石油工程师协会技术年会论文spe166120石油工程师协会技术年会论文spe166120.pdfVIP

SPE 166120 Modeling Wellbore Transient Fluid-Temperature and -Pressure During Diagnostic Fracture Injection Testing in Unconventional Reservoirs B. Nojabaei, SPE, Penn State U., A.R. Hasan, SPE, Texas AM University, and C.S. Kabir, SPE, Hess Corp Copyright 2013, Society of Petroleum Engineers This paper was prepared for presentation at the SPE Annual Technical Conference and Exhibition held in New Orleans, Louisiana, USA, 30 September–2 October 2013. This paper was selected for presentation by an SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of SPE copyright. Abstract Diagnostic fracture injection testing or DFIT has gained widespread usage in the evaluation of unconventional reservoirs. The DFIT entails injection of water above the formation-parting pressure, followed by a long-duration pressure falloff test. This test is a pragmatic way of gaining critical reservoir information, such as the formation-parting pressure, fracture-closure pressure, and initial-reservoir pressure, leading to fracture-completion design and reservoir-engineering calculations. In typical field operations, pressure is measured at the wellhead, not at the bottomhole, because of cost considerations. The bottomhole pressure (BHP) is obtained by simply adding a constant hydrostatic head of the water column to the wellhead pressure (