Interval Control Valves ICVs and Inflow Control Devices ICDs can enable optimization of the production and injection profile along the wellbore. The ICV devices are operated to increase the hydrocarbon recovery and prevent unwanted fluid production. The ICDs are selected and positioned to optimize the water flood profile. Although the operations of devices are well understood, the optimization of these devices in-situ is complex. The real-time monitoring of fluid flow along the wellbore can provide valuable information to set the position of the inflow devices and optimize the fluid flow in multilateral zones. The intelligent Distributed Acoustic Sensor (iDAS) uniquely allows the simultaneous recording of acoustic energy along many kilometers of optical fiber deployed along the wellbore. The system uses a novel digital optoelectronics detection technique that captures the amplitude and phase of the acoustic waves generated and propagated along the wellbore over a wide frequency (1mHz – 100kHz) range with a high dynamic range (>120dB). A number of signal processing techniques have been developed for processing a large array of acoustic data that can be recorded along the wellbore for monitoring the inflow at different zones. The iDAS system can be used with single-mode as well as multimode optical fibers. The iDAS system was retrofitted to existing optical fibers that were already installed along several wells in Saudi Arabia. The acoustic noise energy generated across the inflow devices and propagating along the wellbore tubing was recorded. The acoustic noise spectrum can be used to monitor the fluid flow through the inflow devices. Using array processing, the speed of sound can be determined over several sections of the tubing to identify the fluid composition. This paper reports on the results of the field trial carried in 2012 in several wells equipped with inflow devices.

The energy industry continues to explore innovative technologies and measurement methods. Well completions have become even more complex today: many wells have multizone production capabilities and are equipped with advanced control devices, such as inflow control valves (ICVs). An even flow distribution can be achieved by controlling the zonal flow rates with the end result being more efficient production and longer lifetime of the well. One of the requirements to achieve this level of production optimization is to monitor the zonal multiphase flow rates in real time. Real-time zonal flow measurement downhole also helps detect production anomalies and reduce the need for surface well tests and facilities. This work carries a historical perspective: it is the third part of an ongoing effort that started in late 2007. In the first part, which was published in 2008, it was shown that the optical flowmeter provided invaluable information and operating successfully at most ICV settings, while for some specific ICV settings the excessive acoustic noise masked the flow signal. The findings from the first part were instrumental in improving the flowmeter design to tolerate higher acoustic levels. The new design, Gen-2 System, was tested rigorously under laboratory conditions along with the earlier Gen-1 System, and a Hybrid System, which were specifically designed for already-installed equipment. The design improvements and the results of this comparative laboratory work were the subject of the second part published in early 2010. This third part now focuses on the two separate field tests with the Hybrid System, which took place in 2010. The field tests revealed important facts in three key areas: flow measurement, well operation and well optimization. The test results demonstrated that the Hybrid System is capable of tolerating acoustic levels, which were not possible with the Gen-1 System, and that the issues related to excessive acoustics that masked the flow signal at some specific ICV settings in earlier tests have been largely eliminated. As a result, the Hybrid and the superior Gen-2 Systems can now be used in close proximity to control valves. The tests also revealed the fact that the use of surface choke system plays an important role in the well operation as it affects the flow conditions downhole. Finally, based on the flow measurement results and all the available data, optimum ICV settings can be determined for the production mode. The work also provided insight into the collaboration and feedback process during the course of the field tests. The current work, which represents the successful closure of an effort spanning a four-year period from 2007 to 2011, sets an excellent model that can be used to improve other technologies in the industry; that open collaboration between the operator and the equipment manufacturer can lead to advancement of technology and, as a result, provide more robust solutions.

The paper covers a story of field that was brought on production using a combination of industry leading edge technologies; maximum reservoir contact (MRC) multi-lateral wells; advanced well completions and intelligent field infrastructure. Though individual components of the technologies had been tested and proven but the combination of these technologies in one development made this field to stand out as among the firsts in the industry. This feat came with peculiar challenges and rewarding opportunities.This article undertakes an assessment of the field, the wells and the technologies; following five years of production. The article discusses a unique case study detailing real time field and wells performance monitoring, management and production optimization. The experience from this field has provided unique knowledge and insight to better understand how the advantage of these technologies were nurtured and leveraged to take performance to the next level. During the five years of production, this field has been meeting or exceeding the fundamental field Key Performance Indices (KPIs) such as production targets, sweep efficiency and well potential. Moreover, the intelligent field infrastructural environment has made possible proactive real-time reservoir management leading to more efficient operations and result-oriented business work flows.

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This paper presents a generic workflow to assess direct and indirect production in reservoirs with layered contrasted permeability. The objectives are to quantify the total individual production split from those zones when compared to volumetric and evaluate the productivity efficiency. The workflow comprehensively integrates reservoir surveillance tools such as Production Logging Tools (PLTs) to perform a zonal decline analysis through analytical approach. The numerical simulation modeling is utilized to support this assessment. The paper describes a method of capitalizing the flowmeter results and correlate them with production decline to identify the volumes swept from the tighter zones of interest. The workflows identifies, as a result of this analysis, the split of the two portions of this swept volumes in the tight zones : a portion easy to identify, as it is produced directly through the logged wellbore or migrated vertically to most permeable zones to build-up on the attic portions of the reservoir. Such analysis when conducted in a specific field and coupled with simulation result is a powerful tool to decide on the actual mechanism affecting the sweep including the importance of gravity and percolation process. Consequently, strategic decision could be taken based on the options to develop the contrasted zones. This is including the decisions on wells configuration, whether it is more justified to fetch the tight zones volumes through vertical wells or to rationally exploiting the top layer through horizontal wells. The workflow was applied to real case study and showed a quantitative conclusive result, it demonstrated the equilibrium, required to maintain, in the withdrawals ratio of the contrasted zones. This equilibrium will ensure to have a better sweep of lower productivity zone.