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Friday, February 26, 2016

Flashback: A Random Update Of One Of The First (?) Five-Well Pads In The Bakken -- February 26, 2016

Updates

February 26, 2016: the original post was dated November 23, 2011 and was very short; just pointing out the beginning of the "manufacturing stage" in the Bakken; the IPs, production profiles, and halo effect were all updated this date. 

The original 5-well pad now had a neighboring 3-well pad. Of the 8 wells, all run to the north, except #21952 and #21954, which run to the south. The wells on the 3-well pad all run to the north. For their production profiles, see the bottom of this post.


 
Original Post
November 23, 2011
 
I think this is the first bona fide 5-well pad (permits) in the Bakken, in Alger field, one of the better Bakken fields, all in SWSW 20-155N-92W, all are 350 feet from the south line; the farthest west is 950 feet from the west line, and then they are spaced 25 feet apart, so that the farthest east is 1,050 feet from the west line :
  • 21952, 4,293, Statoil/BEXP, Sorenson 29-32 3H, Alger, t9/12; cum 261K 12/15; runs south;
  • 21953, 2,790, Statoil/BEXP, Cvancara 20-17 2TFH, Alger, t9/12; cum 178K 12/15; runs north;
  • 21954, 3,078, Statoil/BEXP, Sorenson 29-32 4H, Alger, t9/12; cum 227K 12/15; runs south;
  • 21955, 2,972, Statoil/BEXP, Cvancara 20-17 3H, Alger, t9/12; cum 201K 12/15; runs north;
  • 21957, 1,779, Statoil/BEXP, Cvancara 20-17 4TFH, Alger, t7/14; cum 86K 12/15; runs north;
Pretty cool.

When you get to the Alger field (see link above), check out the huge BEXP wells in that field, and then do a head-to-head comparison of IPs with other drillers in that field.

This is where some record IPs were recorded by BEXP (Cvancara and Sorenson). I need to go find the links. This is really quite incredible.

Interestingly enough, these wells are just a few miles to the northeast of where KOG acquired the North Plains Energy acreage. Very, very exciting.

*********************************
Production Profiles For Past Few Months

21952, 4,293, BEXP, Sorenson 29-32 3H, Alger, t9/12; cum 261K 12/15:

PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN12-2015112655233112491227771456
BAKKEN11-20150000000
BAKKEN10-2015111726129288520921910182
BAKKEN9-20151416332239948872758114
BAKKEN8-20153142464094296122491988261
BAKKEN7-20153147224931282143093445864

21953, 2,790, BEXP, Cvancara 20-17 2TFH, Alger, t9/12; cum 178K 12/15:

PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN12-201531248924155087174417440
BAKKEN11-201530323733324113171917190
BAKKEN10-201519263223552846130413004
BAKKEN9-201516927737744529
BAKKEN8-20153130723144121827172150567
BAKKEN7-2015313804380354543033696607

21954, 3,078, BEXP, Sorenson 29-32 4H, Alger, t9/12; cum 227K 12/15:

PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN12-20151121161993142918661679187
BAKKEN11-20150000000
BAKKEN10-20151116921750777191919190
BAKKEN9-20151414411301561186118610
BAKKEN8-201531411842551109450745070
BAKKEN7-201531404540741425541454140

21955, 2,972, BEXP, Cvancara 20-17 3H, Alger, t9/12; cum 201K 12/15:

PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN12-20153149384767364049894824165
BAKKEN11-20153060096153320150254767258
BAKKEN10-20152046034731310321542012142
BAKKEN9-20151325862403131031812895286
BAKKEN8-201531627763802309731060781232
BAKKEN7-20153172087167393571386304834

21957, 1,779, BEXP, Cvancara 20-17 4TFH, Alger, t7/14; cum 86K 12/15:


PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN12-201530432440296839604846071441
BAKKEN11-20153029153025369236683548120
BAKKEN10-2015192589232129942282219092
BAKKEN9-20151863171061851805
BAKKEN8-20153134443606503667456332413
BAKKEN7-201531531251635337791767881129
BAKKEN6-20152933883520590246304387243
BAKKEN5-20153162236285716892969024272


Just one example of the halo effect. The first four wells were taken off-line in the summer of 2014, when the fifth well was fracked. This is the production profile of one of those four wells (#21954) around that time:

BAKKEN9-20142912815126815361165341649143
BAKKEN8-2014201169811389374915559142451314
BAKKEN7-2014233690000
BAKKEN6-20140000000
BAKKEN5-2014181174711722497814928135181410
BAKKEN4-201413954396631604751064521058
BAKKEN3-20141300000
BAKKEN2-20140000000
BAKKEN1-20140000000
BAKKEN12-20130000000
BAKKEN11-201330000000
BAKKEN10-20133123492879690189401894
BAKKEN9-201315383929141210290202902

************************************
Production Profiles Of The Three "New" Wells

26344, 1,896, Statoil, Dvancara 20-17 5H, t7/14; cum 115K 12/15:
26345, 1,463, Statoil, Cvancara 20-17 6TFH, t7/14; cum 60K 12/15:

26346, 2,384, Statoil, Cvancara 20-17 7H, t7/14; cum 152K 12/15:


PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN12-20153176897348611037163113603
BAKKEN11-201530816581554504708431723912
BAKKEN10-2015254403464032921707161097
BAKKEN9-201513293528981868445933081151
BAKKEN8-201531946496026245530625962710
BAKKEN7-20153110649103826985529028482442
BAKKEN6-201529718873474456367613742302
BAKKEN5-2015311130911388565834792520959
BAKKEN4-2015301270212967938324781853625
BAKKEN3-2015311547815204773944943786708
BAKKEN2-2015281608215919765357765040736
BAKKEN1-20151397599589640545474222325
BAKKEN12-2014181015196921515730612920141
BAKKEN11-20140013820000
BAKKEN10-20141417951185805826891276301282
BAKKEN9-20143039501939173225622229333
BAKKEN8-2014310350000
BAKKEN7-20143138473812130430930141295


************************************
A Re-Frack

21957, 1,779, Statoil, Cvancara 20-17 4TFH, spud 5/10/12; TD reached 6/3/12; t7/14; cum 86K 12/15;

This well was originally fracked 8/31/12: 5 stages; 534,092 lbs of proppant (sand + ceramic); obviously something went wrong with the frack or they were simply seeing what 5 stages would do (I doubt it) -- at the time of the application, they were planning on 33 swell packers to complete the well.

They came back and re-fracked on 6/11/2014: 35 stages; 3.3 million lbs proppants
(again, sand + ceramic).

The sundry form for both fracks was received by the NDIC on August 16, 2014. 

Even though it was re-fracked in July, 2014, the well did not reach significant production until several months later, December, 2014. There may have been operational reasons -- there are four other wells on that pad and another multi-well pad in the immediate area.

Full production profile:

PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN12-201530432440296839604846071441
BAKKEN11-20153029153025369236683548120
BAKKEN10-2015192589232129942282219092
BAKKEN9-20151863171061851805
BAKKEN8-20153134443606503667456332413
BAKKEN7-201531531251635337791767881129
BAKKEN6-20152933883520590246304387243
BAKKEN5-20153162236285716892969024272
BAKKEN4-20153072817436966278527479373
BAKKEN3-201531891487641094052865186100
BAKKEN2-20152894169911947363306166164
BAKKEN1-2015301489014554209911407613862214
BAKKEN12-20142513778131552725862945987307
BAKKEN11-20140030000
BAKKEN10-20144446261450145
BAKKEN9-2014304120114215114
BAKKEN8-2014310300000
BAKKEN7-2014313340331042761282418101014

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