The graphic:


Kyle Busch Wins His Second Consecutive NASCAR Championship -- November 17, 2019

A good clean race.

17089 -- How They Do Things In The Bakken -- November 17, 2019

Note: in a long note like this there will be typographical and factual errors. Opinions are interspersed with facts; sometimes it may be hard to separate opinions from facts. This is mostly for my benefit; for the fun of it. If this important to you, go to the source. 

Take a look at this well from the operator's perspective. The CLR Bridger wells, as a rule, are really good wells. But for one some reason, one of the Bridger wells, #17089, was really a lousy well. Look at the full production profile. From the very beginning (2008) it was a lousy well and by 2015 it was a really, really lousy well. What to do? The Bridger wells should be better wells.

Then this.

The operator plans on drilling/fracking/completing new wells in the area in 2017. Why not re-enter #17089, a lousy well, prior to drilling/fracking those new wells. Take it off line for a year (let a little pressure build up) and then re-frack this well with a huge frack at the same time as the newer wells in the are are drilled/fracked/completed.

That may or may not be correct, but that's how I see it. If so, it means these operators are living/breathing this stuff. Thinking all the time how to drill wells; where to drill them; how to go back and get a good well out of a lousy well; etc.

A lousy well drilled back in 2008; then re-entered in 2016; a huge re-frack in 2017, along with neighboring wells:
  • 17089, 400, CLR, Bridger 44-14H, Rattlesnake Point, t4/08; cum 378K 9/19;
Production period of interest:
BAKKEN11-20173016622169011990719639196390
BAKKEN10-20173122673219041694124616227151901
BAKKEN9-20172718302184651558919122161962926
BAKKEN8-20173127510274882742728501217386763
BAKKEN7-20175210220478371178851093
BAKKEN6-2017151923013063170317
BAKKEN5-20170000000
BAKKEN4-20170000000
BAKKEN3-20170000000
BAKKEN2-20170000000
BAKKEN1-20170000000
BAKKEN12-20160000000
BAKKEN11-20160000000
BAKKEN10-20160000000
BAKKEN9-20160000000
BAKKEN8-20160000000
BAKKEN7-201663356448743366367
BAKKEN6-2016302106222060225321592373

Let's look at the file report.
  • This was a re-entry well. Re-entered in 2016. Off line for a year Re-fracked, according to FracFocus: 4/28/17 - 5/19/17. New test date: 8/10/2017.
  • Re-frack: 40 stages; 14.3 million lbs -- a huge re-frack
  • IP after that re-entry / re-frack: 1,344
  • but look at this:
    • "spud date": September 17, 2016
    • cease drilling: September 19, 2016
    • the big rig was on site for two full days? that's why I'm seeing
  • the narrative -- I have never seen a shorter narrative; less than one page long
  • introduction:
    • a horizontal re-entry well targeting the middle Bakken
    • "spud" (actually re-entered) on September 17, 2016; H&P 640 rig
    • drilling was completed September 19, 2016
    • mudlogging and geological services began on September 18, 2016, in the lateral re-entry section at 20,845' measured depth in the middle Bakken
    • TD: 21,158' MD in the middle Bakken formation 
  • lateral #1 (re-entry, 11,560' MD to 21,433'MD
    • started drilling ahead in the re-entry middle Bakken lateral at a MD of 20,845' on September 18, 2016, at 9:44 p.m. CDT
    • gas ranged from 1400 to 2100 units with connection gases reaching 3192 units
    • TD at 21,158' MD on September 19, 2016
Original drilling / completing / testing back in 2008
  • TD = 20,831 feet
  • open hole frack: 1 million lbs sand
This old well / re-entry well (#17089) parallels #31847, right above that Three Forks, first bench well; on the map, the two wells almost look like one lateral in some places
  • 31847, 1,515, CLR, Bridger 9-14H1, Rattlesnake Point, t8/17; cum 211K 9/19; so fracked at the same as #17089 above was re-fracked; first full month for this Three Forks, first bench well: 33,264 bbls;

Bakken Well Production -- Historical Review -- November 17, 2019

From a study posted earlier this week:


This graphic is very, very interesting.

