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The AAPG/Datapages Combined Publications Database

AAPG Special Volumes


G. P. Eberli, J. L. Masaferro, and J. F. ldquoRickrdquo Sarg, 2004, Previous HitSeismicNext Hit imaging of carbonate reservoirs and systems: AAPG Memoir 81, p. 91-105.

Copyright copy2004. The American Association of Petroleum Geologists. All rights reserved.

Integrated Reservoir Characterization of a Carbonate Ramp Reservoir, South Dagger Draw Field, New Mexico: Previous HitSeismicNext Hit Previous HitDataNext Hit Are Only Part of the Story

Scott W. Tinker,1 Donald H. Caldwell,2 Denise M. Cox,3 Laura C. Zahm,4 Liseuml Brinton5

1Bureau of Economic Geology, University of Texas at Austin, Austin, Texas, U.S.A.; Present address: Bureau of Economic Geology, University of Texas, Houston, Texas, U.S.A.
2Marathon Oil Company, Houston, Texas, U.S.A.
3Marathon Oil Company, Denver, Colorado, U.S.A.
4iReservoir.com, Englewood, Colorado, U.S.A.
5LithoLogic, Littleton, Colorado, U.S.A.


This chapter is reprinted, with slight modification, with the permission of the Gulf Coast Section SEPM Foundation Previous HitfromNext Hit T. F. Hentz (editor), GCS-SEPM Foundation 19th Annual Bob F. Perkins Research Conference on Advanced Reservoir Characterization for the 21st Century (1999, p. 213ndash232). Thanks to Art Saller, Gregor Eberli, and Mark Sonnenfeld for helping to refocus the manuscript with insightful suggestions.


South Dagger Draw (SDD) field, located in southeast New Mexico, produces hydrocarbons Previous HitfromNext Hit complex sigmoid-oblique clinoforms of the Pennsylvanian Canyon and Cisco Formations. South Dagger Draw field, a combination Previous HitstructuralNext Hit-stratigraphic trap, represents the northern extension of the Indian Basin field. Through February 2001, the Indian Basin and SDD fields together had produced nearly 23 million bbl of oil and 2 tcf of gas Previous HitfromNext Hit Marathon Oil Company-held acreage. Vuggy porosity, formed dominantly in algal biostromes and bioherms located at the ramp-margin position of each clinoform, represents the primary reservoir. Vugs were formed by acidic hydrothermal fluids that migrated upward along joints and were baffled beneath shales, resulting in dissolution zones that are controlled by the interplay between Previous HitstructuralNext Hit joints and stratigraphic shales and carbonates.

Previous HitDataNext Hit used in the study include logs, cores, modern wire-line log suites, borehole image logs, and three-dimensional (Previous Hit3-DNext Hit) acoustic impedance values Previous HitfromNext Hit Previous HitinversionNext Hit of Previous HitseismicNext Hit Previous HitdataNext Hit. Previous HitSeismicNext Hit Previous HitdataNext Hit provide interwell information helpful for determining the present-day structure of the field but not particularly useful for interpreting the stratigraphy. High-frequency sequence-stratigraphic interpretation, guided by a depositional model derived Previous HitfromNext Hit description of cores and outcrops, was accomplished using a necessary combination of well logs, cores, and Previous HitseismicNext Hit Previous HitdataNext Hit. The sequence-stratigraphic interpretation served as input for multiple iterative Previous HitseismicNext Hit inversions and provided the framework for the integrated Previous Hit3-DNext Hit geologic model.

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