The effect of different fluid types and compositions on stress changes around fractured production wells has been studied in detail in this work. A compositional reservoir simulator which is fully coupled with geomechanics was used for this study. Both mechanical effects due to propped fractures and poroelastic effects due to production are considered while calculating stress changes. It was found that highly compressible, low viscosity fluids such as gases result in a lower stress reversal than lesser compressible fluids such as oils. For a volatile oil, the appearance of gas phase when pressure falls below the bubble point, reduces the stress reorientation as compared to not accounting for phase change and assuming a single hydrocarbon phase. The higher the fraction of the most volatile component, the lower is the resulting stress reversal. Similar conclusions are obtained for vertical wells with a single fracture and horizontal wells with multiple fractures. These findings highlight the importance of considering fluid type and composition while designing refracturing jobs based on the modified stress field due to prior production.
Effect of Fluid Type and Composition on Changes in Reservoir Stresses Due to Production: Implications for Refracturing
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Gala, Deepen P., and Mukul M. Sharma. "Effect of Fluid Type and Composition on Changes in Reservoir Stresses Due to Production: Implications for Refracturing." Paper presented at the 51st U.S. Rock Mechanics/Geomechanics Symposium, San Francisco, California, USA, June 2017.
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