Sunday, February 21, 2016

Random Look At Possible Halo Effect Between TFH And Middle Bakken Wells In The Truax Oil Field -- February 21, 2016

Take a look at the production profile of this well, #20518, drilled back in 2011, and then join me below the graphic for a discussion of this well. This well has been producing since September, 2011, but only production data since May, 2013, is shown. Look at the production jump in November and December, 2013 (a small jump) and the incredible jump in production in November, 2015.

To the best of my knowledge, nothing was done to this particular well to account for the jump in production in either time period. The discussion will continue below the production profile.

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NDIC File No: 20518     API No: 33-105-02152-00-00     CTB No: 120518
Well Type: OG     Well Status: A     Status Date: 9/29/2011     Wellbore type: Horizontal
Location: NESE 11-154-98      Latitude: 48.173327     Longitude: -103.238712
Current Operator: WHITING OIL AND GAS CORPORATION
Current Well Name: REIGER 9-11H
Elevation(s): 2350 KB   2328 GR   2332 GL     Total Depth: 19080     Field: TRUAX
Spud Date(s):  6/26/2011 
Completion Data
   Pool: BAKKEN     Perfs: 11427-19080     Comp: 9/29/2011     Status: AL     Date: 4/9/2012     Spacing: 2SEC
Cumulative Production Data
   Pool: BAKKEN     Cum Oil: 253028     Cum MCF Gas: 599337     Cum Water: 153164
Production Test Data
   IP Test Date: 10/9/2011     Pool: BAKKEN     IP Oil: 1067     IP MCF: 2160     IP Water: 485

Monthly Production Data

PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN12-20153192169499597420221185641564
BAKKEN11-20153013109133031114828657266221945
BAKKEN10-2015521151685294933672502852
BAKKEN9-2015181490172894769016688159
BAKKEN8-20153128712854189712393111361164
BAKKEN7-2015313299337923401188811502293
BAKKEN6-2015151612149497439083593272
BAKKEN5-20153126442754158399914119489
BAKKEN4-201530247024681626754730944365
BAKKEN3-20153131393276258194489068287
BAKKEN2-20152824392491217584878129274
BAKKEN1-2015313413349220471127276213558
BAKKEN12-201431337832211732843569711371
BAKKEN11-20143030582922211995569210256
BAKKEN10-20143136333725282912601125080
BAKKEN9-20143032053056233692428765387
BAKKEN8-201431370039583096108911073860
BAKKEN7-201430393638222974102481009663
BAKKEN6-2014303578359730381028410006188
BAKKEN5-201431405742553093984585071245
BAKKEN4-201429393938592834756060251449
BAKKEN3-2014314799488936741054687041749
BAKKEN2-201428377637663154667048001787
BAKKEN1-201431411540133611807818876099
BAKKEN12-20133169976928705318766018673
BAKKEN11-201326563757421018313466013392
BAKKEN10-20130000000
BAKKEN9-20132826792363169285782308266
BAKKEN8-201331328833561595933639895254
BAKKEN7-2013313098317320427353716694
BAKKEN6-201330305635751252802459471988
BAKKEN5-201331354328321575917458793202

If nothing was done specifically to a well to increase its production, one must look at neighboring activity.

Here's the graphic of the area under discussion. To get oriented, the index well under discussion is #20518. Note #25512.



#25512 was fracked in October 16 - November 2, 2013:
  • 25512, 2,154, Whiting, P Evitt 154-98-13-12-2-4H, 35 stages, 4.7 million lbs sand; t11/13; cum 182K 12/15; this will be important later: note this well was taken off-line for most of October and November, 2015. Hold that thought.
So, perhaps the slight increase in production of the index well in late 2013 can be attributed to the halo effect of drilling #25512. Neat, huh?

It gets better.

Now, look at the production profile of the index well again, noting the jump in production  from about 3,000 bbls of oil/month (July, 2015) to a dramatic jump to more than 13,000 bbls of oil/month (November, 2015).

Looking at the graphic above, there is no obvious reason. There are no horizontals near the index well that could explain this increase in production.

Look at the area in the lower left-hand corner where I noted a fair amount of activity. There is a rig on site, most of the sites are still permitted only (status: loc), and the others are confidential. But here's where the new rules on DUCs and the rules on confidentiality help us out.

