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The AAPG/Datapages Combined Publications Database
Houston Geological Society Bulletin
Abstract
Abstract: Modern Analytical Techniques for Fault Surface
Seal
Analysis:
A Gulf Coast Case History
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By
1Marathon Oil Company, Lafayette
2Department of Geology, University of Southwestern Louisiana, Lafayette
Today's exploration and, particularly, exploitation methods, with a major reliance placed on mapping with 3-D seismic data, generate a great deal of potential information about prospective reservoirs. Effective prospect evaluation requires consideration of the sealing characteristics of faults, and techniques have been developed to improve fault surface analysis. "Allen" fault surface profiles permit assessment of sand juxtaposition across the fault, and can be prepared by manual mapping methods if adequate structural maps are available from 3-D seismic interpretation and well control. Commercial software is available to perform similar analyses directly from the 3-D seismic interpretation.
Vermilion Block 331 Field, operated by
Marathon, was selected for a pilot study.
The field consists of a low-relief anticline,
downthrown to a regional growth fault.
Numerous small faults, with limited vertical
separation, cross the crest of the anticline
and compartmentalize reservoir sands
of Trimosina A (Pleistocene), Angulogerina
B (Pleistocene), and Lenticulina (Miocene)
age. Faulted reservoirs with multiple,
stacked sands are particularly prone to loss
of hydrocarbons by leakage across fault
surfaces, so that this field was considered
ideal for testing the effectiveness of fault
surface analysis. Both lateral and top seal
risk were evaluated by means of fault surface
profiles along five of the crestal faults
to determine the limits of trapping potential
and paths for vertical migration. A
detailed review of actual hydrocarbon distribution
was then compared with the predictions
made from fault surface analysis.
70% of a total of 83 predicted hydrocarbon/water
contacts were found to be correct
within 10 meters (30 feet).
The role of faults in permitting up-fault migration along the fracture surface, or in providing shale smear barriers to cross-fault migration from sand to sand, may confound interpretations based only on fault surface profile geometries. For this reason, shale smear factors were also determined and used in assessing trapping potentials. A critical value of shale smear factor appropriate for this field was found empirically to be between 1.85 and 2.0. Capillary-limited cross-fault migration was blocked in all cases where the value was lower than critical, while spill point-limited traps occur where values are above critical. This analysis explained all the remaining discrepancies between predicted and actual hydrocarbon/water contacts mentioned in the preceding paragraph.
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