Understanding and Predicting Fayetteville Shale Gas Production Through Integrated Seismic-to-Simulation Reservoir Characterization Workflow

Abstract

Abstract This paper describes a comprehensive workflow that incorporates geologic, seismic, and production data in an effort to understand and predict the performance of gas wells in the Fayetteville Shale play. A reservoir model was developed by integration of all available well, log, petrophysical, sonic, image, core, stimulation, production, microseismic and processed surface seismic data. This static reservoir model was used to history match the short- and long-term production performance and its variations across the exploration area. History matching production profile from multiple wells is a critical step toward understanding the key production drivers in unconventional shale gas formations. This workflow involves extensive use of surface seismic to develop a velocity model and to distribute reservoir properties. This paper highlights the multidisciplinary knowledge that was applied in the project and the lessons learned. The reservoir characterization and dual-porosity simulation model developed was used to predict production performance of future wells in the Fayetteville Shale formation. Key production drivers—such as matrix quality, natural fractures, net gas porosity—and ways to identify and exploit these parameters during the development phase of the reservoir are discussed. The ability of the models to predict production performance is also discussed. This workflow is useful in selecting drilling locations, identifying best landing points, optimizing well spacing, and guiding completion practices.