Pressure Transient Analysis for Sandstone Reservoir by Using Saphir

Abstract

This work is discussed how to differentiate between two tricky models for sand stone formation by using the pressure transient analysis PTA for three Wells which are distributed in south, middle and north of X field. In the derivative curve these two models have the same sequence of flow regime which are by hump, first radial flow regime, transition hump and then late radial flow regime. The parameter Kappa (K) played the most important key to select the type of reservoir model and differentiate between the two models in PTA. In the middle and south of the field, this parameter has a value close to one at well no. Rt-16 & Rt-18, which means that the system behaves as dual porosity. On the other hand, Kappa has a value of around (0.74) in Rt-17 to represent a double permeability system but without cross flow between two layers due to the small value of Lamda.

Identifying Average Reservoir Pressure in Multilayered Oil Wells Using Selective Inflow Performance (SIP) Method

“…Layered reservoirs are usually divided into two parts; First, layered formation with cross-flow, where layers communicate at contact planes throughout the reservoir. Second, layered reservoir without cross flow (commingled system) where layers are communicated only through well-bore (which is our case) [2]. In most multi-reservoirs, individual productive layers usually develop different thicknesses, porosity, permeability, skin factor, and average pressure.…”