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Abu Dhabi, United Arab Emirates

Al-Masabi F.H.,Abu Dhabi Marine Operating Company | Al-Masabi F.H.,United Arab Emirates University | Castier M.,United Arab Emirates University
International Journal of Greenhouse Gas Control | Year: 2011

The modeling and simulation of the absorption of dilute CO2 into falling film of aqueous solutions of a sterically hindered amine, 2-amino-2-methyl-1-propanol (AMP), was carried out using COMSOL Multiphysics Version 3.3. The operating cases were divided in gas turbine cases (CO2 3mol%) and boiler cases (CO2 8.5mol%). The key operating parameters for the studied cases are CO2 partial pressure, operating temperature and amine concentration in the aqueous solution. The simulation focused on: (1) CO2 loading in aqueous AMP solution; (2) contact time to reach equilibrium; (3) pH of rich AMP aqueous solution; and (4) total required interfacial area/circulated AMP aqueous solution. The modeling was validated by comparison with experimental results for CO2 loading available in the literature, with deviations below 4%. High operating pressure, low operating temperature, and low AMP aqueous concentration increase CO2 loading. The compression need for gas turbine flue gas was found to be higher than for boiler flue gas. The pH of rich AMP aqueous solution at maximum CO2 loading was 8. The needed contact time to reach equilibrium decreases with temperature increases. The results were utilized to estimate the lower bound to the size of structured packed columns to absorb CO2 from flue gases. © 2011 Elsevier Ltd. Source


Barsoum I.,The Petroleum Institute | Khalaf A.M.,The Petroleum Institute | Khalaf A.M.,Abu Dhabi Marine Operating Company
Journal of Pressure Vessel Technology, Transactions of the ASME | Year: 2015

The conventional joining method of a pipe and a flange uses welding. However, welded pipe-flange joints have the drawback with the inherent distortions and residual stresses resulting from the welding process, which can affect the mechanical integrity and performance of the flange significantly. In this study, a novel pipe-flange connection method based on cold work is evaluated using the finite element method. A weld neck flange is modified by manufacturing circumferential grooves at its internal surface and the pipe is cold worked into the grooves using a hydraulic expansion tool. The finite element model incorporates a pressure dependent friction model for the contact interaction between the tool-pipe-flange and a strain-based ductile failure locus for the pipe material accounting for ductile damage initiation during the cold work process utilizing a continuum damage mechanics approach. The finite element results show that a high load carrying capacity can be achieved for the cold work pipe-flange connection and has good potential for replacing the conventional welded joint. Copyright © 2015 by ASME. Source


Al-Issa A.,Abu Dhabi Marine Operating Company
Society of Petroleum Engineers - Abu Dhabi International Petroleum Exhibition and Conference 2012, ADIPEC 2012 - Sustainable Energy Growth: People, Responsibility, and Innovation | Year: 2012

Whilst best-in-class automation has been put place in industrial plants during the past few years, brought about by the developments in Industrial Control Systems (ICS), the industry has become vulnerable to new types of industrial risks. The Distributed Control Systems (DCS), Safety Instrumented Systems (SIS), Fire and Gas Systems (F&G), SCADA Systems, etc that were put in place are essentially computer systems and became the source of concern as these have become intentional targets to hackers, espionage and blackmailers. The cyber security threat to process control networks and systems was also increasing with successful industrial attacks taking place. Integrated operations in exploration, drilling, processing, refining and almost all oil and gas process operations are using such systems. The Digital Oil Field (DOF) vision materialized as a result of the advances in the application of automation, remote control, real-time data acquisition, and the enablement of collaborative work environments. This vision essentially raised the need to integrate the process control systems with corporate business networks. This has led to the vital need to put in place a robust industrial cyber security infrastructure. This paper will discuss: • A first of its kind cyber defense infrastructure design for protecting the Digital Oil Fields and Critical Infrastructures from Cyber attacks. • The importance of developing the integrated systems design concepts incorporating at its core the ICS Security by design. • The value of engaging digital security specialists at the Front End Engineering Development (FEED) stage in Digital Oil Field projects. Copyright 2012, Society of Petroleum Engineers. Source


Khalaf A.M.,Abu Dhabi Marine Operating Company | Seibi A.C.,The Petroleum Institute
Engineering Failure Analysis | Year: 2011

Tube collapse due to heating of a trapped fluid in confined annuli has become a major concern in production wells and lubrication systems in gas turbines. This is due to the fact that tubes subjected to external pressure developed by fluid heating can generate catastrophic consequences that may lead to the damage of major equipment in the field, which in turn can have a great impact on the production. This paper, therefore, presents a case study of lube oil feed tube collapse of a gas turbine due to pressure build-up caused by fluid heat-up in trapped annulus of the failed tube. A conduction/convection thermal analysis of the tube and its surrounding environment was performed using MATLAB where the obtained results were used in finite element modeling to determine the required buckling pressure of the tube. ANSYS finite element package was used to conduct the stress analysis of the tube subjected to external pressure mimicking the real situation from which the required collapse pressure of the tube was obtained. In addition, an analytical thermal analysis was performed to acquire the build-up pressure at various typical temperatures of the trapped oil in the annulus. The collapse pressure obtained from the finite element analysis was used to estimate the temperature causing failure from the pressure-temperature chart obtained analytically. It was found that the collapse pressure is 125. MPa (18. ksi) which corresponds to 160 °C temperature rise in the annulus. This temperature represents a typical operating condition in the field. © 2011 Elsevier Ltd. Source


Kumar J.,Abu Dhabi Marine Operating Company | Draoui E.,Abu Dhabi Marine Operating Company | Takahashi S.,Japan Oil, Gas and Metals National Corporation
Society of Petroleum Engineers - SPE EOR Conference at Oil and Gas West Asia, OGWA 2016 | Year: 2016

Carbon dioxide (CO2) injection is considered to be a viable option for enhanced oil recovery (EOR) and has already been implemented commercially for more than 40 years. However, the applications are limited to onshore and offshore application for EOR activities have not yet been implemented. This paper presents the subsurface evaluation using laboratory experiments (PVT and corefloods) and compositional modeling, the design and surveillance program of a CO2 pilot project planned in a carbonate reservoir located offshore Abu Dhabi. PVT and coreflood experiments demonstrate the local displacement efficiency of CO2 in tertiary mode due to gas-oil miscibility, swelling of oil and reduction in oil viscosity. The screening study performed using a tuned equation of state (EOS) predicts significant additional recovery in a previously waterflooded area. A pilot is planned in one of the reservoirs of the field, which has 40 years of peripheral seawater injection history. The pilot design is influenced by existing peripheral pressure gradient, and is located down-dip in the field that covers approximately 80 acres. The pilot location is selected based on geology, reservoir quality, maturity to waterflood and surface facility constraints. A comprehensive reservoir surveillance plan, including one to two observers well, is developed to monitor pilot performance. The planned pilot will reduce uncertainties and risk associated with CO2 injection and address bottleneck uncertainties in an offshore environment before large-scale application. The first offshore CO2 injection pilot is designed for implementation in a tertiary mode in a giant carbonate field, which is still under secondary recovery production, to minimize interaction with current production and impact on surface facility. The paper also presents the possible mitigation for various challenges identified like asphaltene, scaling, corrosion, impact on existing carbon steel well completion, etc. associated with CO2 injection. The methodology and technical analysis used to evaluate and design the CO2 pilot are applicable to other potential fields in the region. Copyright 2016, Society of Petroleum Engineers. Source

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