Completion Practices in the Bakken
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Transcript of Completion Practices in the Bakken
NYSE: DNR
Completion Practices in the Bakken October 31, 2011 SPE – ATCE
Pat Handren
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Oil Prices & Bakken Rig Count
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NORTH DAKOTA RIG COUNT / NYMEX $ (Crude Oil)
Rig Count Provided By: Infogram of the Dakotas
$84.83
As of 10/14/11
2008 2009 2010 2011 Avg NYMEX Crude
7/11/08 $142/bbl
11/14/18 96 rigs
4/29/11 $113/bbl
9/2/11 201 rigs
1/2/09 $39/bbl
5/8/09 32 rigs
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ND Production History
From NDIC website
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Williston Basin: Bakken System
● Bakken Rocks!
~8% Porosity, Micro Darcy Permeability
High Perm is Bad
MB < 40’ thick, TFS < 250’+
11% TOC (4% was considered world class)
Fractures: Structural related tectonic, stress related regional, expulsion fractures
associated with over pressuring due to hydrocarbon expulsion.
Over-pressured due to hydrocarbon generation.
Most oil generated stayed in the MB member, not to the Lodgepole
400+ Billion bbls generated from Bakken Shales
3.65 billion bbls recoverable oil, 1.85 trillion ft^3 natural gas, 148 million bbls NGLs
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Williston Basin Bakken Formation
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Williston Basin
Early 2008 Early 2011
3800 wells with
120+ new wells
added monthly.
Covering over
25,000 sq. mi.
● History
1953 – 1960
56 vertical wells targeting both zones (209 BOPD avg IP)
Some have cumulative production over 1,000,000 bbl oil to date
1961 – 1976
Billings Nose “Bakken Fairway” on South west side of the Basin
Bail out zone to Red River
1987 - 2005
Horizontal drilling in the shale along the Fairway & Elm Coulee
225 wells: 86 BOPD IP yielding 145 MBOE
2006+
Parshall Discovery Well
3,000 wells later……
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Williston Basin Bakken Development
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Williston Basin
From Continental Resources Presentation
Plug and Perf Staging
Perf, Frac, Plug – Repeat – Perf, Frac, Plug – Repeat… - Perf, Frac
Flow back and hope it does not plug off…
It’s dark down there
– so who really
knows what is
happening?
Plug and Perf Staging
Perf, Frac, Plug – Repeat – Perf, Frac, Plug – Repeat… - Perf, Frac
Flow back and hope it does not plug off…
Ball and Sleeve Staging
Frac, drop ball, frac, drop ball…frac.
Ball and Sleeve Staging
Frac, drop ball, frac, drop ball…frac.
Flow the well and flow the balls back too!
Ball and Sleeve Staging
Frac, drop ball, frac, drop ball…frac.
Flow the well and flow the balls back too!
Still dark…
Standards Set by “The Industry”
● Interval Length
>350’
● Completion Method
Plug and perf (use your imagination - $$$ and time limited)
Ball and sleeve (up to 40 entry points)
Combination (up to 54 stages)
● Proppant and Fluid Volumes
100-125,000 #/stage
● Sand (100 mesh, 40/70, 30/50, 20/40)
● Ceramic (40/70, 20/40, 12/18)
● Mix
1500-2000 bbls/stage
● Slick water
● Linear gel
● Cross-linked
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Questions that NEED to be Answered
● Issues with closure stress and conductivity needs?
Is closure stress consistent from tip to the wellbore?
How much conductivity is necessary for 100 BFPD/fracture?
● Effects of cyclic stresses?
Are we seeing the effects of pressure cycling?
How are refracs restoring production?
● How much of the Fracture is actually cleaning up?
To the tip?
Beyond?
● How can we satisfy our proppant needs?
Competition with other shale plays, who wins?
Buy our own sand mines?
● Where are we going to get/dispose of the water for/from fracturing?
Where does all the water from Lake Sakakawea?
What can we do with the produced water?
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Bakken EUR – Type Curves (Elm Coulee)
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“…neither geologic nor reservoir properties can be predicted at a specific well
location….both reservoir geology and completion efficiency are sufficiently complex
as to be unpredictable from one location to another location. Consequently,
predicting the performance of any particular well prior to completion is virtually
impossible.” (SPEE Monograph 3)
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Williston Basin Bakken Development