fax 01-972-952-9435. AbstractProductivity of the well often declines rapidly as a result of fracture conductivity loss suffered by proppant flowback and high water cut. In wells with conventional frac-pack completions, sand control screens have often shown signs of damage caused by fines plugging, erosion, and/or corrosion. To combat the proppant and formation sand flowback problems, field trials of an on-the-fly coating curable-resin system were performed to determine whether this resin system is a viable option that can provide an effective means to establish screenless frac-pack completions in this field. This paper presents the results of these field trials involving the screenless frac-pack completions using an on-the-fly curable resin coating system. Detailed descriptions of the completion procedures, the challenges, and lessons learned during the course of these frac-pack treatments are presented.This study has determined that an optimum concentration of resin coating on the proppant is necessary to maximize the bonding between proppant grains and the consolidation strength of the coated proppant pack while minimizing any reduction of its conductivity. Field results indicate that this onthe-fly resin coating treatment effectively stopped the proppant and formation sand from producing back while maintaining the production rates as designed and has drastically decreased the number of workovers compared to the same wells left untreated. The technique provides a very attractive alternative to conventional frac-pack completions in wells with marginal reserves, eliminating the need for sandcontrol screens and providing access to other intervals when needed without wellbore restrictions.

Hydraulic fracturing is widely implemented in stimulation of unconventional reservoirs to unlock the hydrocarbon potential in ultra-low permeability formations. Fracture height growth is a critical parameter in unconventional reservoir to maximize the hydrocarbon productivity. The integrated vertical well interpretations from a case study of the pilot well demonstrates the effect of the vertical stress distribution which impacts fracture height growth. Geomechanical model of a pilot hole was constructed to provide vertical variation of mechanical properties and in-situ stresses. The calibrated geomechanical model has shown that Jubaila source rock has less stiff rock and lower stress than bounding formations. The geomechanical model of the vertical pilot well has shown the overlapping between the minimum horizontal stress and vertical stress in particular, depths restricts the fracture height growth and creates longer horizontal fracture. Pre-frac injection test was performed, analyzed, and integrated into the geomechanical model. Temperature log was performed to identify the fracture height growth and the results of the temperature log were proportional with the geomechanical model. 3D fracture simulation software was utilized to determine the hydraulic fracture properties. The created fracture simulation model was calibrated to the geomechanical model and temperature log interpretations. Furthermore, improving hydraulic fracture design depends on understanding the key parameters and lessons learned from the stimulated vertical well and the integrated process. This will help in selecting the landing point, redesign the completion strategy, and optimize the production in the future horizontal wells.

fax 01-972-952-9435. AbstractProductivity of the well often declines rapidly as a result of fracture conductivity loss suffered by proppant flowback and high water cut. In wells with conventional frac-pack completions, sand control screens have often shown signs of damage caused by fines plugging, erosion, and/or corrosion. To combat the proppant and formation sand flowback problems, field trials of an on-the-fly coating curable-resin system were performed to determine whether this resin system is a viable option that can provide an effective means to establish screenless frac-pack completions in this field. This paper presents the results of these field trials involving the screenless frac-pack completions using an on-the-fly curable resin coating system. Detailed descriptions of the completion procedures, the challenges, and lessons learned during the course of these frac-pack treatments are presented.This study has determined that an optimum concentration of resin coating on the proppant is necessary to maximize the bonding between proppant grains and the consolidation strength of the coated proppant pack while minimizing any reduction of its conductivity. Field results indicate that this onthe-fly resin coating treatment effectively stopped the proppant and formation sand from producing back while maintaining the production rates as designed and has drastically decreased the number of workovers compared to the same wells left untreated. The technique provides a very attractive alternative to conventional frac-pack completions in wells with marginal reserves, eliminating the need for sandcontrol screens and providing access to other intervals when needed without wellbore restrictions.