Ehlig-Economides, Christine2019-09-182019-09-18May 20152015-05May 2015https://hdl.handle.net/10657/4844There are reported cases of hydraulically fractured shale wells that exhibit boundary dominated flow in a very short period. This study suggests that dissolution of salt-sealed natural fractures in the shale offers a novel explanation for the early boundary dominated flow. We first discuss a plausible diagenetic history for generation of a salt-sealed natural fracture system in shale gas and how core, log, and conventional test data may behave. We then note that flowback of water with significantly higher salinity than the injected fracture fluid may suggest that the injected low salinity fracturing fluid dissolved salts that sealed an existing natural fracture system. In this scenario, the effective permeability would represent that of the natural fracture system induced by salt dissolution, and the stimulated rock volume would be directly related to the leakoff volume. A simple material balance model tracks salt dissolution by leaked off fracturing fluid and estimates the resulting stimulated rock volume.application/pdfengThe author of this work is the copyright owner. UH Libraries and the Texas Digital Library have their permission to store and provide access to this work. Further transmission, reproduction, or presentation of this work is prohibited except with permission of the author(s).Fracture porositySRVDSRVDissolutionImbibitionSaltMaterial balance2019-09-18Thesisborn digital