American Oil and Gas Reporter - September 2016 - 54

SpecialReport: Reservoir Optimization & Modeling
FIGURE 4

-10,000

11,000

-9,000

10,000

9,000

-8,000

8,000

-7000

North (feet)
-6,000

TVD (feet)
6,000
7,000

-5,000

5,000

-4,000

4,000

3,000

-3,000

2,000

-2,000

Example of Two Stages Indicating
Fracture Half-Lengths on Order of Well Spacing

1,000

2,000

3,000

4,000

5,000

6,000
East (feet)

7,000

8,000

9,000

10,000

11,000

significant overlap between wells, indicating fracture half-lengths longer than
the 1,350-foot well spacing. This suggests
a high potential for interwell production
communication, but also creates more
confidence in propped fracture halflengths between wells.
Microseismic event coverage was excellent along the wellbores. Observed
fracture half-lengths ranged from 1,250

2,000

3,000

4,000

5,000

6,000
7,000
8,000
9,000
Distance along Cross Section (feet)

10,000

11,000

12,000

13,000

to 1,600 feet on the 1-2-3 pad, and from
1,650 to 1,950 feet on the 4-5-6 pad.
Since treatment sizes were fairly similar
for both pads, it is not yet clear why
fractures appear to be longer on the
second pad.
Fracture half-lengths increased during
treatment, reaching maximum extent toward the end of the stage, indicating that
treatment size can control fracture half-

length effectively.
The average principal fracture azimuth
was north 64 degrees east. Microseismic
events indicate great coverage of the main
target zones accompanied by significant
upward height growth through the Niobrara, with total heights between 1,100
and 1,500 feet. Some downward growth
also was observed into the Fort Hays and
"outlier" deep events (>9,000-foot TVD),
which could be stress-related shear events
around faults (appearing mainly in the
toe-half of wells 5 and 6 and the heelhalf of well 2).
Figure 4 shows an example of two
stages with fracture half-lengths greater
than the 1,350-foot well spacing and a
microseismic event cloud width of 400500 feet, indicating fairly planar fractures
from the multicluster stages with no apparent secondary azimuth or multidirectional fracture network complexity. The
larger spread of events in the "green"
stage is related to continued microseismic
activity from previous stages. Fracture
heights are about 1,000 feet and biased
strongly toward shallower TVDs from

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American Oil and Gas Reporter - September 2016

Table of Contents for the Digital Edition of American Oil and Gas Reporter - September 2016

Contents
American Oil and Gas Reporter - September 2016 - Cover1
American Oil and Gas Reporter - September 2016 - Cover2
American Oil and Gas Reporter - September 2016 - Contents
American Oil and Gas Reporter - September 2016 - 4
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