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Numerical Investigation of Transient Flow Responses in Fractured Tight Oil Wells Open Access


Other title
Numerical Investigation
Transient Flow
Type of item
Degree grantor
University of Alberta
Author or creator
Yue, Min
Supervisor and department
Leung, Juliana (Civil and Environmental Engineering)
Dehghanpour, Hassan (Civil and Environmental Engineering)
Examining committee member and department
She, Yuntong (Civil and Environmental Engineering)
Dehghanpour, Hassan (Civil and Environmental Engineering)
Leung, Juliana (Civil and Environmental Engineering)
Nouri, Alireza (Civil and Environmental Engineering)
Department of Civil and Environmental Engineering
Petroleum Engineering
Date accepted
Graduation date
Master of Science
Degree level
Increasing demand of global energy and limited conventional resources force the petroleum industry to shift their focus towards the low permeability reservoirs such as shale or tight rock reservoir. Multi-fractured horizontal wells have economically unlocked the massive hydrocarbon resources from unconventional reservoirs. Horizontal drilling and hydraulic fracturing create a complex fracture network that could enhance reservoir contact area to achieve economic production rates. In this study, we compute the transient response in a segment of a hydraulically fractured horizontal well using a triple-porosity model. Impacts of capillary discontinuity (fracture face-effect) and some limitations in analytical models such as sequential flow, single-phase flow and fully-connected symmetric fractures are investigated. We find that the uncertainty in model history-matched parameters and assumptions associated with analytical models could potentially over- or under-estimate production by up to 30%. History-matching with analytical models alone and the assumption of uniformly-spaced fracture stages would tend to overestimate long-term production forecast. In contrast, the assumption of no solution gas in tight oil reservoir leads to underestimation of reservoir properties such as length of fracture and permeability. Moreover, the simulated production data indicates that fracture face-effect results in rapid production decline. Lower capillary contrast between fracture and matrix results in less water blockage and higher production.  
This thesis is made available by the University of Alberta Libraries with permission of the copyright owner solely for the purpose of private, scholarly or scientific research. This thesis, or any portion thereof, may not otherwise be copied or reproduced without the written consent of the copyright owner, except to the extent permitted by Canadian copyright law.
Citation for previous publication
Yue, M., Leung, J., Dehghanpour, H. 2013. Integration of numerical simulations for uncertainty analysis of transient flow responses in heterogeneous tight reservoirs. In SPE Unconventional Resources Conference Canada. Society of Petroleum Engineers. doi:10.2118/167174-MSYue, M., Leung, J. Y., and Dehghanpour, H. 2016. Numerical Investigation of Limitations and Assumptions of Analytical Transient Flow Models in Tight Oil Reservoirs. Journal of Natural Gas Science and Engineering. doi:10.1016/j.jngse.2016.01.042

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