bluuebunny/crossref_metadata_2025_split huggingface dataset:
Developing Project Management Professionals
Authors: Al Jaidah Bader 
Published: December 2014

Abstract
TAFAWOQ, which means "excellence" in Arabic, was established in 2011 as a regional non-profit Project Management Centre of Excellence, to deliver a world-class course program which aims to develop the competencies of project managers for capital projects in the State of Qatar and the GCC.
The Hamad Bin Khalifa University (HBKU), Qatar Petroleum (QP) and Qatar Shell developed the TAFAWOQ initiative in supporting Qatar National Vision 2030 (QNV 2030), one of the most ambitious development programs in the world. This program is accompanied by investment projects valued at more than US$ 230 billion.
A Memorandum of Understanding between the three partners was signed in October 2012.
This paper illustrates how TAFAWOQ contributes to the development of the competencies of project managers and other participants in project teams in Qatar and the region. In summary, this is through: The delivery of a world-class course program for project managers and those participating in projects in the State of Qatar and in the GCC region. This program is developed in conjunction with the Shell Project Academy, Cranfield University in the UK, Technical University Delft in The Netherlands, Queensland University of Technology in Australia, and the University of Texas in Austin.Community Events to promote networking and provide the project management community with a forum to discuss major subjects regarding project management in the GCC region.Tailored courses to address specific requirements of regional companies and delivery of courses at their premises.Toolbox sessions to refresh what was presented in our courses or to address a particular topic.
Over 250 project professionals from companies in Qatar and other countries in the region successfully completed the TAFAWOQ programs and four community events were organized. Meanwhile, the first batch of course participants passed the APMP examinations.
4D Seismic Processing Pilot, Offshore Qatar
Authors: Blanco B. , Charron P. , Brechet E. , Pagliccia B. , Radigon M. , Emang M. 
Published: December 2014

Abstract
4D seismic is a powerful tool to monitor a reservoir. This geophysical technique involves repeating 3D seismic over a produced area. It is well known as a robust reservoir monitoring tool in clastic deposit environments. In a carbonate reservoir however, once oil is replaced by water the effect on seismic parameters is less pronounced and should result in only a slight 4D signal. Thus 4D seismic has often been overlooked to monitor the production of carbonate reservoirs. However, in such context, Total E&P Qatar engaged in a 50 km2 4D pilot study in 2012. This was carried out over the Al Khalij field, offshore Qatar, a Middle-East carbonate field under development. This 3D survey, shot more than 10 years after baseline acquisition, helped to determine what could be achieved by 4D data. 4D inversion and interpretation have since shown encouraging results, consistent with well calibration. Therefore, a full field acquisition that will repeat the 1999 3D vintage is envisaged to be shot during 2014.
This paper will develop the meticulous 4D processing that has been done in order to optimize the interpretation of this slight 4D signal. Each processing step has been challenged with over a hundred SEGY outputs on the whole project for internal QCs. 3D seismic processing is already a challenge over the Al Khalij field and the intensive 4D testing flagged numerous errors that have had no impact for 3D purposes although were detrimental to the 4D analysis. In order to prepare for the future full field 4D processing, the 4D pilot processing has been restarted from scratch several times in order to fine tune results. For ensuring 4D repeatability a test will be launched on the full field acquisition with Total E&P's original method for predicting 4D noise during acquisition.
Deposition, Stabilization, and Removal of Asphaltenes in Flow-lines
Authors: Aslan Seyma , Firoozabadi Abbas 
Published: December 2014