The "discovery" well that resulted in the Bakken boom was drilled in 2006. One can get a feeling for the "2006" wells at this post. From a 2010 post:
Then, in 2006, EOG opened the Bakken on the North Dakota side of the border with its discovery well in the Parshall oil field, the Parshall 1-36H, file number 16164. 
Around 2012, the Bakken was hitting its stride. Infrastructure/takeaway capacity barely able to keep up.

2014 - 2016: the Saudis opened their taps; flooded the world with crude oil; tried to "break" the US shale industry. 2015 was the midpoint of that debacle for the Saudis. "That which does not kill us, makes us stronger."

Increase in cumulative production between the "2006 wells" and the "2009 wells" was 105%. There were very few Bakken wells drilled in 2006. I have long forgotten, but by 2009, I think the EURs for Bakken wells was around 375,000 bbls.

Most striking was how little improvement there was between 2009 and 2012. I wonder if one goes back, one can correlate that with the price of oil? Were operators still rushing to drill at least one well in each drilling unit to hold leases by production?

The 38% increase in production of the "2015 wells" over the "2012 wells" was "normal" -- "normal" in that operators had learned a lot about the Bakken by now, both completion strategies and geology, and sweet spots. On the other hand, I think the 105% increase between 2006 and 2009 was simply an "anomaly."

From 2015 to 2017, all things being equal, I think one could argue that one would have seen some increase but certainly not an increase of 43%. The low price of WTI drove operators to improve production / well.

By the way, the periods covered were all three years (2009/2006; 2012/2009; and 2015/2012) with one exception. That 43% increase in production was done over a two-year period (2017/2015).

So, going forward, for wells completed (the "test date)" in 2019, the number to watch is 160,000 bbls of crude oil in 360 days. Below 160,000 bbls/year is below the 2017 curve; above 160,000 bbls of crude oil in one year is above the 2017 curve. Another metric to track.

The big question: how soon will operators run out of Tier 1 locations? How are Tier 1 locations defined? Perhaps by the "160,000 bbls" number?

Off The Net For Awhile -- November 17, 2019

Most important Bakken posts so far this morning:
**************************
For The Granddaughters

How did the Cape of Good Hope get its name?

Boa Esperan├ža in Portuguese.

boa = good

esperan├ža = hope

From various sources:
In 1421 the Far East was cut off from western Europe, literally overnight.

First, in December, 1421, the overland route to China and the Spice Islands -- the great Silk Road running from China right across central Asia to the Middle East -- had been blocked when the Ottomans surrounded Byzantium. In that same climactic month, on 6 December, the Mamluk Sultan Barsbey seized power in Egypt and nationalized the space trade.

The effect of the two events was to ruin the merchants who had controlled the spice trade, seal Egypt's borders to international trade and sever the sea route through the Bosphorus to the western end of the Silk Road.

With the canal linking the Red Sea and the Nile (completed in the tenth century) collapsing and unusable, all land and sea routes to the East were now closed to Christians.

A new ocean route to the East had to be found.

When the "forefront of Arika" was discovered and successfully rounded, the Pope said there was "good hope" that a new sea route to the East had been found. 
So, there you have it. The Cape of Good Hope.

For extra credit, what is the southernmost point of Africa?
Cape Agulhas, the "Cape of Needles." About the year 1500, it was noted that the direction of magnetic north (and therefore the compass needle) coincided with true north in this region.
Cape Agulhas, the southernmost point of Africa, is about 90 miles east-southeast of the Cape of Good Hope.

And finally, the name of the two currents that "meet" and turn from each other at Cape Agulhas: the warm-water Agulhas current from the east, and the cold water Benguela current from the Atlantic. The oceanic meeting fluctuates between the two capes. 

