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NARROW
GeoRef Subject
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all geography including DSDP/ODP Sites and Legs
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United States
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Texas
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Crane County Texas (2)
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McElroy Field (3)
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Upton County Texas (1)
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West Texas (2)
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commodities
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oil and gas fields (3)
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geologic age
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Paleozoic
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Permian
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Guadalupian
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Grayburg Formation (1)
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Primary terms
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data processing (1)
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geophysical methods (7)
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oil and gas fields (3)
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Paleozoic
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Permian
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Guadalupian
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Grayburg Formation (1)
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sedimentary rocks
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carbonate rocks (2)
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United States
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Texas
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Crane County Texas (2)
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McElroy Field (3)
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Upton County Texas (1)
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West Texas (2)
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well-logging (2)
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sedimentary rocks
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sedimentary rocks
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carbonate rocks (2)
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Resolution of slowness and reflectors in crosswell tomography with transmission and reflection traveltimes
A continuation approach to regularization of ill-posed problems with application to crosswell-traveltime tomography
Introduction to the supplement on velocity estimation for depth imaging
An expanding-wavefront method for solving the eikonal equations in general anisotropic media
Analysis of the spectral hole in velocity versus depth resolution for reflection traveltimes with limited aperture
Seismic monitoring of a CO 2 flood in a carbonate reservoir; a rock physics study
Hybrid l 1 /l 2 minimization with applications to tomography
High-resolution crosswell imaging of a West Texas carbonate reservoir; Part 1, Project summary and interpretation
High-resolution crosswell imaging of a West Texas carbonate reservoir; Part 5, Core analysis
Geostatistical Integration of Crosswell Data for Carbonate Reservoir Modeling, Mcelroy Field, Texas
ABSTRACT By establishing a statistical link between a reservoir property of interest (e.g., porosity) and a more extensively available seismic attribute (e.g., acoustic impedance), one can use geostatistical integration algorithms to build improved reservoir models over those generated using well-based information only. This improvement is the result of the additional secondary information regarding interwell heterogeneities of the reservoir property that are known to influence heavily fluid flow in the reservoir (Hewett and Behrens, 1990; Omre, 1991). When these improved models are used in reservoir simulations, the expected value of a suite of simulation outcomes is likely to be closer to the true value than predictions made with only the sparser well control. In addition, the range of outcomes (i.e., uncertainty) should be less with these improved estimates. This reduces the risk associated with using the simulation results when considering various investment options for reservoir management. In a proof-of-concept exercise, we use the P-wave reflection image from a crosswell seismic survey in the McElroy oil field of west Texas to help build a suite of porosity-permeability models. Because we are dealing with crosswell seismic data, the resolution is more than an order of magnitude better than we can get with surface seismic data. We apply a seismic inversion methodology (Bashore and Araktingi, 1994) to compute an image of acoustic impedance between the wells, which we then correlate at each wellbore with porosities obtained from well logs and core measurements. We expect impedance to be a good predictor of porosity because both velocity and density are variably influenced by differing amounts of porosity. We generate several equiprobable porosity and permeability models using conditional simulation. A comparison of two reservoir flow simulations, one using well data only and the other using both well data and crosswell seismic data, suggests that models based upon the second set of data provide results more similar to actual field observations.