Tuesday, November 17, 2015

Evidence Of Communication Between Wells -- November 17, 2015

Updates

April 26, 2016: in the original post, it was noted that #26158 was taken off-line (status: inactive). As of November, 2015, this wells was back on line:
  • 26158, 3,771, Statoil, Johnston 7-6 3TFH, Banks, t11/14; cum 67K 2/16;
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN2-2016226895739776911229211236591
BAKKEN1-2016251339613316123412222820262978
BAKKEN12-2015281627416317149752774026382177
BAKKEN11-2015211261412039184862569823888965
BAKKEN10-20150000000
BAKKEN9-20150000000
BAKKEN8-20150000000
BAKKEN7-2015001200000
BAKKEN6-2015838383826183454675028439
BAKKEN5-20152741474221226718398149213477

 
Original Post
 
This is a long note. There will be typographical and factual errors. I may be seeing things that do not exist. If this is important to you, go to the source.

While looking up this well for other reasons I happened across this little gem, which is another pixel in the Bakken mosaic, helping me to better understand the Bakken.
29564, SI/NC, Statoil, Skarston 1-12 XE 1H, Banks, no production data,
I think this is a big, big deal, but then I am inappropriately exuberant about the Bakken. I get excited about a lot of things that turn out not to be so exciting and I have been accused of "childlike glee" (yes, that accusation followed one of my book reviews over at Amazon.com).

So with childlike glee and with inappropriate exuberance I post the following -- a small excerpt -- from the file report on this well:
As a measured depth of 20,411', April 4, 2015, the decision was made to stop and circulate out gas while transferring mud and increasing the mud weight. The decision was then made to continue to circulate off bottom while preparation could be made to switch the drilling fluid to oil-based mud. The oil-based mud was then increased to 12 ppg. It was found that even with 12 ppg oil-based mud, the shut in casing pressure (SICP) continued to increase while the well was shut in. It was then decided that the mud weight should be increased further to near 14.2 ppg. This process took several days to complete.
It was later discovered that the unidentified mineral was in fact, ceramic proppant. This is sometimes used as frac sand, or in conduction with quartz sand. It was also later confirmed, that there was in fact communication with an adjacent well that had been recently completed. 
It was believed that this communication between wells was causing the increased pressure and fluid gains.
This adjacent well was the Statoil Johnston 7-6-3TFH (#26158).
The mud weight was increased to 14.2 ppg....after drilling resumed, the pressure increased, and fluid gains were seen. The decision was then made to shut the well in and circulate bottoms up. This yielded a trip gas of 4,602 units, and a large flare ....
...drilling resumed .. while drilling ahead within the lateral, the ROP was near 35 ft/hr.
The slow ROP was due largely to the high mud weight. This caused the pump pressure to be near the maximum pump pressure rating of 5,000 psi at half pump strokes of the previous salt water driling fluid. Even with the high mud weight, slow ROP, and going through the gas buster, the background gas was near 750 units, and a 3 - 10 foot flare produced.
While nearing the end of the drilling, the report continues:
Bottoms up was circulated through the choke, after getting back to bottom. This resulted in a 10'flare and a trip gas of 6,282 units. ... [several challenges ensued]...the lateral was called TD at 20,823 feet (approx 1225 feet early) on April 14, 2015.
Separation and formations:
Horizontal separation between the laterals of the Skarston well and the Johnston well: about 600 feet

Vertical separation between the two laterals, approximately, 130 feet, it appears.
  • The Skarston well, TVD = 10,903 feet
    The Johnston well, TVD = 11,035 feet
The target formations:
  • Skartson: middle Bakken
  • Johnston: Three Forks



The Johnston well:
  • 26158, IA/3,771, Statoil, Johnston 7-6-3TFH, Banks, 35 stages, 4.5 million lbs sand and ceramic, t11/14; cum 18K 9/15; there is no information in the file report why this well is now inactive 
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN9-20150000000
BAKKEN8-20150000000
BAKKEN7-2015001200000
BAKKEN6-2015838383826183454675028439
BAKKEN5-20152741474221226718398149213477
BAKKEN4-201530000000
BAKKEN3-201531000000
BAKKEN2-201528000000
BAKKEN1-201531000000
BAKKEN12-201431000000
BAKKEN11-201430103191013716985000

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