Shifting The Focus To Optimized Production -- November 17, 2019

Beginning with the abstract sent to me by a reader I did a google search for relevant articles hoping to learn a bit more about drilling locations and completion strategies in the Bakken.

Springer, September 23, 2019: growth drivers of Bakken oil well productivity. The full article currently available. One may want to archive it before it disappears. Wow, wow, wow -- a light bulb goes off -- it comes down to technology and geology. The former is dynamic, the latter is static. Let's look at geology. In all the articles I have read, this seems to be the progression:
  • the oldest articles compared basins around the world -- akin to macroeconomics in the business world
  • with the shale revolution, articles began to compare various basins in the US: the Haynesville, the Marcellus, the Permian, the Eagle Ford, the Bakken, etc. -- again, macroeconomics
  • most recently, analysts are comparing "areas" within a basin, such as areas owned by certain operators, or in the case of the North Dakota Bakken, the four or five major counties
  • I don't follow the other plays closely enough to say, but in the North Dakota Bakken, for whatever reason the state regulators decided to define fields, it has worked out incredibly well;
  • it seems like a no-brainer but studies are still faulted for comparing McKenzie County with Williams County, for example. Each of those counties is relatively huge; and different fields within each county vary significantly in quality.  
The second light bulb that goes on: in this paper, wells from 2010 through 2017 were analyzed. I'm sure the researchers factored all that in but I think including wells drilled in 2010 with wells drilled in 2017 is like comparing apples to oranges. Too much to think about. Time to move on. [Later: see first comment.]

Denver Well Logging Society, Spring, 2019, workshop.

Hart Energy, one year ago, September 4, 2018: shifting the focus to optimized production. Operators see opportunities for production gains in legacy wells, refracturing, and data analytics.
  • caption at the linked article: Equinor will deploy artificial-intelligence powered artificial lift technology on its rod pump wells in North Dakota
  • there is evidence that operators might be pumping as much proppant into the well as they can can and that laterals have extended so long that it might not be economic to drill out much farther
  • the phrase "reached a point of maximum return" is tarting to show up more often
  • so, if operators have reached "maximum return" with regard to sand, where do they go next?
  • Equinor -- machine learning/artificial intelligence
in late July (2018) Equinor announced it will deploy a rod lift technology developed by Ambyint—a company that specializes in artificial lift and production optimization equipment— on its wells in the Bakken Shale, where Equinor will expand the system to full-field development.During pilot testing, Equinor was able to automate rod pump well optimization through the use of Ambyint’s autonomous set point management functionality, according to a press release. By identifying wells that were overpumping or underpumping, controller set points were adjusted “with minimal human interference,” the release stated.
  • legacy well optimization:
    • pumping improvements (see article)
    • workovers
    • managing chokes
    • it's not the highest EUR, but the highest IRR
  • well refracturing
    • Oasis experience in the Bakken (see article)
  • artificial life trends (see article)
  • analytics (see article) -- may be the biggest payoff
  • well bashing -- relationship between "parent" and "child" (see article)
    • again, Oasis in the Bakken
Oasis’ Reid said that in North Dakota the company is applying full-field development strategies, so Oasis does not have much activity cycling in the same area, which helps allay the effects of well bashing.
“We generally have one parent well in each of our DSUs, and when we come in for development drilling we are drilling out the full DSU at all depths in the Bakken and Three Forks to minimize future interference effects,” he said. “In addition, we are often refracking the parent well to improve its performance and to minimize the disruption to the new wells from a depleted parent well.”

What Buffett Is Buying, Selling -- November 17, 2019

Disclaimer: this is not an investment site.  Do not make any investment, financial, career, travel, job, or relationship decisions based on what you read here or think you may have read here.

Note: I often make simple arithmetic errors, and factual and typographical errors. If this is important to you, go to the source.

This past week, Warren Buffett got a lot of attention with regard to Apple, Inc; Restoration Hardware; and, other SEC filings for Berkshire Hathaway.

