Random Update Of CLR's Bridger / Bonnevillle Wells In Rattlesnake Point -- August 23, 2015

Updates

February 21, 2019: see this post; a re-entry; large re-frack; 

December 1, 2018: see this post for an example of an halo effect between a middle Bakken well and a Three Forks upper bench well. 

March 7, 2018: update of an old Bridger well that's been successfully re-entered and re-fracked.

December 21, 2017: Bridger/Bonneville wells with jump in production, some fracked; some not fracked.

October 22, 2017: Rattlesnake Point wells have been updated.

August 8, 2017: Bridger 9-14H1 (#31847) was fracked in April, 2017. 

January 28, 2017: two more Bridger wells added (see below); one Bridger well taken off-line; reason not noted.

December 4, 2016: update here; a long and important update. 

September 28, 2015: From a reader -- FYI, In the next few days when August production numbers are available on NDIC, check out the decline curve on either well #19011 or #19013. Halo effect?

Original Post

Note: in a long note like this there will be factual and typographical errors. In addition, CLR made a lot of changes in targets and well names after the original applications; not all changes have been noted below. If this information is important to you, please go to the source, either CLR or NDIC.  Once wells are completed, names will be corrected if necessary.

These are the wells:

I am posting this information based on an earlier long comment from a reader which is re-posted here:

Some interesting things going on with all these new [Bonneville/Bridger] wells. None of the nine new wells have ever been on confidential so you have access to their well files.

The 6-well pad is on a 2560-acre unit; the last three Bridger wells are on a 1280-acre spacing unit. The Bonneville wells are being drilled right now as 2 MB wells and 1 TF1 well. The Bridger wells appear to have been fracked? They are MB TF1 & TF2 wells. Oil has already been hauled off for two of the Bridger wells with the note on the form that this is NOT the first sale of oil, also noted something about coil tube sale? What does that mean?  [Comment: readers will have to weigh in; I do not know but I will see what I can find out.]

Of the new wells, same layout MB TF1 & TF2, it appears that they must be in a big hurry to drill as it looks to me like the day NDIC approved the permits the surface casing for all three had already been set? If I read the file correctly.

Also if you look in the new files the plan and profile for the wells on the drilling unit show a detail I don't think I have seen before. There are ovals drawn perpendicular to the well bore and the further north they go the larger they become. You suppose those ovals represent the frack effort they intend to achieve?

Also note on the gas capture form they estimate that the initial daily flow of oil, not counting gas, is just over 2,100 barrels a day each for all three. (I don't understand gas production numbers.) That would be a high IP rate for a CLR well let alone that rate for any period of time. Maybe for design purposes they overstate anticipated production? When you look at the area map of these wells you realize the north end of these wells are not far from the south end of a very special Whitman well in the Oakdale field. It will be interesting to follow over the next year or so to see how these wells turn out. [Comment: lots of observations and comments; I will do what I can. Hopefully, other readers will weigh in -- provide some thoughts.]

Comments: with regard to oil  production, if there were any sales, that would have to be noted on the NDIC scout ticket; to date that data is not there but there could be a delay in reporting.

It is noted that in a sundry form for 29554, for example, a small amount of oil (222 bbls) has been sold, and it was said that "this is not the first sales" -- but that is boilerplate from the form. It is possible the "coiled tube sales" is referencing a coiled tube fracking. I would assume all wells would be fracked at approximately the same time and the fact that there is still on rig on site suggests that they have yet to frack the wells, but, again, a) I don't know the timing, the process; and, b) there can be a disconnect between what is happening in the field and what we see in the files and on the GIS map server due to delays in reports and updates. Bottom line: for me, it's still too early to say how this will all play out.

In the planning report for #29554, for example, with regard to ONEOK, under flowback strategy, CLR anticipates first production to be 9/27/15; gas sales connection is expected by 9/13/15. Anticipated oil and gas rates: IP, 4,490 BOPD, 3,628 MCFD.

