American Oil and Gas Reporter - December 2015 - 71

page 65-73_Layout 1 12/2/2015 12:13 PM Page 71

From this analysis, it is proposed that
numerous bed boundaries and a complex
geomechanical stratigraphy create major
restraints to fracture growth, specifically
limiting proppant transport, placement
and ultimate fracture conductivity. This
is reflected in the microseismic PSRV,
which despite the inherent limitations of
the mass balance model, demonstrates
that only 40 percent of the total stimulated
volume was propped and likely contributing to production.

Encouraging Results
The wireline, core and geochemical
datasets identified two distinct target
zones within the Lower Eagle Ford, each
of which displays geologic properties
that are interpreted to yield high matrixto-fracture deliverability and overall
greater effective matrix drainage of the
reservoir. By targeting multiple zones
within the same reservoir volume, vertical
coverage (SRV and PSRV) within the
entire Lower Eagle Ford section is maximized, allowing access to numerous
compartmentalized flow units prevalent
throughout the section.
Flow analysis from many ultralowpermeability reservoirs suggests that much
of the economic productive time of the
well is dominated by linear flow from
the adjacent matrix that surrounds the
productive fractures. This fracture area
and matrix can be accounted for by calculating the RTA-derived parameter
Sqrt(km)*Acm (or Arootk). It is defined as
the product of total fracture surface area
draining the matrix (Acm) and the square
root of matrix permeability (km). Arootk
was calculated for the six staggered test
wells, with propped surface area estimates
from microseismic or SEM-derived permeabilities substituted into the equation
to solve for km or Acm.
The results show that both estimates
of Acm and km are within the same order
of magnitude predicted by either variable.
This suggests that both estimates are reliable in predicting reasonable well deliverability parameters. The Arootk parameter
also implies that well delivery is dictated
by surface area and not volume, which is
important to recognize when interpreting
the microseismic results of the two pads
with different completions designs.
Decline curve analysis (DCA) and
RTA were used for production forecasting
to understand long-term productivity and
its implications on ultimate field recovery.
After four months of production on pad
1 wells and two months on pad 2 wells,
early results are encouraging. All wells
are performing similarly or better than
offset stand-alone single-zone wells with
no clear productivity loss evident between

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DECEMBER 2015 71
American Oil and Gas Reporter - December 2015

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