Two stories of note. The first story:
  • he sold about 751,000 AAPL shares
  • his stake in Apple, Inc., increased to 5.6%
  • the strange outcome was due to Apple buying back its own shares; outstanding shares have decreased
    • In a 13F filing with the Securities and Exchange Commission late Thursday, Berkshire disclosed what amounts to a rebalancing of its Apple investment, as the number of shares it owned declined by 750,650 to 248,838,679 shares as of Sept. 30, 2019, from 249,589,329 shares as of June 30, 2019.
    • However, because Apple’s shares outstanding declined to 4,443,265,000 from 4,519,180,000 shares, Berkshire’s ownership stake increased to 5.60% from 5.52%.
    • And since Apple’s stock surged 13% during the quarter, the value of the stock owned by Berkshire increased by over $6 billion, to $55.73 billion as of Sept. 30, 2019, from $49.40 billion as of June 30, despite the lower share count.
The second story.

For Investor's Business Daily I thought this was a pretty poor article. The writer listed the top ten Berkshire Hathaway holdings by the number of shares held, not by the dollar value. The number of shares held is obviously irrelevant. The only thing relevant is the dollar value.

The writer uses the share price of September 30, 2019, when providing holdings by dollar value. That makes sense because we don't know what Buffett may have done with his holdings between September, 2019, and November 15, 2019.

In addition, the author did not note the companies that BRK owns outright, like the Burlington Northern railroad. The top ten listings were only equity holdings in publicly traded companies.

I have added the share value for each of the top ten (Friday, November 15, 2019, close, rounded)
  • BofA: $33/share x 927.3 million shares = $30,600 million
  • Coca-Cola: $53/share x 400 million shares = $21,200 million
  • Wells Fargo: $54/share x 378.4 million shares = $20,434 million
  • Kraft Heinz: $31/share x 325.6 million shares = $10,094 million
  • Apple: $266/share x 248.8 million shares = $66,181 million
  • American Express: $120/share x 151.6 million shares = $18,192 million
  • Sirius XM: $7/share x 136.3 million shares = $7,770 million
  • US Bankcorp: $59/share x 132.5 million shares = $7,818 million
  • Bank of New York Mellon: $49/share x 80.9 million shares = $3,964 million
  • General Motors: $37 x 72.3 million shares = $2,675 million
Doing the math as it is done above, does point out something else. Of the ten holdings, five of them are in the $10 - $30 million range; and, four of them are  below $10 million each in total value.

There is one outlier: AAPL, accounting for almost $70 million, twice that of BofA, #2.

Considering that based on number of shares, AAPL is only #5 of the top ten, but is an outlier in dollar value would suggest to some that AAPL is highly overvalued (though its P/E is only in the low 20s) or the other holdings are undervalued. Or perhaps everything is valued correctly, but AMEX and AAPL need to split their shares to bring them into the $40 - $60 share price enjoyed by most of the others.

Sirius seems to be an outlier for several reasons, but depending when he bought SIRI, Buffett may have done quite well.

Most interesting is this factoid. As of September 30, 2019, AAPL accounted for 26% of the total Berkshire Hathaway portfolio. I do not know if the the writer includes everything owned by BRK or just the equity in publicly traded companies

But, whatever. If AAPL accounts for 26% of his portfolio, equity in publicly held companies or overall, Jim Cramer might argue that this is not a well-diversified portfolio.

Disclaimer: this is not an investment site.  Do not make any investment, financial, career, travel, job, or relationship decisions based on what you read here or think you may have read here.

Note: I often make simple arithmetic errors, and factual and typographical errors. If this is important to you, go to the source.

China Oil Imports -- November 17, 2019

I'm not sure if I posted these graphics earlier. These are important for the archives.



Global Warming Hit The US Very, Very Early This Year -- November 17, 2019

Link here.
  • The Midwestern Regional Climate Center reports more than 850 daily records have been broken across the Midwest in the past two days.

