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Sunday, December 4, 2016

Update On The Bridger Wells In Rattlesnake Point Oil Field -- December 4, 2016

In a long note like this, there will be typographical and factual errors. The NDIC map server was a bit tough to sort out but I think I have it correct; but there could be errors. If this information is important to you go to the source.

In a long commentary, facts and opinions will be interspersed. It is often difficult to separate facts from opinions.

If something appears wrong, it probably is.

Finally, I did not proofread this page in its entirety. I consider the page to be a PAGE IN PROGRESS FOR AT LEAST A WEEK giving readers a chance to weigh in on the post.

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To bring yourself up to speed regarding with the Bridger wells, check out this post first, where I track the Bridger/Bonneville wells.

There appear to be eleven (11) CLR Bridger wells. The Bridger wells are on Bridger pads as well as Bridger-Bonneville pads, all in Rattlesnake Point oil field.

The Bridger wells run from the south to the north; the Bonneville wells run from the north to the south.

The eleven (11) Bridge wells are broken down as such:

Five "H" wells, MB: middle Bakken wells. Four of the five "H" wells have been completed and are producing.

Three "H1" wells, TF1: Three Forks, first bench. Only one H1 well has been completed.

Three "H2" wells, TF2: Three Forks, second bench. Only one H2 well has been completed.

Here are the Bridger wells. It's a busy slide. I've tried to line up the "H" wells across the top; the "H1" wells in the second line; and, the "H2" wells along a third line. The "t" date is the month/year the well was tested; generally a well is tested within two months after the well is completed. FracFocus will report exactly when wells are fracked.

SI/NC (DUCs): these wells have been drilled to total depth; they were not fracked at the time they were completed. It is possible they have been fracked; if so, their production reports will soon be available.



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Observations

#17089, middle Bakken well, was completed 4/08. The production profile is quite unusual. Notice the production profile from 7/14 to 4/16.

By 7/14 this well had plateaued at 350 bbls / month. Then taken off line, and production jumped to 3,000 bbls of oil per month. Some suggest this could be simply due to built up pressure while the well was taken off line but that pressure should have "exhausted" itself after a couple of months. Note that the increased production has lasted for many months. It's hard not to think that this increased prodution was due to two "neighboring wells" fracked at this time (8/15).

The problem is that the middle Bakken well that was fracked 8/15 is 1,320 feet away; and, the other "neighboinrg" well that was fracked was from a different formation, the TF1.

But, it's been talked about before the geologic relationship between TF1 and the middle Bakken.

Here's the production profile for #17089:

BAKKEN6-2016302106222060225321592373
BAKKEN5-201631231922316772778342744
BAKKEN4-2016302141202160525422472295
BAKKEN3-201631207620366672494162478
BAKKEN2-201626208522019352472342438
BAKKEN1-2016312849292210903370373333
BAKKEN12-201527260226781158306503065
BAKKEN11-20153321227823820382
BAKKEN10-201531219820141407261002610
BAKKEN9-201530210122272428251302513
BAKKEN8-20152112199112978136401364
BAKKEN7-201500990000
BAKKEN6-20150000000
BAKKEN5-20150000000
BAKKEN4-20150000000
BAKKEN3-20151003000
BAKKEN2-20150000000
BAKKEN1-20152833542911219214745
BAKKEN12-2014314824371533393318
BAKKEN11-201430533687158392252140
BAKKEN10-201422407222345461110351
BAKKEN9-20143044367018343836672
BAKKEN8-201431474448150378243135
BAKKEN7-20143150645214336427985

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Now, take a look at two middle Bakken wells that were fracked back in 2/10. What was the production profile at the time the middle Bakken well that was fracked 8/15?

First, #19013:

BAKKEN1-201631303633062380364023811259
BAKKEN12-201531564957895098637244171955
BAKKEN11-20152235373205402028542043811
BAKKEN10-201523742977717373873656263110
BAKKEN9-20153013506130791406216404635110053
BAKKEN8-2015261330613330161611574197835958
BAKKEN7-201592312252224434430
BAKKEN6-2015301276133346019251817108
BAKKEN5-2015311390133546817861631155
BAKKEN4-2015301395133652718921569323
BAKKEN3-201531163917955852142209052

It's hard to believe that taking a well off-line for less than a month resulted in a build-up in pressure to the extent that production went from 1300 bbls/month to 13,000 bbls/month.

Now, #19011:

BAKKEN1-2016126881319214879287592
BAKKEN12-2015311787144993019176741243
BAKKEN11-201512109030771764
BAKKEN10-20156140050889089
BAKKEN9-20152110011307269103358975
BAKKEN8-201526296928401012290317301173
BAKKEN7-2015126476702196216210
BAKKEN6-2015302471268760832432921322
BAKKEN5-2015312504224267529562270686
BAKKEN4-2015302569272770728712192679
BAKKEN3-2015312874293171231862981205

I can't make any sense out of #19011. This well's production profile has been very erratic over varying periods. One can see the difficulty of figuring this well out when it was only on line for only 6 days in October, 2015, (producing a trivial 140 bbls) and on line for only 12 days in November, 2015, (producing a trivial 109 bbls).

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What I Will Be Watching For

With regard to the halo effect, the next data point to watch will be the production profile of #17089 when #31846 is fracked.

With regard to the halo effect, the next data point to watch will be the production profile of #29552 when #31847 is fracked.

With regard to the halo effect, the next data point to watch will be the production profile of #29554 when #31845 is fracked.

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Discussion to continue.

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Because this was a particularly long note, I had my assistant check the numbers:

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