Impact of Shrinking Fracture Length and Decreasing Fracture Conductivity on Bottom-Hole Pressure Performance: A Semi-Analytical Model to Characterize Waterflood-Induced Fracture Around Water Injection Well
- Y. Wang (China University of Petroleum Beijing) | S. Cheng (China University of Petroleum Beijing) | K. Zhang (Lusheng Petroleum Development Co. Ltd SINOPEC Shengli Oilfield Company) | L. F. Ayala H. (Pennsylvania State University) | J. Qin (China University of Petroleum Beijing) | Y. He (China University of Petroleum Beijing)
- Document ID
- Society of Petroleum Engineers
- SPE Western Regional Meeting, 22-26 April, Garden Grove, California, USA
- Publication Date
- Document Type
- Conference Paper
- 2018. Society of Petroleum Engineers
- 2.5.2 Fracturing Materials (Fluids, Proppant), 2 Well completion, 5.4.1 Waterflooding, 2.4 Hydraulic Fracturing, 5 Reservoir Desciption & Dynamics, 5.4 Improved and Enhanced Recovery, 3 Production and Well Operations, 3 Production and Well Operations
- waterflood-induced fracture, fracture-storage effect, pressure-transient analysis, shrinking fracture length, variable fracture conductivity
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There is growing evidence showing that water injection may induce formation fracturing around injectors in tight reservoirs. Because waterflood-induced fractures (WIFs) are not strengthed by proppants, they close gradually during the field-testing period, which results in "fracture-closure-induced" flow rate, shrinking fracture length (SFL) and decreasing fracture conductivity (DFC). In this paper, we propose a novel semi-analytical model to characterize the BHP behavior of water injectors under the influence of WIF. We consider that pressure losses take place within three sections: reservoir, WIF and wellbore. Flows between reservoir and WIF are linked through a fracture-storage coefficient and fracture-face skin factor, while flows between WIF and wellbore are coupled via wellbore-storage coefficient and choked-fracture skin factor. Finite difference and perturbation theory methods are deployed to include the SFL and DFC effects, respectively. Duhamel principle is invoked to characterize flow rate changes caused by wellbore and fracture storage effects. Results show that bi-storage effects can be identified as two unit slopes in the pressure derivative curve. In the abscense of extra pressure drop between wellbore and WIF, i.e., choked-fracture skin equals to zero, a prolonged storage period with a considerably large storage coefficient can be obtained. In addition, we find that SFL could cause the variable fracture storage effect while DFC may lead to the upward of pressure derivative curve at late times. Finally, the model is successfully applied in the Changqing Oilfield to validate its reliability.
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