Abstract
Asphaltenes are the most polar components of crude oil and its deposition is a serious problem in petroleum production. Asphaltenes are composed of 10-12 fused benzene rings with aliphatic chains, heteroatoms, and some metals. To stabilize the asphaltenes from deposition or to chemically remove the deposited asphaltenes, we studied various dispersant/stabilizers to assess their effectiveness. We have studied two oils, MN-133 and BAB, and employed two acidic dispersants (DBSA and PAO-72) and a stabilizer (BA). We have performed mixing, sedimentation and characterization of the supernatant in vial studies, and stabilization, deposition, and removal of asphaltenes in flow-line experiments. Our results indicate that only 5 ppm of BA is sufficient to stabilize asphaltene particles. To remove the previously deposited asphaltenes, 5% of an acidic dispersant for 1-2 pore volumes is sufficient. Our experiments have been performed in laboratory scale but show great promise for a field-testing. This study will enhance our knowledge on the effect of non-ionic and acidic surfactants in asphaltene solubilization/stabilization, decipher the mechanism, and shed light on fundamental understanding of asphaltenes at the molecular level.
Improving Gas-Condensate Recovery Factor and Addressing the Flow Assurance Issue with an Innovative and Highly Accurate Fluid Sensors for Wet Gas Business
Authors: Pinguet B. 
Published: December 2014

Abstract
In wet gas business, the fundamental challenge from a metrology point of view is to detect either condensed water or first formation water entry. This need is related to the flow assurance concerns, mitigation process to be started with chemical injection, and detection of water breakthrough at reservoir level.
In recent years, operators have requested multiphase and/or only wet gas meter manufacturers to solve these challenges by additional measurement and specifically the ‘salinity’ measurement (i.e. conductivity). Most of the manufacturers have responded by incorporating additional sensors into their conventional meter, which address the fundamental problems that their technology is facing and to correct the bias coming from a change of salinity, but unfortunately, it is also increasing the entire complexity and equipment cost.
This paper is describing the development of the most innovative solution to obtain this additional conductivity measurement and thru this versatility in the installation of the sensor becoming an enabler for some oil and gas operators that can obtain a very cost effective solution in some field developments.
The paper is explaining the fundamental principle, and the entire process of qualification encountered over 4 years for obtaining a commercial solution including for high pressure and temperature conditions. The performance of the conductivity measurement will be check against the best flow loop references around the world.
The paper demonstrates that even in control conditions with only few tenth to hundredth ppm of liquid (0.001%), it is possible to discriminate the different phases, even the condensate formation inside the pipe (crossing the dew line). This innovative solution is a breakthrough for any wet gas development where flow assurance is critical.
Identifying New Opportunities Through Reservoir Performance Reviews and Systematic Benchmarking of TQ Recovery
Authors: Prelicz R. M. , Fearfield D. , Sobera M. , Roeterink R. , Van der Harst C. 
Published: December 2014

Abstract
The Champion field is a large offshore oil field in Brunei Darussalam, which has been on production since 1972. The field is complex both geologically and in terms of the production system. The reservoir has over 500 stacked sandstone reservoirs across 15 fault blocks. Over time production facilities have increased to 40 surface structures supporting production and processing from over 1300 completion intervals. Although the field is considered a mature field and with aging facilities, there is a clear long-term vision to rejuvenate the field to sustain production for another 30 years through re-development and expansion of the water injection scheme.
Ongoing maturation of the waterflood project is supported by continuous Reservoir Performance Reviews (RPRs). The RPRs bring together the reservoir understanding, hydrocarbon saturations and production data. The purpose of the RPRs is to identify opportunities – restoration, acceleration and reserves addition and compile them in an integrated development plan covering the short, mid and long term. RPRs are carried out at the flow unit level - a small group of commingled reservoirs within a single fault block.
Top Quartile Recovery Factor (TQ RF) analysis is an integral part of the RPR. With the Top Quartile Estimated Ultimate Recovery (TQ EUR) tool, Shell developed a benchmarking tool which provides a conceptual framework that probes the performance of each field in a consistent manner. Basic geological and fluid properties as well as economic parameters are used to determine a complexity factor for each flow unit. The current and expected ultimate RF of the unit is then compared to the TQ RF (from reservoirs of the same complexity).
A systematic approach is taken to bridge the gap to TQ RF. Closed-in well reviews identify restoration and water injection candidates. Deterministic analysis of sweep patterns and high remaining oil saturations are compared with streamlines in the NFA forecast model. Potential gains are quantified by the simulator. The outcomes are near-, mid- and long-term surveillance and development plans to move the recovery up to TQ and beyond to the technical limit (TL).
By applying this systematic RPR/TQ process per flow unit across the whole field, a detailed reservoir understanding of this giant, complex field is achieved. This approach enabled the integrated WRFM team to deliver significant value in terms of increased production, optimization of Waterflood development and new in-well and infill opportunities.
First Real-Time Drill-Stem Test in Deepwater Using Fully Acoustic Telemetry Monitoring and Control of the Well
Authors: Dias Flávio , Marcançola Fernando , Wakabayashi Dalmo , Piazza Ralph 
Published: December 2014

