American Oil and Gas Reporter - September 2015 - 78

SpecialReport: Reservoir Characterization
FIGURE 7
Microseismic Event Depth Histograms (19-Stage Utica Well B)

sand was pumped than in well A. The well
showed three or four bounces, with a characteristic spacing of 1,320 feet per bounce.
The red line denotes the top of the Trenton Limestone, and the green line is the
quantile contour at the top of the deepest
15 percent of points. Well B was drilled
in consistent stratigraphy using geosteer-

ing to maintain its position in the section.
The results from the 29-stage well C
(Figure 8) include obvious faulting effects.
Stage 2 in the hybrid completion design included an 8- to 10-foot fault identified by
geosteering. In this stage, points climbed
to 900 feet above the zone of interest. As
successive stages were pumped, the points

came back to the borehole, indicating that
fluid was being emplaced at the level of
microseismic activity, and that the associated stress shadow in that interval was
providing enough additional stress contrast
to limit height growth in following stages.
This suggests that the process of multistage fracturing in a lateral is potentially a "self-correcting" process. When
closely spaced fractures interact, they escape the stress shadow by propagating out
of zone. Once enough stress has accumulated in the out-of-zone section, stress shadowing allows subsequent fractures to
again be created in-zone. This probably explains why the emphasis on tighter stage
spacing is proceeding in many unconventional plays without obvious problems.
However, understanding the impact of
stress shadowing underscores the importance of using available means to keep
fractures in zone and to minimize the additional hidden costs that can occur as more
stages jump out of zone (deriving from, for



American Oil and Gas Reporter - September 2015

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