Abstract: Subsurface Integration of Drill Stem Test Information in the Rocky Mountain Region Provides Low Cost Analysis of Regional Reservoir Parameters
FORSTER, JOHN R, and MARY McGEE FORSTER
Recent improvements in computer hardware and software are changing the way the Oil and Gas explorationists find and develop hydrocarbon reserves. One change is in the integration of multiple data sets for the purpose of subsurface mapping. Integration of stratigraphy from well logs and seismic data, with other subsurface information such as core, drill stem test, stimulation, and completion data is leading to a new, highly sophisticated understanding of hydrocarbon deposits. Drill Stem Test data integration will be one of the keys to the new generation of subsurface maps.
Traditionally, DST data are used to determine reservoir extent and fluid type. Conventional techniques show individual well or field level reservoir parameters. Rarely are these data applied to determine regional reservoir parameters. However, with the vast amount of DST data available and the ability to process this data with current, computer technologies, regional subsurface reservoir parameters can be mapped from DST data.
Regional mapping of individual fluids or the distribution of related fluids are useful. Mapping an individual fluid like black sulfur water in the Williston Basin shows local reservoir variations. Canadian Hunter used regional fluid sequences in Alberta to define the deep basin gas play at Elmworth Field. Similarly, in the Powder River Basin, Wyoming, large hydrocarbon saturated areas can be mapped in many of the Cretaceous producing zones. Through filtering the database to obtain reliable pressures, regional pressure maps can be generated. Shut in pressures in the Muddy Formation, show multiple isolated pressure cells related to local stratigraphic variations and known fracture breeds.
AAPG Search and Discovery Article #90946©1997 AAPG Rocky Mountain Section Meeting, Denver, Colorado