Abstract
As exploration has moved into deeper, more hostile environments, drill-stem testing (DST) has had to address new challenges related to testing in these ever-changing, more demanding environments. These new scenarios have required continuous technology innovations to enable DSTs to meet the additional needs inherent to the deeper offshore environments. Testing technology has had to find solutions for these conditions, while maintaining cost optimization and operational safety, both of which present continuous concerns. One strategy has been to reduce the use of electrical cables in the well and minimize the application of pressure to the annulus. This paper presents the industry's first fully acoustic telemetry controlled and monitored real-time drill-stem testing (DST) operation performed in a deepwater environment. The fully acoustic controlled operations included: Opening tester valve for flowClosing tester valve for build upOpening circulation portsActuating downhole samplersAcquiring real-time pressure and temperature data.
This job was performed in the pre-salt region of southeast Brazil from a semi-submersible rig at 7,053-ft water depth in a well that was17,600 feet deep. In this DST, a completely wireless acoustic system was used to control the downhole tools, and as such, had to actuate the tester valve, the circulation valve, and the bottomhole fluid sampler, while acquiring real-time bottomhole pressure and temperature data. This was the first time that this type of operation had been attempted in deep-water conditions.
Acoustic telemetry systems usually can help optimize operational cost because of their capability to access quickly real-time data pertinent to the reservoir evaluation; because of this capability, immediate well-timed decisions or changes to operations can be made.
The fully wireless system (acoustic wireless transmission across the subsea safety tree and its components) provided the operator with acoustic feed-through response, which enabled troubleshooting from the surface and capability to change the "next steps" for the DST quickly.
This paper also discusses how the use of these tools elevated testing operations to a higher performance level and improved quality standards.
Fluid Loss Prevention for PrePerforated Liners, in High-Temperature and High-Pressure Applications
Authors: Carrejo N. , Kellogg B. R. , Barnard J. J. , Gaudette S. L. 
Published: December 2014

Abstract
Global demand for energy is driving the necessity to develop completion technology that optimizes production while maintaining a cost effective strategy. Operators rely on these technologies to push the boundaries to complete ultra-deep, high pressure and high temperature wells. These depths require proper fluid placement during drilling. After thetotal depth is reached, a conventional method to gain access to the reservoir in a cased-hole application is to use gun perforating systems or wireline platforms to perforate the casing. These systems generate costly losses in production time, and are followed by a clean-up run to prevent the debris from plugging the well or damaging other tool systems. In addition, the perforation of the drilling liner can cause unwanted skin damage to the formation that can impede production. High-strength disintegrating materials (HSDM) are an engineered metallic that provides an interventionless solution. HSDM combines the strength of metallic material with the unique quality of degradable composites by dissolving in brines or acids. This material enables the liner to be predrilled to a predesigned diameter, and filled with a high-strength disintegrating plug (HSDP). The HSDP provides a flow path for essential drilling fluids, and after displacing the drilling fluids to completion brines or acid, the HSDP dissolves. After removal of the HSDP, the operator gains full access to the formation without impeding production. The technology is combined with a new bonded bead matrix to provide reliable sand control while maintaining the HSDM as a fluid loss barrier. These two technologies form an extreme pressure frac screen (XPFS). With the bonded bead matrix protected by a HSDM disc, the working pressure rating is 15 ksi in burst and collapse. Upon removal of the HSDM disc, the bonded bead matrix is a sand control screen that prevents production of 85 to 95% of all particles larger than 53μm while maintaining high erosion resistance and compatibility with corrosive fluids such as hydrochloric acid. This paper presents the pressure rating dependability and sand control capabilities of a liner that provides operators with an interventionless ability to reliably complete ultra-deep, high-pressure and high-temperature wells.
Integrated Water Injection System Capacity Optimization through Cluster Looping
Authors: AlSelaiti I. H. , Aly Moussa M. , Mohammed Al Haj J. , Yersaiyn S. , Mehran F. , Didanloo A. , Cristea Z. 
Published: December 2014

