NADOA North Dakota Seminar
The Game Plan
April 11, 2012
Enerplus Assets
1
Nesson Anticline
Montana
North Dakota
Detailed Williston Basin map
Williston
Watford City
Sidney
Elm Coulee Field
Ft. Berthold Indian Reservation
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2
Elm Coulee Bakken Type Log
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Hydraulic Fracturing
Fracturing fluid - The fluid used during a hydraulic fracture
treatment of oil, gas, or water wells. The fracturing fluid has two major
functions:
1.Open and extend the fracture.
2.Transport the proppant along the fracture length.
Proppant - Suspended particles in the fracturing fluid that are used to
hold fractures open after a hydraulic fracturing treatment, thus producing a
conductive pathway that fluids can easily flow along. Naturally occurring sand
grains or artificial ceramic material are common proppants used.
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4
Lateral Configuration 2000 - 2002
First 17 Wells Completed as 5-1/2” Mono-Bores
Focus was on limited entry
• Four, 3’ perf clusters placed across drilling breaks and gas shows
• Typical perf density was 29 holes over 3,000’ of lateral in five groups
• Early perforating was done with TCP guns
• Perfs in the toe clusters were increased slightly assuming that the frac
would prefer to treat the heel due to higher treating pressures
• 30-35# X-linked Borate gels pumped at 45 BPM placing 390,000 # of
premium 20/40 resin coated proppant ramped up to 6 ppg
9-5/8”
• RA tracers were run in to better understand proppant distribution
• Tracers indicated some heel treatment, however, frac preference seemed
to be towards the toe
5-1/2”
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Lateral Configuration 2002 - 2004
• Continued to run 5-1/2” casing cemented from the curve to the base of the
9-5/8” surface casing
• Cementing was through a DV tool above an External Casing Packer
9-5/8”
5-1/2”
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Lateral Configuration 2004 - 2006
• Begin to run 7” intermediate casing cemented from the curve to the base
of the 9-5/8” surface casing
• Cementing was through a DV tool above an External Casing Packer
9-5/8”
4-1/2” Liner
7”
7
Lateral Configuration 2006-2007
•
First attempt to use a single water swell packer in open hole to
create two separate isolated compartments that could be
fraced independently of each other.
– Mid-lateral to toe was pre-perforated and perforations were
plugged with aluminum inserts that could later be knocked off with
a bit prior to fracturing
– A composite bridge plug was then set inside the liner at mid-point
followed by jet perforating from the mid-point to the heel prior to
fracturing second stage
– Completion results were more encouraging
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Sleeping Giant 2008-2009
•
Progression to 2-3 water swell packers to break lateral in to 3-4
compartments (1,500-3,000’ in length)
–
–
–
–
–
Pre-perforating mid-point to toe
Jet perforating mid-point to heel
Using ball sealers and benzoic acid flakes (BAF) for diversion
Later used fiber gel slugs in an attempt to create fluid diversion
Frac fluid systems were similar to pre-2008 jobs
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Current Completion Design 2012
10
Double Barrel Ball Seats
Side view
Front view
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Ball Actuated Frac Sleeve
• Sleeves contain ball seats that are sequentially opened
during the scheduled fracture treatments
• The ball serve two purposes:
º
º
Shift open the sleeve
Temporarily isolates previous stage/interval
• Locking device ensures the sleeve remains open
12 © 2009 Baker Hughes Incorporated. All Rights Reserved.
Hydraulic Set Open-Hole Packer
• Used to isolate intervals to be fraced
• Set with differential pressure at the packer
13 © 2009 Baker Hughes Incorporated. All Rights Reserved.
Swell Packer
• A self-energized swelling elastomeric packer that seals in
open hole
• Built on a casing pup that matches the mechanical properties
of the liner
• The packer element reacts with annular fluid
º
º
14 © 2009 Baker Hughes Incorporated. All Rights Reserved.
Water reactive element
Oil reactive element
Single Frac Stage Pumping Schedule for Ft. Berthold
Stage
Fluid
Rate
Clean
Proppant
Proppant
Proppant
Description
Description
Liquid + Prop
Volume, gal
Type
Concentration
Volume
Drop ball(s)
10# Water Frac
35
10,000
Pump-in
Slickwater
10
1,000
0
0
Pre-pad
35# Linear gel
35
10,000
0
0
Pad
35# XL Borate (33)
35
12,000
0
0
Prop Laden Fluid
35# XL Borate (33
35
2,000
0.25
500
Spacer
35# XL Borate (33
35
12,000
0
0
Prop Laden Fluid
35# XL Borate (33
35
2,000
0.5
1,000
Spacer
35# XL Borate (33
35
12,000
0
0
Prop Laden Fluid
35# XL Borate (33
35
10,000
20/40 ceramic
1
10,000
Prop Laden Fluid
35# XL Borate (33
35
12,000
20/40 ceramic
2
24,000
Prop Laden Fluid
35# XL Borate (33
35
15,167
20/40 ceramic
3
45,500
Prop Laden Fluid
35# XL Borate (33
35
11,000
20/40 ceramic
4
44,000
Total
109,167
20/40 ceramic
20/40 ceramic
125,000
Note: Will seat frac ball(s) at 10-15 BPM
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Dissolving Frac Balls
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Frac Sleeve Demonstration at 40 BPM
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Thank You!
Any questions?
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