American Oil and Gas Reporter - January 2015 - 129

TECH TRENDS
Petrophysical Analysis
The petrophysical analysis of tight oil
formations plays a fundamental role in
understanding the mechanical behavior
of tight oil formations and their total organic carbon. Since tight oil reservoirs
vary tremendously from play to play in
mineralogy, stress and the maturity of
organic matter, traditional petrophysical
logs (e.g., resistivity, gamma ray, and
neutron density) assume a more limited
role. Mineralogy in the tight oil formations
controls the rock's mechanical behavior
and determines where and how a formation
should be stimulated.
Production zones in the Barnett Shale,
for example, are strongly correlated with
low stress, high quartz-clay ratios. Mineral
content is a controlling factor also in determining the response of clays (e.g.,
swelling) to stimulation fluids, which can
have an adverse influence on production.
New wireline spectroscopy tools, coupled with advanced multimineral modeling
software tools, have become essential in
understanding the formation fabric of
tight oil reservoirs. Advanced multimineral
modeling can be used to identify prospective zones, quantify rock properties, and
optimize hydraulic fracturing. Customized
multimineral models to estimate kerogen
content, brittleness, and even closure stress
have been developed for shale plays.
Multimineral modeling allows the analyst to specify the minerals and fluids to
be modeled, and then solves for an optimal
solution that provides the best match
among the data, the model and the results.
For example, kerogen modeling in the
Barnett Shale has been improved greatly
with the addition of special minerals such
as pyrite and siderite, which are conducive
to the reducing environment associated
with organic carbons (Figure 4).
Electrofacies analysis also can be
adapted to tight oil formations for facies
delineation and reservoir quality predictions. While many techniques have been
proposed for creating electrofacies with
varying clustering methods based on statistics, graph-theory or neural networks,
the key challenges that formation evaluation professionals face are determining
how many clusters to form and eliminating
operator bias.
In essence, what we want to do is analyze the underlying structure of the input
data and form natural groups. Multiresolution, graph-based clustering offers a

solution that determines the optimal number of clusters at a number of different
resolutions and allows the geologist to
control the final level of detail in his
classification such that it is appropriate
to his requirements. This cluster method
is being applied to tight oil reservoirs
with high levels of success.
Understanding Stimulation
Microseismic data have proven to be
an effective tool in estimating the volu-

metric extent of formations impacted by
hydraulic fracturing, understanding the
stimulation efficiencies along horizontal
wells, optimizing well spacing, and mitigating hazards. This information is fundamental in assessing reservoir heterogeneity and planning future wells.
As the application of microseismic
data and its supporting technology matures, its value in estimating EUR also is
strengthened for the upstream oil and
gas industry. When evaluated with full-

FIGURE 2
Full-Azimuth Common Reflection Angle Image Gathers
From Eagle Ford (Left) and Bakken (Center)
And Eagle Ford Stress Orientation/Intensity Map (Right)

Note: Eagle Ford seismic data courtesy of Seitel

FIGURE 3
Full Characterization of Eagle Ford
Using Full-Azimuth Angle Domain Image Gathers
Total Organic Carbon

Total Organic Carbon

Brittleness

In Situ Stress

JANUARY 2015 129



American Oil and Gas Reporter - January 2015

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

Contents
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