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Analyzing post-flowback production data suggest oil drainage from limited stimulated reservoir volume: An Eagle Ford shale-oil case
International Journal of Coal Geology ( IF 5.692 ) Pub Date : 2020-04-02 , DOI: 10.1016/j.coal.2020.103469
Sabbir Hossain; Obinna D. Ezulike; Hassan Dehghanpour

This study conducts qualitative and quantitative analysis of flowback and post-flowback production data from six multi-fractured horizontal wells completed in Eagle Ford shale formation. Petrophysical analysis of samples from the target shale shows oil window with type II kerogen. We analyzed two groups of wells with different well-completion and operational parameters. Wells fractured with slickwater, with higher total injected volume (TIV) and larger choke size show higher initial oil rate, but faster pressure depletion compared with the wells fractured with cross-linked gel, with lower TIV and smaller choke size. Both groups show supercharged fractures when flowback starts and reservoir pressure remains above bubble point during post-flowback production. Interestingly, rate-normalized pressure plots of oil and water from both groups during post-flowback production show pronounced unit slope indicating boundary dominated flow (BDF), while this trend is not observed during flowback period. Analyses of rate-normalized pressure and rate-decline data suggest that both oil and water are produced from a closed tank under BDF conditions. We propose a multiphase flowing material balance (FMB) model to describe water and oil production from stimulated pore volume (SPV) during post-flowback period. The proposed FMB model assumes negligible oil and water influx into the stimulated region. The driving forces considered are closure of fractures and expansion of oil and water in SPV. Model application on post-flowback data confirms that after fracture depletion, oil is produced from highly stimulated matrix around hydraulic fractures while water is mainly produced from fractures.
更新日期:2020-04-21

 

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