<p> The fluvial and deltaic Wilcox Group is a major target for hydrocarbon and coal exploration in northern and central Louisiana. However, the characterization and delineation of fluvial systems is a difficult task due to the variability and complexity of fluvial systems and their internal heterogeneities. </p><p> Seismic geomorphology is studied by recognizing paleogeographic features in seismic stratal slices, which are seismic images of paleo-depositional surfaces. Seismic attributes, which are extracted along seismic stratal slices, can reveal information that is not readily apparent in raw seismic data. The existence and distribution of fluvial channels are recognized by the channel geomorphology in seismic attributes displayed on stratal slices. The lithologies in the channels are indicated by those seismic attributes that are directly related to the physical properties of rocks. Selected attributes utilized herein include similarity, spectral decomposition, sweetness, relative acoustic impedance, root mean square (RMS) amplitude, and curvature. Co-rendering and Red/Green/Blue (RGB) display techniques are also included to better illuminate the channel geometry and lithology distribution. Hydrocarbons may exist in the channel sand-bodies, but are not explicitly identified herein. Future drilling plans for oil and gas exploration may benefit from the identification of the channels and the lithologies that fill them.</p>

<p> Located in LaSalle Parish, Louisiana, the area of interest for this study encompasses portions of the Tullos-Urania and Olla oil fields, with their hydrocarbon accumulation stemming from the Wilcox Group. The overall objective of this study is threefold; first, generate structure maps of the strata within this area of investigation and identify the productive formations. Second, utilize seismic modeling from local wells defining the most accurate resistivity-to-sonic transform. The last goal is to generate an accurate seismic-to-well tie employing the most accurate sonic log generated at the wells bounding the high-resolution shallow imaging seismic data. This study must use resistivity data to model sonic logs for the bounding wells which have no sonic logs available. The modeled sonic logs are then used to create time- depth relationships between the acquired seismic data and the wells bounding the seismic line. To use resistivity logs to model a sonic log, this study will compare three equations (Faust, 1953; Kim, 1964; Smiths, 1968) to determine their relative accuracies for a one-step resistivity-to-sonic transform. Accuracy is measured by the absolute average deviation of the modelled sonic data from the measured sonic data from wells within the study area, but distant from the seismic line, which have recorded sonic logs. The results of this study indicate that the one-step resistivity-to- sonic equation proposed by Faust (1953) generates the least amount of error when applied to the short resistivity curve. Throughout the modeled logs, the Faust (1953) equation generates an absolute average deviation of 6.0% for the short resistivity curves while Kim&rsquo;s (1964) and Smiths (1968) equations produce 9.7% and 12.8% absolute average deviation. By understanding the variability of these models, future studies can ascertain the best fit model for further investigation of shallow hydrocarbon bearing formations within, or similar to, the Paleocene-Eocene aged strata in Central Louisiana.</p><p>

<p> Among the most important properties controlling the production from conventional oil and gas reservoirs is the distribution of porosity and permeability within the producing geologic formation. The geometry of the pore space within these reservoirs, and the permeability associated with this pore space geometry, impacts not only where production can occur and at what flow rates but can also have significant influence on many other rock properties. Zones of high matrix porosity can result in an isotropic response for certain reservoir properties whereas aligned porosity/permeability, such as open, natural fracture trends, have been shown to result in reservoirs being anisotropic in many properties.</p><p> The ability to identify zones within a subsurface reservoir where porosity/permeability is significantly higher and to characterize them according to their geometries would be of great significance when planning where new boreholes, particularly horizontal boreholes, should be drilled. The detection and characterization of these high porosity/permeability zones using their isotropic and anisotropic responses may be possible through the analysis of azimuthal (also referred to as azimuth-limited) 3D seismic volumes.</p><p> During this study the porosity/permeability systems of a carbonate, pinnacle reef within the northern Michigan Basin undergoing enhanced oil recovery were investigated using selected seismic attributes extracted from azimuthal 3D seismic volumes. Based on the response of these seismic attributes an interpretation of the geometry of the porosity/permeability system within the reef was made. This interpretation was supported by well data that had been obtained during the primary production phase of the field. Additionally, 4D seismic data, obtained as part of the CO₂ based EOR project, supported reservoir simulation results that were based on the porosity/permeability interpretation.</p>