American Oil and Gas Reporter - July 2015 - 68

and fracture characterizations, and for
testing the impact on long-term well performance. The matrix attributes mapped
to the simulation grid and used to constrain
the flow simulation are dominant facies,
porosity and permeability. The fracture
attributes per family are dominant orientation, Fisher coefficient and intensity.
Distance to faults also is used to weight
the fracture intensity relative to facies
(brittle facies tend to fracture more than
porous facies near faults).
Fracture attributes then are used to derive
production-constrained directional permeability, porosity and fracture-matrix surface
area using discrete or continuous fracture
modeling. Fracture attributes are used to
derive production constrained directional
permeability, porosity and fracture-matrix
surface area through discrete or continuous
fracture modeling (see Dershowitz, et. al.,
SPE paper 49069, and Gilman, et. al.,
SPE paper 146580). Understanding natural
fractures is obviously important for optimizing completions and well spacing.
Figure 6 shows how the pressure field
(depletion) generated from flow simulation
varies along the well path using simulated
field pressure after 100 days of production.
This variability is a function of matrix
properties (porosity and matrix permeability) and natural fracture intensity near
the wellbore. Areas with a higher intensity
of natural fractures tend to deplete faster
than areas of lower intensity in this example (lower pressure is related to more
depletion). A constant 5X permeability
enhancement was applied in the model
to simulate hydraulic fracturing with a
150-foot effective stimulated radius.
Beyond the traditional use of seismic
data to map "the container" in reservoir
models, seismic data can help constrain
matrix and fracture models calibrated
using flow simulation. Advances in fracture
mapping from post-stack structural seismic
attributes are generating better-constrained
fracture models that include fracture orientations, intensities and dispersion (Fisher
coefficient) per fracture set. Consistency
between static and dynamic data increases
confidence in long-term production forecasts, helping to optimize development.
Critical Dimension
Even though enormous progress has
been made in using seismic to constrain
flow simulation models, there is still a
long way to go before all the data available
in unconventional reservoirs can be integrated fully. Microseismic data acquired
during stimulation will add another critical
dimension to calibrating seismic results
and estimating stimulated rock volumes
from flow simulation.
68 THE AMERICAN OIL & GAS REPORTER



American Oil and Gas Reporter - July 2015

Table of Contents for the Digital Edition of American Oil and Gas Reporter - July 2015

Contents
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