Horizontal drilling accompanied with Hydraulic fracturing makes the unconventional reservoir a viable addition to worldwide production. Hydraulic fracturing of a well is the largest cost when evaluating total well expense. Therefore, understanding the fracture performance is fundamental to the success of a shale well. The two main factors controlling a shale horizontal wells performance is completion design and reservoir quality. The completion efficiency depends on factors such as well spacing, stage spacing, cluster spacing, fluid volume, proppant type and volume, injection rate, type of fracture fluid and gas price. There are many techniques used to evaluate the hydraulic fracture performance. Some include post fracture analysis, tracer analysis, micro seismic analysis, rate transient analysis, production log analysis, fiber optics data and pressure transient analysis. This paper presents the integration of completion data, petrophysical data, fluid sample analysis, mini-frac analysis, and flowback data in matching long term buildup data. More than 6 months of data was collected for one of the unique shale gas condensate wells during the appraisal stage of an area. The analysis showed the effect of liquid drop out and phase segregation in the flow regimes. Also, this paper presents a different analytical model used to match the actual buildup data. The resulting model is used in building a reservoir model to forecast performance for the well.

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Determining log-based water saturation using Archie's (1942) equation, or any derivative shaly sand method, requires correct inputs to produce valid results. In resource plays, the rock matrix is composed of water wet and oil wet constituents, therefore, correct values of Archie's cementation factor (m) and saturation exponent (n) are critical. In practice, it is pragmatic to use the Pickett plot (Pickett, 1973) to set connate water resistivity (Rw) and Archie's ‘m’. However, it is difficult, if not impossible, to derive Archie's ‘n’ parameter without additional information. Research combining core and log data shows evidence of a positive correlation between Archie's saturation exponent and the total organic content (TOC) in a given unit volume. Using this relationship, Archie's equation may be used to define a variable ‘n’. It is hypothesized that ‘n’ increases with increasing TOC volume as a result of an interruption of electrical pathways that resistivity tools exploit. This disruption results in an increase in the apparent value of ‘n’ required to compute correct water saturations. Due to the apparent excess resistivity in organic-rich rocks, an increase in ‘n’ values or kerogen corrected resistivity is needed to produce a fit to core-derived water saturations. This article will demonstrate the methodology used to derive a variable ‘n’ parameter and kerogen corrected resistivity in an organic-rich interval.