Challenge
The field consists of massive,homogeneous marine turbiditesandstones with excellent reservoirproperties; however postdeposi-tional faulting and deformationresulted in highly deformedreservoir boundaries. These fea-tures complicate well placement.On some wells, more than 33% of injection shales were crossedon the horizontal section, affect-ing borehole stability and impact-ing well production. The primaryobjective was to develop theresource safely and with the leastnumber of wells.
Solution
A reservoir heterogeneity studywas conducted over the field to understand the shale and thesand injection distribution, basedon the combination of four com-ponent and Q-Marine* surfaceseismic data.
Results
The results of this study encour-aged the use of specialized tech-nology; for example, an ultradeepresistivity LWD tool was partic-ularly useful in addressing thespecific challenges of the field.
Reservoir Heterogeneity Study Improves Well Planning Efficiency Case study: Reduced drilling risk with 3D surface seismic data
Steering in complex sandstone formations
The field under study consists of massive, homogeneous marine turbidite sandstones
with excellent reservoir properties. The reservoir is located in a Tertiary formation,
providing stratigraphic traps consisting of massive, medium-grained, homogeneous
turbiditic sandstones and enclosed by shales. The deposition and geometry of the
turbidite sand lobes were primarily controlled by the original basin morphology, which
forced the sand to deposit along a main axis parallel to a structural high.
The postdepositional faulting and deformation resulted in highly deformed reservoir
boundaries, where shales have been squeezed into the sand and sand has been injected
into the overlying shales in the form of dikes and sills. These features complicate well
placement and make it even more important to steer the wells accurately. On some
wells, more than 33% of injection shales were crossed on the horizontal section, affect-
ing borehole stability and impacting well production.
3D seismic facies analysis
A reservoir heterogeneity study was conducted over the field to understand the shale
and the sand injection distribution, based on the combination of four component and
Q-Marine surface seismic data. The results of this study encouraged the use of special-
ized technology, for example, an ultradeep resistivity LWD tool was particularly useful
in addressing the specific challenges of the field.
Heterogeneity mapping confirmed the shale injections at the well location.
Geology
Case study: Reduced drilling risk with 3D surface seismic data
In this field, the turbidite
sand lobes have undergone
syn- and postdepositional
deformation generating a
complex geometry of the
main reservoir sands. This
geometry is characterized
by a shale streak coming
from beneath the reservoir
and sand injectites distrib-
uted above the reservoir and
on both margins of the main
sand lobe.
The general inversion
scheme involves 3D seismic
facies analysis, which is
a powerful quantitative technique derived from seismic stratigraphy. Seismic facies are
groups of seismic reflections with parameters such as amplitude, continuity, reflection
geometry, and frequency. These are distinct from adjacent groups.
This approach consists of a 3D classification of the seismic texture attributes using
a proprietary algorithm. The geological derivation of the classes is determined by investi-
gating the character of the seismic data and the lateral-vertical associations of seismic
facies, using well calibration and rock physics analyses.
The heterogeneity classes are extracted as a 3D geobody and sampled as a grid. The
geobody grid is populated with rock physics properties, which add a qualitative measure-
ment to the heterogeneous bodies. 3D geobodies include a risk scale that converts the
classification results into a 3D drilling risk map.
Well planning process improved
The primary objective of asset teams is to develop the resource safely and with the least
number of wells. Predrill seismic assessment of drilling hazards has become an essential
part of the well planning process. 3D reservoir heterogeneity mapping leads to a better
understanding of the geometry of the reservoir interval and increases the efficiency of the
well planning process.
E-mail [email protected] or contact your local Schlumberger representative to learn more.
06-DC-011 November 2006 *Mark of SchlumbergerCopyright © 2006 Schlumberger. All rights reserved.Produced by Schlumberger Marketing Communications
www.slb.com/dcs
Optimizing well placement with a 3D risk map.
3D distribution of the seismicfacies derived from classifica-tion of seismic texturesabove the main sand lobe. Red denotes the potential sandinjectites. Log data from thewells confirmed the presence of remobilized sands.
Shale injections mapped as V-shaped features on the seismicdata. On some wells, more than33% of shale injections werecrossed on the horizontal section.