bluuebunny/crossref_metadata_2025_split huggingface dataset:
Qusahwira from Project to Production: Establishment of Business Processes Model
Authors: Mohamed Al Jaberi Adel Saleh , Al Ahmed Easa Ismael , Al Zaabi Abdulla Rashed , Rabii Walid Mustafa , Bani Hashim Ahmed Mohamed , Martto Joshva 
Published: November 2015

Abstract
South East (SE) is one of the major assets in Abu Dhabi Company for Onshore Petroleum Operations Ltd (ADCO)'s portfolio. Until 2013, SE was producing from fields (Asab, Sahil and Shah) and 2 new fields (Qusahwira & Mender) which were under development. The initial operation philosophy for the new fields was to have a centralized operation organization with necessary support functions at Asab and to deploy only the facility operating resources at respective fields.
Due to the change in company strategy, SQM (Shah, Qusahwira & Mender) has been spin-off from SE and a new organization was put in place while Qusahwira (QW) was moving from commissioning to production in 2013.
SQM Operation Management Team (OMT) has initiated a business transformation program to ensure required business processes were in place for the new organization to seamlessly integrate the development asset in to a producing portfolio. Assigned task force acted as a program management office and process champions were allocated within the major Level 1 (L1) processes for its implementation. Finally SQM has successfully integrated into the existing organization through implementation of necessary business process within the asset.
The paper will discuss the detailed methodology, challenges faced and the change management initiatives implemented during commissioning to production transition.
A Development Framework Plan for the Emarati Workforce in ADCO
Authors: Al Sayegh Ali Ahmed 
Published: November 2015

Abstract
The paper discusses the importance of a development framework for the Emarati workforce. To do so the Competency Assurance Management System (CAMS) program will be presented along with how it has helped integrate the Emarati workforce into ADCO's culture. Additionally, the Career Ladder and Succession Planning processes will also be presented to shed light on how they have helped in creating a foresight in terms of career development for the national workforce.
The first section of the paper will focus on the challenging nature of Emiritization. It will answer the question of what challenges the mandate of Emiritization brought to companies it was imposed on and how they adopted to challenge.
The following section of the paper will then focus on the Competency Assurance Management System. The section is divided into three different subsections, the first subsection will focus on the structures of the CAMS, the second subsection will focus on the overall challenges the CAMS faced and finally the last subsection will focus on the value CAMS brings to ADCO.
The third section of the paper then illustrates the continuous development of Emaratis within ADCO even after they have completed the CAMS. The section is divided into two subsections one that focuses on the Career Ladder profiles meanwhile the other focuses on the Succession Planning profiles.
Flowingly, section four discusses what can be observed from the previous sections and illustrates how the Emarati workforce has changed its perspectives. Finally then the paper is concluded with a discussion on the set of challenges that ADCO might face in the future and the different methods it might adopt in order to face those challenges.
A Novel Enhanced Oil Recovery Technique: Experimental Results and Modelling Workflow of the DME Enhanced Waterflood Technology
Authors: Chernetsky A. , Masalmeh S. , Eikmans D. , Boerrigter P. M. , Fadili A. , Parsons C. A. , Parker A. , Boersma D. M. , Cui J. , Dindoruk B. , te Riele P. M. , Alkindi A. , Azri N. 
Published: November 2015

Abstract
Dimethyl Ether Enhanced Waterflood (DEW) is a novel and promising solvent-based EOR technology developed by Shell. Dimethyl Ether (DME) is a widely-used industrial chemical which is applied as a water soluble solvent for EOR applications to enhance a conventional waterflood. Once the DME-brine solution is injected into the reservoir and comes in contact with the oil, the DME molecules partition into the oil phase which leads to oil swelling and mobilization of residual oil. Moreover the partitioning of the DME into the oil phase decreases the oil viscosity and improves its mobility. The combination of these effects results in both a significantly higher ultimate oil recovery compared to the conventional waterflood as well as accelerated oil production at lower energy footprint compared to thermal technologies. As the solvent is water soluble, it can be very effectively back-recovered from the reservoir by re-dissolving the trapped DME in the DME-free chase water slug. The solvent is recovered from the produced oil and water streams at surface and re-used. The main objectives of this paper are to present the first experimental results, explain the physical mechanisms of this novel concept and demonstrate the extra oil recovery. Additionally, modeling workflows used to interpret the experiments and predict the benefits of field EOR application are illustrated.
To gain an insight into physical mechanisms behind the DEW, develop modeling workflows and de-risk the technology, an extensive experimental program was set up to investigate both the fluid-fluid and rock-fluid interactions. Phase behavior of DME/brine and DME/crude mixtures has been carried out, with a focus on the partitioning of the solvent between brine and crude. Mixing rules for properties affecting the phase mobilities have been determined. In parallel, a number of coreflood experiments were conducted on both carbonate and clastic cores of varying permeability to investigate the dynamic DME/crude behavior and DME/rock interaction. PVT experiments were used to build phase equilibrium models. Based on these PVT models, the coreflood experimental data was matched and interpreted using numerical simulation.
Coreflood experiments confirmed the phase behavior-driven character of the DEW technology. A good match between the experimental and simulated oil recovery was obtained in most cases. This shows that PVT models, generated using measured basic data, are in a good agreement with the dynamic coreflood experiments.
Monitoring & Surveillance Improve ESP Operation and Reduce Workover Frequency
Authors: El Gindy M. , Abdelmotaal H. , Botros K. , Ginawi I. , Sayed E. , Edris T. 
Published: November 2015

