Wednesday, December 16, 2015

How About 90,000 Bbls In One Month In A Short Lateral, 320-Acre Spacing, Antelope Oil Field, The Bakken, North Dakota -- December 16, 2015

Note: I track the EOG Riverview wells in the Antelope oil field at this post. It is confusing because there are also EOG Riverview wells in Clarks Creek, just to the west. I track those wells here, as well as the Antelope oil field Riverview wells.

Updates

March 7, 2017: a well of interest.

Later, 7:19 p.m. Central Time: see first comment below.
On slide 10 of EOG's 3Qtr presentation, they graphically depict the 4,000+ micro seismic events (fractures) per 1,000' that occur with these high density fracs. This is almost a tenfold increase from frac jobs of just a few years ago. 
What is more significant, however, is that they can contain the frac radius fairly close to the wellbore, thus enabling the placement of far more laterals per DSU.

EOG increased their estimated recovery Bakken wide as a consequence of the Riverview's output. 
Other operators will be sure to follow. 
This is the graphic the reader refers to:


Original Post
 
Hold on to your hat. I can't wait to see the frack data on this well; it should be available tomorrow.

Remember: this is a short lateral. The spacing unit: 320 acres according to the permit application.

Spud date: 3/6/15
Cease drilling: 3/20/15

Total depth: 15,564 feet
Total vertical depth: 10,523 feet

Note: almost 90,000 bbls in one month -- rounding up......

We talked about this well several months ago. See this post. Also here. And in a meandering note.

At the links, note the location of this well, and its relationship to Clarks Creek. 

By the way, this is another good example of a well being on the confidential list, then coming off the confidential list and going to SI/NC list, and then going back on confidential list before being fracked. Some years ago, T----- stated that wells don't come on and off and then back on the confidential list.

30286, 1,974, EOG, Riverview 102-32H, Antelope, 23 stages, 12.8 million lbs in a short lateral:

Monthly production data:
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
SANISH1-2017311061210569545240777356621298
SANISH12-201631111111119563293901734624576
SANISH11-2016237861795252202427220841671
SANISH10-20162780438359482341155339273914
SANISH9-201630965291895461474594371055
SANISH8-20163110869108725701497874595614
SANISH7-201631117331177959675036046226317
SANISH6-2016301246312419619350799453061891
SANISH5-2016311485514878685757395461907388
SANISH4-2016301635016456696558878536891376
SANISH3-2016311990219715766970289632402229
SANISH2-2016292266922750778069119562139381
SANISH1-2016311910219750654122936168132306
SANISH12-2015272032719712753444279041153
SANISH11-2015222323424173776567426064716
SANISH10-201531392113918210746829845305826345
SANISH9-201530456344527811980814745632121521
SANISH8-201523395873959011087810211057467872
SANISH7-2015318692487533221321816810177874
SANISH6-20152236619351521145462522059880

It's going to be interesting to see the frack/completion data tomorrow.

From FracFocus (link here): 
  • it was fracked between 5/10/15 and 6/14/15 (inclusive)
  • total volume water: 6,437,764 gallons = 53,725,744 pounds of water or about 54 million lbs of water
  • by weight, the water + sand: 80.64% was water; 19.23% was sand
Working backwards, I get about 12 million lbs of sand. The most sand I recall used by EOG for a frack was 14 million lbs, although deep in the recesses of my mind, I vaguely recall there might have been a 19-million-lb frack. Ah, yes, it was 19 million lbs; here are some "monster wells" with upwards of 19 million lbs.

By the way look at the halo effect on the earlier well on the same pad. The names of these wells suggest the first well (#19247) is a middle Bakken well, and the newer well (#30286) is a Three Forks well:
  • 19247, 1,692, EOG, Riverview 01-32H, Antelope, off-line much of 2015, short lateral, 320-acre spacing; 15 stages, 9.2 million lbs; t11/10; cum 207K 10/15;  
The halo effect may not be much, but there was a slight increase in the production (although, again, it could have been due to other factors than the fracking of neighboring well):

PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
SANISH10-20153123602276786499203841
SANISH9-20153025232431629512604020
SANISH8-20153130293047607542104270
SANISH7-20152028692589687409803366
SANISH6-20150000000
SANISH5-20150000000
SANISH4-20150000000
SANISH3-20150000000
SANISH2-201521147841172350170
SANISH1-20153119822113384449603348
SANISH12-201431164918284403524732303
SANISH11-20143018511836487398411341736
SANISH10-2014312110182769257836413991
SANISH9-201430175218112864925183816
SANISH8-2014311944218842443093153839
SANISH7-201431192117204294244693340

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