ABSTRACT
Traditionally, hydraulic stimulation treatments were assessed using their pressure response during and post treatment (Economides, Nolte, and Ahmed 1998). Although robust, these methods are based on the interpretation of pressure curves that have limited resolution of the inverse problem of characterizing fractures. It is desirable to add other engineering tools that can help understanding the behavior of the stimulation, both during and after the treatment has been undertaken. It would be beneficial to gather information away from the wellbore. Microseismic monitoring, permanent downhole inflow tracer monitoring technology, and fiber optic monitoring can constrain the outcomes of stimulation and compare it to the modeled fracture. In the following sections each of the three techniques is discussed with field application case studies (Ahmed et al. 2015).