Initial Production Data For The Incredible CLR Carus Wells Coming Off The Confidential List This Next Week -- November 17, 2019

This page will not be updated. The CLR Carus wells are tracked here

35578, conf, CLR, Carus 11-28H, Cedar Coulee,

DateOil RunsMCF Sold
9-20194614556965
8-20195297362506
7-20193031643395
5-201922700

35548, conf,CLR, Carus 6-28H1, Cedar Coulee,

DateOil RunsMCF Sold
9-20193825847363
8-20195953071928
7-20191995221407
5-201922260

35549, conf, CLR, Carus 5-28H, Cedar Coulee,

DateOil RunsMCF Sold
9-20192053322887
8-201956075988
5-201912320

35577, conf, CLR, Carus 9-28H, Cedar Coulee,

DateOil RunsMCF Sold
9-20193659743949
8-20195046459629
7-20192397024989
5-201919550

35550, conf, CLR, Carus 4-28H1, Cedar Coulee,

DateOil RunsMCF Sold
9-201945774988
5-20196220

 35576, conf, CLR, Carus 9-28H, Cedar Coulee,

DateOil RunsMCF Sold
9-20192575129418
8-20194241642767
7-20192912929705
5-201912040

35575, conf, CLR, Carus 8-28H1, Cedar Coulee,

DateOil RunsMCF Sold
9-20192697331541
8-20193524340998
7-20191630915285
5-20197170

Initial Production Data For Wells Coming Off The Confidential List This Next Week -- November 17, 2019

36236, conf, BR, CCU Prairie Rose 1B TFH, Corral Creek,
DateOil RunsMCF Sold
8-2019052

36138, conf, XTO, Sorkness State Federal 34X-36D, Sorkness, no production data,
35578, conf, CLR, Carus 11-28H, Cedar Coulee,

DateOil RunsMCF Sold
9-20194614556965
8-20195297362506
7-20193031643395
5-201922700

35548, conf,CLR, Carus 6-28H1, Cedar Coulee,

DateOil RunsMCF Sold
9-20193825847363
8-20195953071928
7-20191995221407
5-201922260

35255, conf, Hess, BB-Olson-LE-150-95-09H-1, Blue Buttes, no production data, 
29608, conf, Slawson, Snakeeyes 8-20-29TFH, Big Bend,

DateOil RunsMCF Sold
9-201923650
8-201952620


35910, conf, WPX, Beaver 22-21HW, Squaw Creek, no production data,
35256, conf, Hess, BB-Olson-150-95-09H-11, Blue Buttes, no production data, 
35257, conf, Hess, BB-Olson-150-95-09H-10, Blue Buttes, no production data,
31616, conf, BR, He 6-8-20UTFH, Elidah,

DateOil RunsMCF Sold
9-20190508

35909, conf, WPX, Beaver 22-21HC, Squaw Creek, no production data,
35609, conf, Hess, RS-Flickertail-156-91-1720H-2, Ross,


Oil Runs
MCF Sold
9-2019106888015
8-2019127177221
7-201984973887
6-2019155847027
5-2019242128

35604, conf, Whiting, Sylte 24-10-2TFH, Tyrone,

DateOil RunsMCF Sold
9-20191521011543
8-20192053913439
7-20192047914129
6-20191843910112
5-20193473306
  
35549, conf, CLR, Carus 5-28H, Cedar Coulee,

DateOil RunsMCF Sold
9-20192053322887
8-201956075988
5-201912320

35258, conf, Hess, BB-Olson-150-95-09H-8, Blue Buttes, no production data,
31615, conf, BR, Hefer 7-8-20MBH, Elidah,

DateOil RunsMCF Sold
9-20190227

29921, conf, Oasis, O M Erickson 5501 43-7 6B, Missouri Ridge,

DateOil RunsMCF Sold
9-20191977216643
8-20192548321607
7-20191576310697
6-20192479713046
5-201975855097