Abstract
This paper describes an efficient approach to evaluate the water supply-to-injection cluster facilities capacity and also to define the required upgrades and areas of optimization.
The supergiant filed understudy is located in Abu Dhabi and is producing for decades from multilayered carbonate reservoirs. The field is under peripheral water injection to maintain reservoir pressure and also to enhance the oil recovery.
Total of 53 water injection clusters have been commissioned in the field to support water injection operation for reservoir management purpose. The water clusters consists of producing wells from water bearing formations and multiple injection wells completed in different reservoirs. Frequent down time in the water supply wells and existing bottle necks in the water supply to injection system has led Abu Dhabi Company for Onshore Operation to evaluate the clusters looping option to enhance the water injection capacity of the field and optimal re-distribution of the water through the clusters.
By this strategy, the high capacity water supply wells will be able to feed the candidate clusters required extra water or the clusters with the closed water supply well under maintenance.
To achieve this strategy, a fully integrated water supply to water injection system was built using a commercial fluid flow simulator. The integrated model consists of water supply well equipped with ESP, water injection facilities network with surface pumps, strainers and choke manifolds as well as injection wells. The system was validated against most reliable measured data at a snap shot of time.
The full integrated water supply to injection model was used to evaluate the opportunities to loop the high capacity clusters to high demanding clusters, identify the bottlenecks in the system and also to determine the various options in the clusters facilities to enhance the water injection capacity of the field.
Advanced Monitoring and Inspection Help Increase the Safety of Operations
Authors: Kapusta Sergio , Wang David 
Published: December 2014

Abstract
Asset integrity is one of the crucial components of process safety. While process safety incidents in the oil and gas industry are rare, they have the potential to cause injury to people and damage to the environment, to our business and to the industry's reputation. To prevent and mitigate the impact of such incidents we establish successive safety barriers such as adequate materials selection, process operating windows, corrosion control, monitoring and inspection. In this presentation we focus on some of the novel techniques to inspect and monitor the condition of equipment and detect potential hydrocarbon leaks. These techniques are integrated through robust work processes and management systems into the asset integrity program, and can help to dramatically improve the safety of operations.
Rising Heat, Rising Threat - Hydrate Before It's Late
Authors: Al Ali Mohamed A. , Sarkar Prabir Kumar 
Published: December 2014