Abstract
The Western Desert in Egypt has multiple fields in which most wells are artificially lifted. Wells with ESPs represent the major percentage of oil production by volume in that area. ESP run life is a principal criteria that is typically evaluated before the initial design and throughout the well's life time. Most wells are remotely positioned from one another and from the main gathering stations (2 to 8 Km. approximately). This is one of the major challenges when trying to maximize uptime and reduce the production deferment.
Operational issues including power supply and capacity limitations as well as changing inflow conditions can have negative impact on the ESP run-life, predominantly caused by excessive trips and shutdowns. Also such trips will result in lengthy downtimes due to the remoteness of the wells. On the production side, these trips will ultimately have a major effect on production targets due to intermittent deferment.
ESP wells connected to real-time monitoring and surveillance systems incur less lifting costs because of proactive responses and early detection of incidents. Systematic alarms along with pro-active remedial actions can minimize such preventable trips while maintaining the integrity of the ESP, eventually extending its run life.
This paper discusses a number of case studies showing how the implementation of such system prevented trips in some situations and allowed making key decisions and recommending remedial actions to optimize the ESP operation.
Autonomous Inflow Control Device - A Case Study of First Successful Field Trial in GCC for Water Conformance
Authors: Iqbal F. , Iskandar R. , Radwan E. , Abbas H. Abdel-Moneam , Douik H. , Least B. , Mohamed Z. 
Published: November 2015

Abstract
The paper presents the case study of first successful Autonomous Inflow control Device (AICD) application in the GCC region. The AICD works on the principle of viscosity difference of the produced fluids and resists the unwanted fluid (water) to maximize the oil flow rates. The innovative design overcomes the subsurface uncertainty and changes due to dynamic reservoir behavior (changes in Sw, water break through, fracture etc.) by facilitating oil flow through a short and direct path of least resistance, thereby reducing watercut and increasing oil production rates relatively.
The paper elaborates the design considerations and implementation methodology for AICD completion installed in a watered out well of naturally fractured reservoir. A rapid increase in watercut was observed soon after commissioning the well on ESP which resulted in rapid decline in oil production rates. An integrated subsurface approach was adopted to analyse the problem, evaluate probable causes and identify potential remedial for the subject oil well. The subsurface and production data including seismic, borehole image, open hole and production logs, etc. were incorporated through a pragmatic approach in the design process. The conventional Inflow Control Device (ICD) was also compared to establish the added value.
In the end, the results of the successful AICD deployment are presented which indicate 400% increase in oil production with significant drop in watercut. The well is currently on production has produced 3 times more cumulative as compared to the pre-workover cumulative in 2.5 years. Overall, the AICD deployment resulted in overcoming the reservoir heterogeneity and improved sweep efficiency with a significant gain ultimate recovery from the well.
Risk Based Inspection Planning Using Bayesian Updating
Authors: Atia Mohamed , Manzocchi Mark , Munday James , Azouz Amr , Omar Tarek , El-Khouly Wael , AbdelKhalek Ahmed 
Published: November 2015

