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Friday, January 4, 2019

Impact Of Neighboring Fracks -- January 4, 2019

Here we go again, with another example, another nail in the Hubbert coffin.

Put Another Log On The Fire, Tompall Glaser

This well was reported today:
  • 33588, 378, Oasis, Muri 5298 14-28 9T, Three Forks, 50 stages, 4 million lbs, Banks, t7/18; cum 84K 11/18;  #18651, #18980 -- 
Two neighboring wells to follow: one remains off line; the other is back on line --
  • 18651, 462, Oasis, Berquist 34-27H, 33-053-03105, Banks, t8/10; cum 377K 11/18;
Production after initial frack more than eight years ago, followed by the dreaded Bakken decline:

BAKKEN9-20112860945633240921431197871544
BAKKEN8-20112458025419198019025178461079
BAKKEN7-20112865696934320735390350390
BAKKEN6-2011301066810833403540085396800
BAKKEN5-2011301008510337243226352232352712
BAKKEN4-2011291420014238368636778366780
BAKKEN3-2011291672016862744741286316289558
BAKKEN2-20112473757289290913141187811163
BAKKEN1-201130100109819239918151119016150
BAKKEN12-2010311076011011272922437187873550
BAKKEN11-2010301173111453351223427185774750
BAKKEN10-2010311260712702487625319184696750
BAKKEN9-2010301258912276467915744156440
BAKKEN8-20102798849827424415845157450
BAKKEN7-20109384433365136035030

So, how is this well doing now, eight years later? According to FracFocus, this well was not re-fracked. I did not check the sundry forms at the NDIC. One well like this will not move the needle, but tens of thousands over 35 years certainly will. It didn't cost Oasis a dime to see this increased production. Well, I'm sure there were some associated costs ... whatever.

PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN11-2018291119611182179632928128802189
BAKKEN10-201831983810015185932234821700338
BAKKEN9-20185165997989473165307441
BAKKEN8-20180000000


2 comments:

  1. Had that album on cassette in my car. Played til the player ate it. Good stuff
    With the potential of nearby fracs and re-fracking, there is no telling what the ultimate recovery might be from a given well.
    Bodes well for the future

    ReplyDelete
    Replies
    1. You are absolutely correct. My hunch is that the geologists are getting closer and closer to determining "exactly" how much original oil in place(OOIP) exists in any given drilling unit.

      Then it is simply a matter of improving the technology to increase the overall percentage of return. First it was one to three percent return (primary production; then five to eight percent, and Whiting had one time suggested as much as twenty percent, if I recall. Over time, the percent of recovery through primary production will increase.

      Delete

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