Operators are continuously striving to improve oil and gas field development strategies. One of the major improvements in field development strategies is enhancement of well completion designs that maximize profitability while maintaining high standards of reservoir management. Completion strategies have been transforming over the years from conventional wells to the recently drilled multilateral (ML) wells and smart wells that combine inflow control devices (ICDs) and electrical submersible pump (ESP) equipment. The new era of intelligent wells is focused on over-performing the old completion practices in terms of well productivity and reservoir sweep efficiency. Well-A was trial tested for the first time in an offshore field by deploying a hydraulic line wet mate (HLWM) connect system with the intelligent completion (IC). This tool allows de-completing the upper completion, which includes an encapsulated (pod) ESP portion, without the need to de-complete the lower intelligent completion. The completion operation of this well consists of two stages: the first stage consists of completing the well with the intelligent completion, HLWM connect tool and a production packer. The second stage is performed by pulling the production packer by disconnecting at the HLWM point and consequently running the ESP completion while maintaining the integrity of the lower intelligent well completion in place. The completion operation in Well-A was run in two stages only to trial test the reliability of the HLWM connect system in this field, since it was utilized for the first time. In subsequent wells, the intelligent completion can be run in one stage with the ESP integrated as part of the final completion design. A production optimization sequence utilizing a simulation model was used to analyze the potential of the well and selecting the right inflow control valve (ICV) settings from the two laterals for optimum reservoir drainage.

A study was undertaken to evaluate the production performance/potential of horizontal wells equipped with inflow control devices (ICDs) in an offshore oil field in Saudi Arabia. Several challenges are associated with the optimum ICD completion design in this field due to the reservoir sequence of the thick sandstone with thin layers of shale, siltstone and limestone. The sand members are unconsolidated, which poses potential issues with fine migration for screen plugging. An additional challenge to the completion design is the practice of long open hole (OH) horizontal sections, normally drilled with net pay in the range of 3,000-4,000 ft MD with oil based mud (OBM). The reservoir has very good permeability and the high permeability streaks pose a threat of acute water production early in the life of the wells.Many representative wells were analyzed by constructing a calibrated ICD model based on their actual completion characteristics with ICD completion and the reservoir parameters of each well. The calibrated model was used to match the wells' production logging measurements profile and analyze future performance based on potential enhancements in the completion design. Results showed that using a nozzle based ICD instead of a helical ICD design for the same influx profile in these wells caused a reduction in the pressure drop across the completion. The use of additional isolation packers in the ICD sections has the potential to improve the influx balance profile by creating more compartmentalization in the long OH horizontal sections. These findings are taken under consideration for optimizing the completion practices in the future development of the field.

fax 01-972-952-9435. AbstractSeveral innovative techniques and practices have been recently implemented to improve well production performance in offshore assets in the Arabian Gulf. The challenges which followed past practices were identified and intensive work was focused on enhancements to existing well completions to increase well productivity and prevent premature water or gas encroachment.

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractIn an effort to improve well production performance targeting recent increases in oil demand, Saudi Aramco implemented several innovative technologies and practices in its offshore assets in the Arabian Gulf. The identified challenges which followed past practices were focused on enhancements to existing well completions, chemical treatments of damaged wells, implementation of Smart field technologies and early detection of casing leaks to enhance wellbore integrity and meet environmental standards. This paper describes the methodologies of four technologies which were tested and implemented in three major offshore fields in Saudi Aramco. These technologies are the use of passive inflow screens combined with swellable packers in horizontal sidetracked wells to prevent premature water or gas encroachment, smart in-situ gas lift completion which utilizes the reservoir gas cap for artificial lift of oil wells, the chemical treatment of wells which endured formation damage and the utilization of a modified ultrasonic tool for early casing leak detection in aged wells equipped with up-hole packers.

Recent evolution in oil field technologies has made a great revolution in the oil and gas industry all over the world leading to the emerging development of intelligent fields (I-Fields)1, 2, 3, 4. The integration of I-Field technologies whether downhole or at surface, coupled with communication networks along with sophisticated simulation and monitoring applications has lead to significant advancements not only in monitoring and control capabilities, but rather also in decision making processes5. Therefore, the overall system upgrade has resulted in an enhancement of the field surveillance, which will lead to higher levels of oil production in these assets as a consequence of Saudi Aramco's development strategy for these fields. A comprehensive redevelopment and I-Field transformation of three elderly remote onshore oil fields in Saudi Arabia has taken place where extensive drilling and workover programs have been reinitiated to complete both oil production and peripheral water injection wells, and equip them with the latest downhole production technologies. The project has also involved construction of new oil and gas processing and water injection facilities, which are being linked with the wells via a state of the art fiber optic communication network for controlling both subsurface and surface parameters and data surveillance in real-time. Further integration of I-Field components, such as Permanent Downhole Monitoring Systems (PDHMS), Smart Well Systems, Multiphase Flow Meters (MPFM), Single Phase Flow Meters, pressure and temperature sensors with specially tailored monitoring, and simulation software has facilitated the development and implementation of optimized production and injection strategies. This paper will discuss the development strategy of the three fields sharing the lessons learned from this project. Moreover, examples, such as well performance monitoring and validation, crude blend assessment and assurance and reservoir pressure mapping, which are all being performed in real-time will be presented. In addition, this paper will also illustrate how the integration of I-Field components has effectively helped in optimizing the production from a portfolio of developed reservoirs.