Dual-viscosity fluid is a fracturing fluid that has been recently introduced to cover a wide range of fracturing applications varying, from a non-delayed to delayed fluid system for treatments in low to moderate to high temperatures, respectively. Reducing the impact of the pressure effect of traditional borate cross-linked systems, the system crosslinker is compact and delivers a relatively high concentration of crosslinker per unit volume; it is also compatible with current metering pumps, covering a range of treatment rates compared to the current fluid system, and this can simplify logistics on location. The North Bahariya oil fields are onshore fields located in the Western Desert of Egypt and operated by Sahara Oil and Gas Company (SOG). The fields contain proven oil reserves in two sandstone packages at relatively shallow drilling depths (6,500 ft. subsea) in the Abu Roash "G" member (A/R G) of Cenomanian (Cretaceous) age. These sandstones comprise the main reservoirs in the field. During the last 4 years, the introduction of various techniques has led to a fourfold increase in the production from these fields. This success story is mainly the result of using the new hydraulic fracturing methods such as channel fracturing technique and continuous improvement of the fracturing treatments. SOG has been at the forefront in applying novel technologies to optimize the fracturing fluid treatment by using the dual-viscosity fracturing fluid to improve the wells potential. This technology has been implemented in Abrar field. As seen in case studies, very positive results have been seen in both zones of the A/R G formation in terms of improvement in the well performance. Experiences in Abrar field illustrate how to optimize the production rate in a marginal field by optimizing the hydraulic fracturing treatment fluid and how to build on this success for subsequent fields while pushing the innovation envelope further.

No doubt that facies modelling process is a key process during building the static model which dominates all the petrophysical distribution after that. One of the best way to describe the facies change laterally across the reservoir is seismic attributes interpretation. However; unfortunately seismic attribute doesn't show accurate results in Western Desert in Egypt mostly because the reservoirs thickness is relative small.Several trials on seismic attributes were performed during performing a study on West Qarun field which is located in Abu El-Gharadig basin, Western Desert, Egypt but without reaching conclusive results. West Qarun wells are producing mainly from Middle Abu Rawash "G", and Lower Abu Rawash "G" reservoirs which their thickness ranges from 30 to 60 ft. This paper presents another approach that was utilized to create facies log for each well integrating the petrophysical interpretation output and the core data as well. After that a thickness map for each facies per each reservoir was created. The resulted maps were utilized for facies model creation and consequently dominated the petrophysical properties distribution: porosity, permeability, and initial water saturation.Permeability-Porosity relationship was described as a function of flow zone indicator (FZI) considering the distributed facies model. Defining FZI range for each facies type yields to more accurate reservoir characterization and prevents usage of unreliable permeability multipliers during history match process.In spite of the absence of seismic attributes conclusive results, the resultant model showed excellent results during dynamic model in terms of production potential of different areas of the reservoir and the connectivity between different wells. The model showed good well by well match, total field match specially the ongoing pilot water injection project and also helped in planning the complete water injection project.