Geomorphologic
Delineation of Deepwater Hydrocarbon Reservoirs with Pre-Stack Seismic
Inversion
Contreras, Arturo J.1, Torres-Verdin Carlos2, William L. Fisher2,
William E. Galloway2 (1) Chevron ETC, Houston, TX (2) The
This paper describes the successful
application of a new inversion methodology to quantitatively integrate
pre-stack seismic data, well logs, geologic data, and geostatistical
information for the spatial delineation of deepwater Miocene reservoirs in the
Marco Polo Field, located in the central
Inversion results clearly evidence the
existence of lobate geo-bodies associated with
prospective reservoir areas (M-series). Deterministic inversion results show
high-porosity geo-bodies detected from the P-impedance model, and low “LambdaRho” anomalies characteristic of hydrocarbon-bearing
sands. Similarly, lithotype distributions obtained
from stochastic inversion confirm the presence of lobate-shaped
sand bodies.
Furthermore, co-simulated 3D models of petrophysical properties consistently reveal the existence
of internal heterogeneities (minor internal lobes) within the main lobes.
We use the channel/lobe depositional
model introduced by
The geometry and relatively small size of
the geo-bodies obtained from inversion results, suggest that the M-series
reservoir sands can be described as “mounded” lobes: sandy turbidite
deposits, with low-moderate channelization, and small
areal extent (~ 1 km2). These reservoirs
have been finally interpreted as stacked terminal turbidite
lobes within an overall fan complex; the interpretation is consistent with
previous core-data interpretations and regional stratigraphic/depositional
studies.
AAPG Search and Discover Article #90063©2007 AAPG Annual Convention, Long Beach, California