Smart oilfield technologies and management real-time data surveillance, in terms of reliability and availability, has proven essential in the process of prolonging asset lifespan, improving asset integrity, and proactively preventing problems. This illustrates a leadership role in the integration of cutting-edge technologies by utilizing an Intelligent Field concept. Surveillance capitalizes on real-time data transmitted from Intelligent Field equipment, where mathematical algorithms and logic are automated and imposed. The application captures specific sets of data to help identify and analyze challenges associated with Intelligent Field equipment. Major prevailing benefits include, identifying systematic techniques to utilize automated diagnostics for reduction in human intervention, develop field level surveillance, cross-validating measurements through online modeling, and further enhance collaboration. This paper details the methodology, the outcome, the requirements, and considerations associated with effective real-time data utilization in energy industry applications. The platform allows business team members and their partners to communicate, collaborate, and coordinate activities in real time.

Multiphase flow metering is considered one of the most essential technologies in well testing. Since the mid 1990's, Multiphase Flow Meters (MPFM) have evolved from a revolutionary new technology into a consolidated solution widely adopted by the major operators worldwide. This evolution has taken place thanks to the high quality of measurements, low operational cost and the capability of enabling remote monitoring of wells' performance with ease. The meters have proven to be durable for testing oil wells of Saudi Aramco's (SA) fields. The installed MPFMs in Northern fields of Saudi Aramco have contributed effectively to enhancing the semi-real time measurements' quality as well as improving reservoir characterization. However, MPFMs are prone to mechanical and firmware failures. To keep the general health of the installed systems, various preventive and ad-hoc services are needed. The MPFM technology largely seems to be performing as expected and delivering high quality data. So far, 58% of the systems have been in service for more than 8 years and continuing to operate efficiently. Thorough analysis of the routine maintenance and checkups conducted during the past 10 years revealed the following: The MPFMs Mean Time between Failure (MTBF) and Mean Time to Repair (MTTR) indicated that the MPFMs have been available 97% of the time.The use of a probabilistic approach (Monte-Carlo™ Simulation) to study the P10, P50 and P90 values of the maintained MPFMs indicated that the variance between these values is small, demonstrating the reliability of these equipment.The classification of the diverse types of problems faced while operating the MPFMs highlighted the dominant cause of failures and enabled the initiation of a surveillance and subsequent failure mitigation program. The latter program resulted in fewer failures and higher equipment efficiency. This paper discusses the lessons learnt and experience gained from operating 168 MPFMs provided by different vendors in different environments during a 10-year period, along with the appropriate solutions that were implemented to mitigate the challenges faced and subsequently improve the efficiency and data quality of the MPFM.

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The global demand for energy is on the rise daily, this puts a heavy burden on Oil and Gas companies as the drilling and production challenges are increasing. Efficient and cost-effective solutions are always sought. Drilling multilateral horizontal wells is considered as one of the optimum solutions to maximize recovery with minimal cost in terms of wells drilled. The production from multilateral wells imposes it is own challenges, such as flow distribution and contribution from laterals. Installing smart completions in multilateral wells was a huge breakthrough and revolutionized the industry. The idea behind smart completions is to continuously monitor and control the production from each lateral individually. With the current configuration of downhole packers, the number of interval control valves (ICV) installed per well is four at most, which limits the number of effective laterals in a well. Considering the primary objective of minimizing drawdown and hence maximizing sweep efficiency from each well, it was studied and simulated that some reservoir compartments have an optimum number of five laterals, which makes it complicated to control and optimize the production. This paper exhibits the deployment of the first "5-Zone Smart Completion" technology in a five lateral well, to control the flow contribution from each lateral. Each completion section installed is comprised of a gauge carrier, a hydraulic flow control valve, a packer with feed-through ports and a sub to accommodate and secure control line splices. The technology enabled the control of the flow rate from five different zones and the measurement of pressure and temperature from each compartment. The completion design included another two pressure and temperature sensors downstream of the flow, only a few hundred feet above the gauge of the upper zone, utilizing a single electric cable to power up and communicate with the surface panels. All hydraulic valves were successfully tested and fully cycled in place and the packers installed at the programmed depths upon installation. The technology enhancement that supported five zones completions ranges from material technology, which permitted enough metal to be removed from the packers, where seven, quarter-inch bores, have to be drilled for control lines to be run to accommodate electronics and telecommunications. This development enabled up to 16 sensors to be connected by one single electrical conduit. The paper presents the production string concept, the technology used to achieve seven bores in the packer, while maintaining the packer's integrity, the complete sequence of pre-job preparation, and the installation outcomes, with its impact on the downhole flow controls.

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