Abstract
Offshore Structures are typically designed with a target end of field life between 20 and 30 years. Many offshore Structures remain in service while exceeding their designed life which requires robust methods for evaluating and maintaining target risk levels through regular sub-sea inspections.
Risk based inspection plans are generated based on strength and fatigue analysis (typically S-N based fatigue assessment) which involves a number of uncertainties which are inherent to the fatigue process. These uncertainties inevitably lead to inconsistencies between analysis predictions and the outcome of underwater inspections. Although the inspection findings are acknowledged, there is generally not much effort made to make use of the inspection findings to optimise future inspection plans.
This paper applies reliability updating methods to optimise inspection plans (inspection intervals) using fatigue reliability based on the results of in-service inspections. This methodology forms part of the work requested by ADMA-OPCO during the customisation of Atkins Fleet Management System (FMS) for the application to their Offshore Structures fleets. It has been reviewed and adopted by ADMA-OPCO to replace existing qualitative methods. The methodology works towards optimising their inspection efforts and cost to maintain acceptable target risk levels.
The methodology is based on evaluation of the SN fatigue reliability since the SN Curves are implemented in the fatigue design methods outlined in International Standards. A probabilistic model for fracture-based reliability calculation is developed by calibration of initial crack size to match SN based fatigue reliability. This model enables utilisation of the Bayesian updating techniques which allow incorporation of the inspection results in the calculations.
Environmental data from Umm Shaif Field (ADMA-OPCO) have been utilised in the calculations along with fatigue design SN Curves from the API RP 2A international standard. The calculations target the acceptance probability of failure levels of a critical component (hotspot) with a target design life of 30 years.
In the event that no fatigue cracks are identified through in-service underwater inspections, the existing inspection plans can be revised utilising the developed methodology to optimise the inspection intervals, leading to cost saving and optimisation of the inspection plan. Major in-service inspection campaigns have been executed by ADMA-OPCO where no fatigue cracks were identified. Other operators within the region have also concurred that no fatigue cracks were observed during in-service inspection campaigns, which indicate that the methodology proves effective in optimising inspection costs within the region.
Suppliers Compliance Assurance Mechanism
Authors: Alashqar Ameed , Yoo Jaeho , Elshareef Abdulla , Awda Hisham 
Published: November 2015

Abstract
Over 60% of the "Mega-Projects in Oil production and development" budgets is allocated for equipment procurement, therefore, most of the EPC contractors in today's competitive bidding and the lump Sum Project environment in the UAE put most of their effort to save in this area to maximize their profit.
The equipment supply sustainability risk levels elevated in the last decade due to collapsed of several major suppliers, the scatter of supplier experience, large acquisitions of specialized manufacturing sourcing from low cost centers and the trade between cost and quality.
A Suppliers Compliance Assurance (SCA) Mechanism has been developed to address such market challenges to fill the gaps between end users and vendors for maintaining the specified quality of end products.
With this Supplier Compliance Assurance Mechanism, ADMA-OPCO was able to set specific requirements and goals and enabled getting involved at critical stages on the right time to ensure the agreed scope is decided and with sufficient time to secure corrective measures and Contractor's supplier compliance in a transparent environment.
This in turn will contribute to develop company's organizational process assets for future challenges, to encourage young engineers to broaden their capabilities and to drive us towards e higher fficiency and excellence.
Production Management System to Enhance Collaboration and Production Surveillance, Garraf Oil Field
Authors: Didanloo Ali , Rivadeneira Ivan Marcelo , Idris Khairul Nizam , Latef M Zukhairi 
Published: November 2015

Abstract
Production engineers frequently use back allocation to estimate actual production volumes from wells based on frequent well test data or theoretical calculations using well and reservoir characteristics.
PETRONAS executed a centralized production data management system from early days of production to establish a scalable and reliable workprocess among the organization. The production and operation data management system of the field supports data collection, QC, validation and production back allocation as well as production downtime optimization.
The new system provides a means to visualize complex networks, verify the production streams, track gathering systems functionality through time and derive the allocation networks.
The various downtime coding and quantifications, helped Petronas to quantify the root cause of production shortfalls and optimized the unwanted shut downs.
The new system has improved the data quality and reliability and has made the data transparently available to the various stakeholders in the organization.
After the new back allocation system became fully operational, Petronas started to realize the following benefits from this successful implementation. Determine the production quantities of each well and reservoir for production accounting.Quality check and approval for the test data before being used for further calculationsAbility to allocate production, where accurate measurements are not possible or cost effective.Ability to determine fluid flow quantities through every strategic point in the network
The current paper describes the challenges and benefits of the subjected system implementation.
Dispersants for Cement and Salt Contaminated Manganese Tetraoxide High-Density Water-Based Drilling Fluids
Authors: Al Moajil Abdullah M , Nasr-El-Din Hisham A. , Kar Yusuf , Al-Bagoury Mohammed , Steele Christopher D. 
Published: November 2015

