Tactics for Use of Diagnostic Fracture Injection Tests in Unconventional Reservoirs

Fig. 1—Typical DFIT pressure response.

To achieve optimal production from unconventional reservoirs, it is useful to determine the permeability, pore pressure, and state of stress of rock strata. An effective way to derive this information is to conduct in-situ pressure-transient tests. Because injecting fluid into or withdrawing fluid from the pore network of tight rock is difficult, diagnostic fracture injection tests (DFITs) have been used to create an analyzable pressure-decline response and to derive the minimum horizontal stress through fracture-closure identification.


Well testing is the technique of establishing fluid flow in the reservoir by ­either producing from or injecting into a well and then changing or terminating the flow rate to create a transient event, usually by shutting in the well at the surface. The resulting wellbore-pressure response is then evaluated to derive reservoir properties, such as transmissibility and initial reservoir pressure.

Creating a hydraulic fracture bypasses wellbore damage and near-wellbore stress concentrations and connects the wellbore to a significant portion of the reservoir-layer thickness, enabling a representative investigation of reservoir properties.

This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE 163863, “Diagnostic-Fracture-Injection-Testing Tactics in Unconventional Reservoirs,” by D.D. Cramer, SPE, and D.H. Nguyen, SPE, ConocoPhillips, prepared for the 2013 SPE Hydraulic Fracturing Technology Conference, The Woodlands, Texas, USA, 4–6 February. The paper has not been peer reviewed.
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Tactics for Use of Diagnostic Fracture Injection Tests in Unconventional Reservoirs

01 February 2015

Volume: 67 | Issue: 2


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