HSP was used for all completions in the Barik sandstone. Production analyses showed better production from stages receiving larger proppant concentrations and achieving higher dimensionless fracture conductivity.
Hydraulic fracturing has been an integral part of the development of two gas/condensate fields in Oman. The producing reservoirs are quite thick (160-190 m) and highly laminated, so fracture height growth and vertical coverage are key issues. High production rates and condensate production also mean that non-Darcy flow in the fracture is important. There are significant variations in permeability and depletion (following several years of production) within the reservoir, which makes any analysis more complicated. There has been an evolution in the fracturing strategy in terms of the number of treatments pumped per well (going from 1 to 5 fractures), the size of proppant used (12/20, 16/30, 20/40) and the size of the pad volume (75 - 350 m 3).
Questions existed about the performance of the fracture stimulation treatments, particularly about whether the effectiveness of the fracture stimulations was decreasing over time, as one performance indicator showed. In order to answer these questions, a study was performed to evaluate the individual fracture performance based on the post-frac production logging data (PLT) which gave a production rate for each fracture in the well.
Author(s): Josef R. Shaoul, Pinnacle Technologies; C.J. de Pater, Delft U. of Technology; Mahmoud Al-Hashmi, Petroleum Development Oman; Robert A. Langedijk, Shell Todd Oil Services Ltd.
Paper Number: SPE82209