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Bridger-Bonneville Well Pads 

One day after the original post, CLR added another 3-well pad, NWNE 23-146-96, 495 FNL, 1740 - 1830 FEL; they look to be in same area as the new 6-well pad in the graphic:

• 31845, 879, CLR, Bridger 7-14H2,Three Forks 2nd bench, t8/17; cum 322K 12/20; cum 325K 2/21;
  
• 31846, 1,389, CLR, Bridger 8-14H, middle Bakken, t8/17; cum 224K 12/20; cum 226K 2/21;
  
• 31847, 1,515, CLR, Bridger 9-14H1, Three Forsk, 1st bench, t8/17; cum 230K 12/20; 232K 2/21;
  

It appears the Bonneville wells run north, the Bridger wells run south. Again, I could be wrong, 29552and there might be exceptions.

• 19013, 399, CLR, Bridger 2-14H, Three Forks, 21 stages, 2.3 million lbs sand/ceramic, t12/10; cum 388K 12/20; 393K 2/21;
  
• 19012, 365, CLR, Bonneville 2-23H, Three Forks, 24 stages, 2.5 million lbs; 4 sections, t12/10; cum 222K 12/20; huge bump in production 6/17; not re-fracked according to FracFocus; cum 224K 2/21;
  
• 19011, 725, CLR, Bridger 3-14H, Bakken NOS, 21 stages, 2.2 million lbs sand/ceramic; 4 sections, t12/10; cum 354K 12/20; a small bump in production after coming back on-line; cum 355K 2/21;
  
• 19009, 651, CLR, Bonneville 3-23H, Bakken NOS, 24 stages, 2.5 million lbs sand/ceramic; 4 sections, t12/10; cum 436K 12/20; slight bump in production after being off-line for a few months; cum 438K 2/21;
  

• 29554, 1,018, CLR, Bridger 4-14H2, name change when target changed to Three Forks B2 (was TF B1); 4 sections,  API: 33-025-0267; t1/16; cum 390K 12/20; cum 395K 2/21;
  
• 29553, 1,160, CLR, Bridger 5-14H, Bakken NOS, four sections, API 33-025-02678; t9/15, cum 419K 12/20; cum 422K 12/20;
  
• 29552, 1,977, CLR, Bridger 6-14H1, Three Forks B1 (originally was 6-14H2, TF B2); four sections, API 33-025-02677; note: all the documents up to this date (November 9, 2015, show this well still named -14H2, but the GIS map shows it correctly at -14H1; 30 stages, 6 million lbs; t9/15; cum 303K 12/20; 305K 2/21;
  

• 29551, 1,311, CRL, Bonneville 4-23H, sounds like a minor glitch at the KOP while drilling; originally planned to be a TF well; changed target to middle Bakken; t8/17; cum 267K 2/21;
• 29550, 1,407, CRL, Bonneville 5-23H1, new name; apparently was a middle Bakken; now a Three Forks first bench; nice production but back on conf list; t8/17; cum 311K 2/21;
• 29549, 1,518, CRL, Bonneville 6-23H1, original target the middle Bakken; changed to Three Forks B1; t8/17; cum 354K 2/21;

• 17088, 267, CLR, Bonneville 41-23, 1 million lbs sand, t4/08; cum 246K 11/20; stripper well, September 21, 2012; was not re-fracked; huge jump in production in 7/17; off line 12/20; cum 248K 2/21;
  



• 17089, 400, CLR, Bridger 44-14H, t4/08; cum 404K 12/20; and then back on confidential; re-fracked 4/17; see this post; cum 406K 2/21;
  
• 32740, 1,485, Bridger 10-14H2, Rattlesnake Point, t9/17; cum 353K 12/20; 356K 2/21;
  
• 32781, 1,067, CLR, Bridger 11-14H1, Rattlesnake Point, t12/17; cum 276K 2/21;

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Geology limits in this area, +/-, TVD, #29554:

• Lodgepole: 10,265
• Upper Bakken Shale: 11,128
• Middle Bakken Member: 11,144
• Lower Bakken Shale: 11,182
• Three Forks/Base of Shale: 11,195
• Three Forks Target: 11,217
• End of Lateral: 11,192 

Geology limits in this area, +/-, TVD, #29550:

• Lodgepole: 10,265
• Upper Bakken Shale: 11,128
• Middle Bakken Target: 11,159
• End of Lateral: 11,169