It turns out that #31238 is the answer. This is so cool.
  • 31238, conf, Whiting, Carscallen 31-14-3TFH, API 33-105-04047, fracked 9/22/15 - 10/5/15
Although #31238 is on the confidential list, some information was posted before the well was placed on the confidential list. The spacing unit for #31238 is .... get this ...  sections 2/11-154-98. That's right. Even though the well is on the confidential list, and even thought the horizontal is not yet shown on the GIS map server yet, the application for this well says the spacing unit is 2/11-154-98. This horizontal is going to go right "through" the index well horizontal. If you don't believe me, look at the plan:

But it gets even better --- not only will we frack #25512 next to your existing well, but we will frack #31238 that runs right through your existing well, and if you are patient, we will frack another well, paralleling #31238 (see diagram which I did not go through the effort to notate; the point is being made):


It looks like the two new wells running south-to-north are TFH wells.

If that's accurate (and it is), think about this. The index well is a middle Bakken well.

It appears #31238 which has already been fracked and probably accounts for the jump in production of the index well (#25512) is a TFH well. The target is the TFH, first bench, at 11,133 feet.

Let's look at the depth of the index well. This should be fun. According to one sundry form (the stimulation form) the vertical depth of the middle Bakken at this location was 11,112 feet. The total vertical depth was 11,147 feet. Maybe someone can provide better numbers but the vertical separation will be less than 40 feet, as far as I can tell (this is way beyond my comfort level; I could be way wrong on this, but various forms confirm this).

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I remember all those discussions early on (back in 2010, I suppose) about whether the middle Bakken and the Three Forks communicate, and later, all those discussions about whether there was such a thing as a halo effect between neighboring wells targeting the same formation. Later, there were discussions about the halo effect between neighboring wells targeting different formations.

I guess I will leave it at that. I think I've provided enough information to at least get started on all this.

Oh, I almost forgot. Remember this from above:
  • 25512, 2,154, Whiting, P Evitt 154-98-13-12-2-4H, 35 stages, 4.7 million lbs sand; t11/13; cum 182K 12/15; this will be important later: note this well was taken off-line for most of October and November, 2015. Hold that thought.
#25512, practically out of the picture was taken off-line for most of October/November, 2015, probably because these new TFH wells were being fracked. That speaks volumes. By the way, was there any jump in production in this well back in December, 2015. I don't know. Let's check:

NDIC File No: 25512     API No: 33-105-03063-00-00     CTB No: 125512
Well Type: OG     Well Status: A     Status Date: 11/6/2013     Wellbore type: Horizontal
Location: SWSW 12-154-98        Latitude: 48.169929     Longitude: -103.232662
Current Operator: WHITING OIL AND GAS CORPORATION
Current Well Name: P EVITT 154-98-13-12-2-4H
Elevation(s): 2332 KB   2304 GR   2304 GL     Total Depth: 22300     Field: TRUAX
Spud Date(s):  6/2/2013
Completion Data
   Pool: BAKKEN     Perfs: 11638-22177     Comp: 11/6/2013     Status: AL     Date: 6/25/2014     Spacing: 4SEC
Cumulative Production Data
   Pool: BAKKEN     Cum Oil: 181771     Cum MCF Gas: 406998     Cum Water: 109043
Production Test Data
   IP Test Date: 11/9/2013     Pool: BAKKEN     IP Oil: 2154     IP MCF: 4432     IP Water: 1496
Monthly Production Data

PoolDateDaysBBLS OilRunsBBLS WaterMCF ProdMCF SoldVent/Flare
BAKKEN12-2015316442659048741291212239580
BAKKEN11-20151213961278222615321208290
BAKKEN10-201532372063041251143
BAKKEN9-20151922862742151441663947165
BAKKEN8-20153140573788301182867700494
BAKKEN7-20153140774223245181357852191
BAKKEN6-201530433142363176102579201967

It's subtle. I think it's there, from 4,000 bbls to 6,500 bbls, but it will be short term, not amount to much, but it helps make up for the time the well had to be taken off line.

One last comment with regard to communication between the middle Bakken and the Three Forks. Look at the jump in water produced in the index well in November/December, 2015. That was most likely fracking water from the TFH well. I could be wrong, but ....

... the Saudis are looking at this very, very closely. I bet. 

Disclaimer: in a long note like this there will be typographical and factual errors. I will see things that may not exist. I do not have formal training and no background in the oil and gas industry. This is for my use only to help me understand the Bakken. Don't quote me on any of this. If this information is important to you, go to the sources, the NDIC, and FracFocus.

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