29609, conf, Slawson, Snakeeyes 5-20-29TFH, Big Bend,

DateOil RunsMCF Sold
9-201918771
8-201953260

35908, conf, WPX, Beaver 22-21HX, Squaw Creek, no production data,
35259, conf, Hess, BB-Olson-150-95-09H-8, Blue Buttes, no production data,
31614, conf, BR, Hefer 8-8-20 UTFH-ULW, Elidah,

DateOil RunsMCF Sold
9-2019095

29920, conf, Oasis, O M Erickson 5501 43-7 5B, Missouri Ridge,

DateOil RunsMCF Sold
9-20191577513097
8-20192090617955
7-20192624223355
6-20191763910680
5-201971829648

35907, conf, WPX, Beaver 22-21HB, Squaw Creek, no production data,
35607, conf, Whiting, Sylte 21-15-2TFH, Tyrone,

DateOil RunsMCF Sold
9-20191483310878
8-20191519712623
7-20191956613044
6-20192137013170
5-20192576231

35295, conf, BR, Meriwether 1A MBH-ULW, Corral Creek,

DateOil RunsMCF Sold
9-20190329

35260, conf, Hess, BB-Olson-150-95-09H-7, Blue Buttes, no production data,
34771, conf, XTO, Lonnie Federal 31X-3D, Hofflund, no production data,  
35577, conf, CLR, Carus 9-28H, Cedar Coulee,

DateOil RunsMCF Sold
9-20193659743949
8-20195046459629
7-20192397024989
5-201919550

35550, conf, CLR, Carus 4-28H1, Cedar Coulee,

DateOil RunsMCF Sold
9-201945774988
5-20196220

34772, conf, XTO, Lonnie Federal 31X-3G2, Hofflund, no production data,  
31967, conf, Petro-Hunt, Klevmoen Trust 153-95-17D-7-3H, Charlson, no production data,
35606, conf, Whiting, Sylte 21-15-2H, Tyrone,

DateOil RunsMCF Sold
9-2019134708968
8-20191613112520
7-20191798010971
6-2019130607502
5-201946121

35357, conf, XTO, Lonnie Federal 31X-3BXC, Hofflund, no production data,
35605, conf, Whiting, Sylte 24-10-2H, Tyrone
DateOil RunsMCF Sold
9-20191608515873
8-20191923117039
7-20191938216053
6-2019102338073
5-201932821

36039, conf, WPX, White Owl 32-29HY, Eagle Nest, no production data,
35835, conf, Kraken, Richard 19-20 1TFH, Sanish,

DateOil RunsMCF Sold
9-20192297310159
8-2019232289565
7-2019238019061
6-2019235500
5-20193080

 35576, conf, CLR, Carus 9-28H, Cedar Coulee,

DateOil RunsMCF Sold
9-20192575129418
8-20194241642767
7-20192912929705
5-201912040

 34722, conf, Oasis, Mildred Nelson 5298 12-25E 7T, Elidah,

DateOil RunsMCF Sold
9-20192169556586
8-20192915772452
7-20193196665915
6-20193726366272
5-20191231930001

36030, conf, RimRock, Skunk Creek 12-10-11-9H3B, South Fork, no production data,
35575, conf, CLR, Carus 8-28H1, Cedar Coulee,

DateOil RunsMCF Sold
9-20192697331541
8-20193524340998
7-20191630915285
5-20197170

34884, conf, Hess, AN-Norby-152-94-0409H-2, Antelope, no production data,
36040, conf, WPX, White Owl 32-29HC, Eagle Nest, no production data, 
36031, conf, RimRock, Skunk Creek 12-10-11-16H, South Fork, no production data,
34883, conf, Hess, AN-Norby-152-94-0409H-3, Antelope, no production data,
29923, conf, Oasis, O M Erickson 5501 44-7 7B, Missouri Ridge,

