Sunday, June 12, 2016

Another Example Of The Halo Effect In The Bakken -- And Just Think -- "We're" Only Getting Started -- June 12, 2016

Updates

June 13, 2016: a reader writes:
EOR (enhanced oil recovery) should have a good future in the Bakken. Water flooding should be great (water flooding is sometimes considered "primary recovery").
The least productive well on a pad, or a nearby pad would be used as a salt water reinjection well. It takes some horsepower to do this but the readily available "cheap" gas for the pumps should make it exceptionally profitable.
Original Post
 
This is going to be a long note. There will be typographical and factual errors. I may be seeing things that don't exist. I may be coming to conclusions that are incorrect. I am doing this to help me understand the Bakken and for no other reason. If this is important to you, go to the source. 

********************************** 
At the following monthly production spreadsheets, pay attention to the third column (the number of days the well was on-line in 11-2015 and 12-2015); the fourth column (bbls oil); and, the sixth column (bbls water):

Well #3 -- note the increase in water production noted in red --
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN4-201630363635577336464145510
BAKKEN3-20163130653250106173867374926
BAKKEN2-20162918881838111692325220435
BAKKEN1-2016302707265815135386024851285
BAKKEN12-201513129113226566197501938
BAKKEN11-20151311261132722110901070
BAKKEN10-20152926812609157932862346858
BAKKEN9-20153027852953193136553189376
BAKKEN8-2015312966305828374123400129

Well #4 -- note: no increase in oil production, but look at the produced water in red:
Pool DateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN4-20163069766797687910897108070
BAKKEN3-2016316656696597521113810410635
BAKKEN2-201629543453571285597259511128
BAKKEN1-2016305699550014309879155183185
BAKKEN12-2015254979502419680730156941534
BAKKEN11-20151314501510107026912399253
BAKKEN10-20153135333446229662626032143
BAKKEN9-20153034443645243158675240537
BAKKEN8-2015313782385924297385723161

Well #1: no increase in either water or oil -- this well will turn out to be the farthest from the other wells; this well was not taken off-line during this period, unlike the other wells in this exercise:

PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN4-201630219121162544408539941
BAKKEN3-2016312359248027614583446426
BAKKEN2-201629236924082607493648472
BAKKEN1-2016232581248232874081398530
BAKKEN12-20153127622877320855714978500
BAKKEN11-201530270426683000472828681772
BAKKEN10-20153126742595289033632764507
BAKKEN9-20153025252610275327662296387
BAKKEN8-201531275426963078324231035


Well #2 -- this is the newest well; it has just been fracked and has just started producing --
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN4-20163010048979888511360213048468
BAKKEN3-2016312044120892170393004229308642
BAKKEN2-20162926883269872370244006380075912
BAKKEN1-201630224042203031750349981495219957
BAKKEN12-20152524622242844301036231142834728

The "Index" well: this is the well that caught my attention. Why did oil production jump in January, 2016? And note the huge increase in water production at the same time. Where did that water come from? Look how much water was produced in just 19 days in December, 2015 -- not due to fracking this well. This well was fracked years ago.
PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN4-20163070976942796782858093103
BAKKEN3-20163181008456101829529935878
BAKKEN2-201629677665601151780007459454
BAKKEN1-2016306268631921254923746554496
BAKKEN12-20151932543144223833827493724
BAKKEN11-201512724747399949783132
BAKKEN10-20153121962109105725252291141
BAKKEN9-20153019492095134623341899345
BAKKEN8-20153121052075129926372410135
BAKKEN7-2015312189217397126382422123
BAKKEN6-20153021292136123226912273328
BAKKEN5-20153123332274127530892680317
BAKKEN4-20153023372300173328102275446
BAKKEN3-201531242026171621389722601544
BAKKEN2-201528212520691245416220472033
BAKKEN1-201531249827141668454523592093

 *****************************
Observations:

Well #3:
  • it appears the well was taken off line in mid-November, 2015, and placed back on line in mid-December, 2015
  • when it came back on-line, there was no noticeable increase in oil production
  • however, look at the huge increase in water, going from1,500 bbls in October to over 15,000 bbls in January, 2016
Well #4:
  • it appears the well was taken off line in mid-November, 2015, and placed back on line in late-December, 2015
  • when it came back on-line, there was a noticeable increase in oil production
  • also, look at the huge increase in water, going from 2,000 bbls in October to almost 20,000 bbls in December, 2015, even though that well was on-line for less than a full month ("severe vomiting")
Well #1:
  • unlike wells #3 and #4, this well was not taken off-line during this period of time
  • during this period of time, there was no noticeable increase in oil production, month-over-month
  • in addition, there was no evidence in any change in the amount of water produced
Well #2:
  • this well was brought on-line in late December, 2015, after it was fracked earlier
  • following the frack, huge oil production
  • following the frack, huge water production
Index well:
  • it appears the well was taken off line in mid-November, 2015, and placed back on line in mid-December, 2015
  • when it came back on-line, there was a huge increase in oil production
  • in addition, look at the huge increase in water, going from1,000 bbls in October to over 22,000 bbls in January, 2016
************************************

The "Index Well" was a middle Bakken well:
I called the "index well," the index well because it had the most noticeable increase in oil production after a neighboring well was fracked.
Wells #1 and #3 were Three Forks wells.

Wells #2 and #4 were middle Bakken wells.

Summary:
1. Well #2 was a middle Bakken well, fracked in late 2015.
2. Wells #1 and #3 were Three Forks wells and did not show any evidence of the "halo effect" based on increased oil production. In addition, there was no evidence of communication based on produced water between the middle Bakken well (#2) and the Three Forks well #1 -- these two wells are 0.84 mile apart. However, there was evidence of communication based on water production between the middle Bakken well (#2) and the Three Forks well (#3). Wells #2 and #3 are laterally separated by about 265 feet. I assume the vertical separation is less than 100 feet.
3. The middle Bakken "index well" was 0.3 mile from the newly fracked well.
4. The middle Bakken well #4 was less than 800 feet from the newly fracked well. 

The graphic:

I apologize for the confusing graphic. I've labeled the horizontals twice: once with the permit number and formation target; and, a second time with just a numeric label.

I labeled the horizontals, 1 through 4, left to right; perhaps I should have numbered them differently. 

Calling one of the wells an index well may be confusing, but I called it that because it showed a definite halo effect. Once I saw the jump in oil production, I then looked for the likely explanation. The only possibility was the fracking of the neighboring well, which I call #2.




These are the wells:
  • 18758, 714, Whiting, 20711 Paulso 49 1H, Stockyard Creek, t4/11; cum 230K 4/16;
  • 23112, 1,657, Whiting, P Bibler 154-99-1-5-8-16H3, a Thee Forks well, t5/13; cum 180K 4/16;
  • 24196, 2,251, Whiting, P Evans 154-99-2-4-9-15H3, a Three Forks well t8/13; cum 165K 4/16;
  • 24198, 2,282, Whiting, P Evans 154-99-2-4-9-16H, t8/13; cum 199K 4/16;
  • 30850, 2,015, Whiting, Marty 31-4H, Stockyard Creek, t12/15; cum 104K 4/16; API 33-105-04003-00-00; frack start 12/7/15; frack end 12/7/15; 7.6 million gallons of water; white sand frack, 9% by weight of total frack components (Frac Focus; data here at Frac Focus; 40 stages, 6.6 million lbs; the sundry form says the well was stimulated 11/18/2015.

No comments:

Post a Comment

Note: Only a member of this blog may post a comment.