Abstract
The flocculation of aqueous-based drilling fluid, particularly at high temperature or in a high-salinity environment, is a common problem. The aggregation and settling of solid particles (e.g. manganese tetraoxide) causes operational problems, such as stuck pipe, well control, false bit gain, and scale problems. The flocculation of manganese tetraoxide particles becomes more severe at high density with the presence of clays such as bentonite and common fluid contaminants, such as cement and divalent salts. This affects the rheological behavior and sagging tendency of the drilling fluid adversely. Dispersants called deflocculants, thinner or dispersing agents, are used in drilling fluids to prevent solid flocculation. To minimize such flocculation problems, a thorough study was undertaken to identify aggregation of Mn3O4 particles and appropriate dispersants for water–based fluids weighted with Mn3O4.
The dispersion of Mn3O4 particles in aqueous solutions was evaluated through visual transparency testing and a PC-2200 Spectrek laser particle analyzer. A Mastersizer 2000 was used to obtain the particle size distribution and specific surface area of Mn3O4 particles. A TGA was used to assess the thermal stability. The compatibility of over 50 dispersants with aqueous solutions was examined using a variable speed mixer. Viscosity and sagging tendency were evaluated using a Fan 35A viscometer and density variation measurements. The effect of CaCl2 was considered in the experimental study. The drilling fluids were aged using a hot rolling oven up to 400°F.
Linear and other structures of particle aggregations were identified in Mn3O4-based filter cake. Dispersants examined were categorized into groups A, B, and C. Groups A and B dispersants showed settling times of 24 hours and 1–3 hours, respectively. More than 25 dispersants were assigned to groups A and B. Laser particle analysis showed that aggregation of particles was reduced in the presence of a lignosulfonate-based dispersant. Lignosulfonate and acrylate-based dispersants were compatible with water-based fluids and thermally stable up to 400°F and in the presence of CaCl2. Both dispersants reduced the sag factor and fluid loss for the drilling fluids in the presence of cement contamination. The shear stress/rate relationship and viscosity measurements showed that the rheological behavior of drilling fluids dispersed with either dispersants was improved. The dispersants chosen were non-toxic to aquatic organisms and biodegradable. The examined drilling fluids were high-density fluids up to 20 lbm/gal appropriate for deep drilling.
Development and Application of Ultra-Low Invasion All-Oil Coring Fluid: A Viable Technical Solution for Preventing Core Contamination
Authors: Mehtar Mohammed , Jeughale Ramanujam , Salman Mohamed , Al-Busafi Badar , Marinescu Pavel , Kostic Tijana 
Published: November 2015

Abstract
Over the last several years, improved recovery, especially in depleted reservoirs, has prompted many research projects involving operators, service companies and academicians. Recent work on rock-brine-hydrocarbon interactions has demonstrated that carefully designed low salinity water injection in carbonate reservoirs has the potential for enhancing oil recovery as much as 15% compared with conventional treated sea-water or produced water injection. The implementation of this step-changing technology requires studies carried out on in-situ condition cores. Ultra-low invasion drilling fluids must therefore be used during the coring process, to preserve the formation in its original state, without altering its fluids composition, water saturation or wettability properties. This paper outlines the philosophies and criteria brought to reservoir coring fluids design, development and application of an All-Oil synthetic-based coring fluid.
An All-Oil coring fluid with ultra-low invasion characteristics was developed after extensive lab testing. The fluid properties were optimized based on reservoir properties and challenging bottom-hole conditions, which are presented in this paper along with design criteria, fluid characteristics, fluid development methodology, benefits, benchmarks set initially and field application details. Excellent multi-segments collaboration and team work during core planning, fluid development work and on-site fluid maintenance to achieve planned parameters led to operational success and are described in the paper.
For the first time in UAE, a major offshore operator cut the cores with ultra-low invasion All-Oil Coring Fluid, which provided excellent stability to coring parameters and performance. The cores were recovered, processed and preserved in as close in-situ condition as possible, eliminating water contamination and preserving the core integrity, all of which are the basic essentials to achieve successful specialised formation flooding studies leading to the EOR Project. 520 feet of cores were cut in the reservoir section over 9 runs, with 100% recovery of high quality and uncontaminated cores. The cores were slabbed, plugged, photographed, packed, waxed and preserved successfully on site for transportation to lab for flooding studies.
The fluids' outstanding performance that helped in achieving the coring objectives in this new coring strategy are discussed in the paper and lessons learned are contrasted with conceptual design for future optimisation. Laboratory test results are also presented which formed the basis of a well planned field application.