Abstract
Exposure to excessive heat from ambient environmental conditions during the summer months is a common hazard in most of the Oil and Gas installations in the Gulf. ADGAS Occupational Health Risk Assessment has also identified heat as a major hazard during the summer months. In order to mitigate the adverse health effects of heat exposure, ADGAS implemented a comprehensive management programme, based on a multi-angled approach, which included filed surveys, lab tests and control measures as summarized below.
Workplace survey: Walkthrough of the workplace to identify activities with potential for heat exposure along with the availability of controls and employee awareness.
Thermal environment monitoring: Determining the Thermal Work Limit by measurement of dry bulb, wet bulb and globe temperature, and air velocity.
Hydration testing: Measurement of specific gravity of urine samples from selected outdoor workers (308 out of 500 workers) to ascertain the hydration level in accordance with ADNOC COP guidelines.
Control measures: A Multi-tier approach to mitigate the effects of heat exposure through the following: Management involvement: Heat stress campaign with site visits by the top management and provision of water and refreshments.On site arrangements: Rest shelters with provision of drinking water along with tool box talks on heat exposure for the workforce.Employee awareness: HSE leaflets, presentations, awareness booklet, etc., to enhance the level of knowledge on harmful effects of heat.
The above programme resulted in risk reduction for a group of nearly 1000 employees (~59%) of ADGAS workforce. The program has met its objectives as manifested by zero incidents of heat related illnesses in 2013 as compared to eight cases in 2012. The programme has also helped to provide information on the baseline heat exposure, and possible immediate and future control measures.
Rotation by Reciprocation Casing Landing Technology
Authors: Gosselin R. , Montgomery T. , Muriby A. , Yussef Moataz , Karrani S. , Khamis A. 
Published: December 2014

Abstract
With the innovation of ERD and directional drilling and the challenges these wells impose due to complicated and difficult wells’ paths, advanced well profile, Deep and HPHT wells and Horizontal wells, running casing and liner strings has become increasingly problematic.
Conventional casing running methods have not given full confidence of landing at TD every time a casing orliner job is run, especially with difficult and challenging wells.
Not much has been done to address these challenges which vary with wells and fields such as: ledges & obstructions, washouts, swelling shale, bridging, high doglegs, difficult well profiles, fill on bottom and well collapse, etc.
To overcome the challenges, the inventors developed the Fill Drill Product Line as a new technology to facilitate casing operations especially for long horizontal strings, production strings, and intermediate casing strings.
The authors will describe the innovative system utilized to improve the casing run supported by extensive field data. Case History will be presented and the benefits of the application of this technology in these wells will be explained.
Preventing Production Opportunity Losses In LNG Plant
Authors: Al Shehhi Abdulla Bin Saif , Lallchandani Kailash Tikam 
Published: December 2014

Abstract
Rotating Machines are critical key equipment in the LNG plants. Acceptance working conditions have been defined in standards and are followed closely by the operators. In this article, a real case study is described for Critical equipment which was allowed to operate in an abnormal condition, based on a calculated risk decision in which the technical defect and potential consequences were taken into account.
Long term opportunity losses on one of LNG Trains in ADGAS was avoided by taking a calculated risk decision and allowing the Propane Centrifugal compressor to operate at high vibration levels till the shutdown could be planned.
A sudden unexpected trip occurred in one of the LNG train in ADGAS and during start-up, the Propane Compressor driven by a steam turbine tripped several times due to excessive vibrations. Vibration analysis indicated a heavy rub, thermal bow, or ingested foreign material near the center of the rotor along with heavy sounds from the suction drum. This supported the assumption of ingestion of foreign material, rather than a machine originating problem. Hence the machine was allowed to run for six months whilst keeping it under intensive care i.e. a very close online condition monitoring.
Thus an accurate vibration analysis helped Maintenance and Operation personnel to carry out the risk assessment for keeping the Compressor running till all the spares and manpower arrangement could be done and prevent the Production loss.
Introduction
LNG Train#1 was operating at full load condition when a sudden trip was experienced on Das Island on 27th April 2013. System was restored after 2 days and all machines were restarted. The Propane refrigerant compressor driven by a steam turbine was attempted to start but machine tripped repeatedly at high vibration levels.
The machine was brought to full speed by increasing the vibration trip levels and vibration data was collected. The vibration data was well analyzed by ADGAS engineers in-house and also opinions from external experts & OEM were sought, to decide that the machine shall be kept running or stopped immediately. Outage of the machine was suspected to be 6 months due to nonavailability of spares and could have high impact on production targets and risk of meeting commitments.