DateOil RunsMCF Sold
9-20191761113312
8-20192108215092
7-20191506411635
6-20192383912384
5-2019196169341

Wells Coming Off The Confidential List This Next Week -- November 17, 2019

Monday, November 25, 2019: 88 for the month; 189 for the quarter:
36236, conf, BR, CCU Prairie Rose 1B TFH
36138, conf, XTO, Sorkness State Federal 34X-36D,
35578, conf, CLR, Carus 11-28H,
35548, conf,CLR, Carus 6-28H1
35255, conf, Hess, BB-Olson-LE-150-95-09H-1, 
29608, conf, Slawson, Snakeeyes 8-20-29TFH

Sunday, November 24, 2019: 82 for the month; 183 for the quarter:
35910, conf, WPX, Beaver 22-21HW,
35256, conf, Hess, BB-Olson-150-95-09H-11,
35257, conf, Hess, BB-Olson-150-95-09H-10,
31616, conf, BR, He 6-8-20UTFH

Saturday, November 23, 2019: 78 for the month; 179 for the quarter:
35909, conf, WPX, Beaver 22-21HC, 
35609, conf, Hess, RS-Flickertail-156-91-1720H-2, 
35604, conf, Whiting, Sylte 24-10-2TFH
35549, conf, CLR, Carus 5-28H, 
35258, conf, Hess, BB-Olson-150-95-09H-8,
31615, conf, BR, Hefer 7-8-20MBH,
29921, conf, Oasis, O M Erickson 5501 43-7 6B,
29609, conf, Slawson, Snakeeyes 5-20-29TFH,

Friday, November 22, 2019: 76 for the month; 171 for the quarter:
35908, conf, WPX, Beaver 22-21HX, 
35259, conf, Hess, BB-Olson-150-95-09H-8,
31614, conf, BR, Hefer 8-8-20 UTFH-ULW,
29920, conf, Oasis, O M Erickson 5501 43-7 5B, 

Thursday, November 21, 2019: 72 for the month; 167 for the quarter:
35907, conf, WPX, Beaver 22-21HB, 
35607, conf, Whiting, Sylte 21-15-2TFH
35295, conf, BR, Meriwether 1A MBH-ULW,
35260, conf, Hess, BB-Olson-150-95-09H-7,
34771, conf, XTO, Lonnie Federal 31X-3D, 

Wednesday, November 20, 2019: 67 for the month; 162 for the quarter:
35577, conf, CLR, Carus 9-28H, 
35550, conf, CLR, Carus 4-28H1,
34772, conf, XTO, Lonnie Federal 31X-3G2, 
31967, conf, Petro-Hunt, Klevmoen Trust 153-95-17D-7-3H, 

Tuesday, November 19, 2019: 63 for the month; 158 for the quarter:
35606, conf, Whiting, Sylte 21-15-2H,
35357, conf,XTO, Lonnie Federal 31X-3BXC,

Monday, November 18, 2019: 61 for the month; 156 for the quarter:
35605, conf, Whiting, Sylte 24-10-2H,

Sunday, November 17, 2019: 60 for the month; 155 for the quarter:
36039, conf, WPX, White Owl 32-29HY, 
35835, conf, Kraken, Richard 19-20 1TFH,
35576, conf, CLR, Carus 9-28H, 
34722, conf, Oasis, Mildred Nelson 5298 12-25E 7T

Saturday, November 16, 2019: 56 for the month; 151 for the quarter:
36030, conf, RimRock, Skunk Creek 12-10-11-9H3B,
35575, conf, CLR, Carus 8-28H1
34884, conf, Hess, AN-Norby-152-94-0409H-2, 

Friday, November 15, 2019: 53 for the month; 148 for the quarter:
36040, conf, WPX, White Owl 32-29HC, 
36031, conf, RimRock, Skunk Creek 12-10-11-16H,
34883, conf, Hess, AN-Norby-152-94-0409H-3, 
29923, conf, Oasis, O M Erickson 5501 44-7 7B,