In today's drive to improve well production, more innovative methods are continually being implmented to enhance well productivity and reservoir management. Remote monitoring and interactive control are two such methods that are more frequently employed to derive more value from wells. In Saudi Arabia, the world's first maximum reservoir contact (MRC) well, using Intelligent Well Systems and fiber-optic monitoring to maximize production performance was implemented. This paper discusses the implementation of remote monitoring and interactive control systems on Well-194, which was drilled as a tri-lateral MRC well with 4.2 km (2.61 mi) of total reservoir contact. The Intelligent Well System utilized feed-through production packers to isolate each of three laterals in the motherbore. Three remotely operated downhole chokes were installed to independently control flow from each lateral for the purpose of optimizing overall well production. This control extends the production plateau while maximizing reservoir drainage. The fiber-optic monitoring system enables remote monitoring of key production parameters, including pressure, temperature, total flow rate and water cut from each of the laterals, used to determine optimum downhole choke settings. Finally, the well was implemented as "ESP Ready" with 7″ tubing and a Deep-Set SCSSV to enable subsequent installation of a thru-tubing ESP to further improve production. Ultimately, this configuration resulted in a well capable of producing at a very high rate with low drawdown for an extended period of time. This strategy will result in a long-term sustained rate while optimizing the reservoir drainage process. This paper will review the lessons learned and key issues around implementing this type of "Next Generation" well completion system. MRC Well Overview The definition and benefits of MRC wells have been well defined1, however for the purpose of this paper a short description and application of this technology is important. In lower permeability carbonate facies environments, significantly extending wellbore reservoir contact yields significant enhancements in the well's Productivity Index. The length a single horizontal lateral can be drilled is limited by drilling constraints such as Torque and Drag as well as productivity issues around flowing back, cleaning up and getting significant production from excessively long horizontal wells. Multi-Lateral technology has been utilized to extend reservoir contact while not exceeding drilling and production constraints. Typically a MRC well consists of three or four single open hole laterals drilled from a single "Motherbore". Naturally, each single lateral acts as a single well with variances in permeability and productivity identified from lateral to lateral. Intelligent Well Systems can be installed in the motherbore of an MRC well to mitigate the risk associated from variances in reservoir parameters that can lead to early water breakthrough and poor ultimate recovery. In the case of Well - 194, the Intelligent Well System consisted of three separate downhole valves and monitoring stations that independently monitored the production rate and water cut from each lateral and then enables remote isolation of each lateral without intervention. (See Figure 1)

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Over the past few years, Saudi Aramco has had major efficiency improvements while drilling and completing smaller diameter hole sections. Such improvements provided significant reductions in rig time, and consequently reduced the overall operational cost. Less attention was paid to the upper hole sections due to less exposure to third party rental tools used in them. Offshore oil wells in Saudi Aramco have recently gone through major savings in the 28"/22" hole section after the successful utilization of the new Gyro measurement while drilling (MWD) technology coupled with powerful, performance drilling mud motors.The normal process was to drill the 22" hole section, 1,050 ft +/-, running Gyro single-shot surveys every 50 ft -100 ft drilled, until the well is drilled in a safe path away from other wells within its vicinity. After adopting the Gyro-MWD system, along with a modified 22" bit and 11¼" performance mud motor, the rate of penetration (ROP) increased by 82%; Thus, reducing CPF respectively.The increase in the ROP resulted in average savings of 0.9 days per well (6 to 12 wells per platform) at this stage of the well. In addition, the reliability of the gyro tool face from vertical, even when inside the casing, provided confidence in drilling operations, which facilitated the increase of weight on bit (WOB), leading to faster drilling, thereby improving the overall ROP. Furthermore, eliminating the use of wireline to run surveys increased the safety of the operation.The success of these 22" hole sections was substantial across the board, since it was one of the challenging areas where major improvements had not taken place before for years. This paper will evaluate the new drilling practice in more detail. It will also cover the conventional drilling and operational practices, and the thorough planning stages that resulted in these fruitful savings.Coordinator. He began working in 1978 in the offshore drilling industry in various positions, ultimately as a night tool pusher. Jeff has worked in the field, principally in Saudi Arabia and previously in Oman, and is currently a Directional Drilling Coordinator with primary responsibility for offshore operations with Saudi Aramco.