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Zeng H.,Bureau of Economic Geology
Leading Edge (Tulsa, OK) | Year: 2010

Todays seismic interpreters have the luxury of choosing from many tools when performing horizontal seismic facies analysis. If the goal is to predict a reservoir in a stratigraphically complex but structurally relatively simple formation using a 3D seismic data set with a good signal-to-noise ratio, stratal slicing may be a valid choice. Stratal slicing was designed for seismic sedimentologic (both seismic lithologic and seismic September 2010 The Leading Edge 1047 geomorphologic) imaging of seismically thin beds. Major benefits include, but are not limited to, a practical solution to create horizontal seismic display of chronostratigraphic significance, an easy link to paleogeomorphology, a tool for thin-bed imaging, high stratigraphic resolution, and a short interpretive cycle time. However, stratal slicing does have limits and unique challenges. Selecting, picking, and verifying a chronostratigraphic framework for stratal slicing remain the biggest challenges. Identification and handling of residual effects of slicing caused by nonlinear, irregular sedimentation require serious new research. © 2010 Society of Exploration Geophysicists. Source

Zeng H.,Bureau of Economic Geology | John A.,University of Texas at Austin | Katherine G.,University of Texas at Austin
SEG Technical Program Expanded Abstracts | Year: 2011

Study of synthetic models and field data shows that anomalous instantaneous frequency can aid thin-bed and stratigraphic interpretation. Time-frequency analysis of instantaneous-frequency spikes may improve continuity of frequency-spike "events" and presentation of instantaneous-frequency attributes for correlation of stratigraphic and reservoir features. Frequency-spike sections calculated in a proper frequency range highlight mostly seismically thin beds (type II). In the field-data example, frequency-spike sections assist in the interpretation of thick vs. thin beds, facies transition, and channels. © 2011 Society of Exploration Geophysicists. Source

Prieto M.I.,University of Texas at Austin | Moscardelli L.,Statoil | Wood L.,Bureau of Economic Geology
Proceedings of the Annual Offshore Technology Conference | Year: 2014

A detailed geomorphologic and shallow stratigraphic interpretation was performed in three different geomorphological domains of the ultra-deepwater region of the central Gulf of Mexico (GOM) using a set of high resolution bathymetry and subbottom profiles that were acquired at four major oil fields in the Green Canyon and Mississippi Canyon protraction areas. The seafloor expression of the study areas allowed defining three different geomorphological provinces: Minibasin, Sigsbee Escarpment and Disconnected Canopy Province. The geomorphological expression of these provinces is primarily the result of the dynamic behavior of the underlying salt, in which these regions experienced different degrees and types of substrate deformation. Structural deformation affecting these areas has been very dynamic through time enhancing the occurrence of both regional and localized gravity-induced deposits. Regions of high relief along diapiric slopes (e.g.: Sigsbee Escarpment) are affected by headwall failures and the near seafloor stratigraphy reveals the complex dynamic of eroded and re-deposited sediments that have been affected by both gravity- and current-driven processes. This study seeks to improve our understanding of how local bathymetric variabilities (linked to underlying structural controls) interact with gravitydriven and current-controlled processes in the ultra-deepwater region of the GOM to generate the near seafloor stratigraphic record that is observable in our study areas. Copyright 2014, Offshore Technology Conference. Source

Freifeld B.,Lawrence Berkeley National Laboratory | Zakim S.,Echogen Power Systems Inc. | Pan L.,Lawrence Berkeley National Laboratory | Cutright B.,Bureau of Economic Geology | And 3 more authors.
Energy Procedia | Year: 2013

A major global research and development effort is underway to commercialize carbon capture and storage (CCS) as a method to mitigate climate change. Recent studies have shown the potential to couple CCS with geothermal energy extraction using supercritical CO2 (ScCO2) as the working fluid. In a geothermal reservoir, the working fluid produces electricity as a byproduct of the CCS process by mining heat out of a reservoir as it is circulated between injector and producer wells. While ScCO2 has lower heat capacity than water, its lower viscosity more than compensates by providing for greater fluid mobility. Furthermore, CO2 exhibits high expansivity and compressibility, which can both help reduce parasitic loads in fluid cycling. Given the high capital costs for developing the deep well infrastructure for geologic storage of CO2, the potential to simultaneously produce geothermal energy is an attractive method to offset some of the costs and added energy requirements for separating and transporting the waste CO2 stream. We present here the preliminary design and reservoir engineering associated with the development of direct-fired turbomachinery for pilot-scale deployment at the SECARB Cranfield Phase III CO2 Storage Project, in Cranfield, Mississippi, U.S.A. The pilot-scale deployment leverages the prior investment in the Cranfield Phase III research site, providing the first ever opportunity to acquire combined CO 2 storage/geothermal energy extraction data necessary to address the uncertainties involved in this novel technique. At the SECARB Cranfield Site, our target reservoir, the Tuscaloosa Formation, lies at a depth of 3.0 km, and an initial temperature of 127 °C. A CO2 injector well and two existing observation wells are ideally suited for establishing a CO2 thermosiphon and monitoring the thermal and pressure evolution of the well-pair on a timescale that can help validate coupled models. It is hoped that this initial demonstration on a pre-commercial scale can accelerate commercialization of combined CCS/geothermal energy extraction by removing uncertainties in system modeling. Source

King C.W.,Center for International Energy and Environmental Policy | Webber M.E.,Center for International Energy and Environmental Policy | Duncan I.J.,Bureau of Economic Geology
Energy Policy | Year: 2010

Concern over increased demand for petroleum, reliable fuel supply, and global climate change has resulted in the US government passing new Corporate Average Fuel Economy standards and a Renewable Fuels Standard. Consequently, the fuel mix for light duty vehicle (LDV) travel in the United States will change over the coming years. This paper explores the embodied water consumption and withdrawal associated with two projections for future fuel use in the US LDV sector. This analysis encompasses conventional and unconventional fossil fuels, corn ethanol, cellulosic ethanol, soy biodiesel, electricity, and hydrogen. The existing mandate in the US to blend ethanol into gasoline had effectively committed 3300 billion liters of irrigation water in 2005 (approximately 2.4% of US 2005 fresh water consumption) for producing fuel for LDVs. With current irrigation practices, fuel processing, and electricity generation, it is estimated that by 2030, approximately 14,000 billion liters of water per year will be consumed and 23,000-27,000 billion liters withdrawn to produce fuels used in LDVs. Irrigation for biofuels dominates projected water usage for LDV travel, but other fuels (coal to liquids, oil shale, and electricity via plug-in hybrid vehicles) will also contribute appreciably to future water consumption and withdrawal, especially on a regional basis. © 2009 Elsevier Ltd. All rights reserved. Source

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