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Challenges associated in developing mature offshore fields of Saudi Arabia require the optimal integration of best reservoir management practices. Such complicated fields require effective collaboration between reservoir engineers and geoscientists for the application of latest technologies and best practices. A variety of practices were implemented to achieve significant improvements in drilling and completing horizontal wells. Some of these challenges have been addressed with the installation of over 200 inflow control devices (ICD) which are used to minimize water coning and gas cusping affects. Economic development of these offshore projects have involved the implementation of 20 Smart wells, in conjunction with, intelligent field monitoring that improves surveillance and reduces manpower requirements. Real-time geo-steering practices, advanced logging measurements, and seismic imaging techniques were successfully utilized for well placement of over 100 horizontal wells in a geologically complex sandstone environment. Also discussed are some future fit-for-purpose technologies that are being considered for these offshore field development projects. Introduction The developed offshore fields (M, Z and S) of Saudi Arabia are located in the Arabian Gulf and consist of sandstones, siltstones and shales with minor limestones and coals deposited in a complex, fluvial dominated delta system. The main producing reservoirs consist of massive, clean highly permeable 1-5 Darcy sandstone units interspersed with shales. The primary drive mechanisms for all three fields results from natural aquifer influx with limited support from gas cap expansion in two fields. Table-1 shows some reservoir characteristics and completion type. Historically, all wells drilled in these fields have been free flowed to the surface without any artificial lift. Recently, one of the fields installed a number of electrical submersible pumps (ESPs) to increase well productivity. For other wells that cease to flow at high water cut, a drilling program has been undertaken to convert these vertical wells to horizontal wells with passive inflow control devices (ICDs). Horizontal wells were introduced in the early nineties in all Saudi Arabian offshore fields to sustain production targets. Before 2003, most horizontal wells drilled in the sandstone offshore reservoirs were completed as cemented and perforated liners completions. After 2003, many of the new horizontal wells began using ICDs to improve production profile along the horizontal lateral section. These new completions increase the distance to the oil water contact (OWC), reduce water coning tendencies, and extend the life of the well. Additionally, for those those wells located in fields with a central gas cap dome area, Smart in-situ gas lift technology is available to increase production and further extend well life. The objective of this paper is to share the best reservoir management practices and strategies to meet challenges associated in developing mature offshore fields of Saudi Arabia.

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Drag reducing agents (DRA) are commonly used in the industry to increase pipelines' throughput by reducing the frictional pressure drop along the pipeline segment. The application of DRA has been primarily for single phase flow; however, a multiphase DRA was introduced and trial tested in an offshore gas-oil separation plant (GOSP) in Saudi Arabia to maximize the production of heavy oil from the GOSP without the need to flare the excess produced gas. This initiative was considered to avoid a major GOSP upgrade.

The combination of two new technologies - a production equalizer system combined with in-situ gas lift or electric submersible pumps (ESP) _ have been successfully implemented in Saudi Aramco offshore oil fields to optimize well rate and recovery. Merging these technologies has allowed Saudi Aramco optimal completion methods to exploit the remaining reserves from both Khafji and Safaniyah sandstone reservoirs. This paper describes the benefits of integrating production equalizer technology with artificial lift (Insitu gas lift or ESP) to optimize production, delay water /gas coning, ensure uniform inflow, and prolong well life. A case history from Saudi Aramco will be presented, where these integrated technologies resulted in significant saving for the operator, and improved production performance in horizontal offshore oil wells. Background The offshore fields in Saudi Arabia are sandstone reservoirs with good petrophysical properties. These fields have been producing since the mid-fifties, and the production mechanism is a strong water drive. Natural depletion and proximity of the water created a new challenge for sustained production. Horizontal wells were introduced in the early nineties to sustain production target. Prior to 2003, most horizontal wells drilled in the sandstone offshore reservoirs were completed as cemented and perforated liner completions. This method proved to be less then optimal as only a small fraction of the net pay encountered produced resulting in early water or gas arrival leaving many reserves behind. The introduction of a uniform control device along with mechanical openhole packers provided a cost effective method to equalize the inflow from the entire horizontal section, increasing well PI and prolonging well life. Completion Selection Case histories showed that early water breakthrough from cemented and perforated completions resulted in a severe drop in the individual well productivity. The early water breakthrough was associated with poor inflow profiles caused by permeability variations and formation damage from perforating.