bluuebunny/crossref_metadata_2025_split huggingface dataset:
ADCO's Experience and Lessons Learned in Quality Management of Major Projects
Authors: Daoud Mohamed , Mohamed Alaa , Fawzi Mohamed , Hegazy Haytham , Folathi Ali al 
Published: November 2012

Abstract
ADCO has recently managed a major project called 1.8 MMbd Bab Thamama G and Habshan 2 consists of additional wells, flow lines, new process units and modification of existing surface facilities that are required to increase oil production in the Bab field by a sustainable rate of 80 MBOPD.
The facilities will include four additional Remote Degassing Stations (RDSs), namely RDS-7, RDS-8, RDS-9 & RDS-10 that gather from numerous production flow lines and deliver the raw crude to the BCDS through transfer lines.
Overall Project Objectives is to achieve EPC completion by Q4 2012, improve on ADCO's HSE targets, and Implement project within approved budget
The purpose of this paper is to share ADCO's experience during project execution, both in terms of technical and project quality management issues. The paper highlights the challenges faced, achievements and lessons learnt during execution of the project.
Mitigation of increased risk and consequences of failures due to higher service severity, Cost/time optimization drive due to material delivered from new and cheap suppliers with less quality level, Increasing inspection tasks of materials from different sources, and Management of the Third Party Inspection (TPI) to control all scattered activities locally and overseas were some of the major quality challenges during execution of the project.
The projects quality control practices implemented throughout the lifecycle of the project, starting with conceptual and preliminary engineering, through detailed engineering, procurement and construction are highlighted in the paper.
Major lessons learnt, quality control improvements tools, and other project quality issues are discussed in the paper.
Computation of Axial Load and Torque Distribution in Tubulars Used for Extended-Reach Horizontal Wells Using A Holistic Design Philosophy
Authors: Omojuwa E. , Osisanya S. , Ahmed R. 
Published: November 2012

Abstract
Drilling extended-reach horizontal wells (ERHWs) have become a viable option for field development because these wells bring additional reserves on line which may not be accessible with conventional well designs. Tubular design for ERHWs must be compatible with the intended well objectives, target location, wellbore trajectory in order to minimize the downhole dynamic events such as torque and drag, buckling and vibrations. Presently, the dynamic models used for calculating expected axial load and torque transfers along tubulars in ERHWs consider only the effect of the contact loads and frictional forces generated from torque, drag and buckling events. The expected axial loads and torque calculated during tubular design process are been underestimated using present dynamic models. However, the contact loads and frictional forces generated by lateral and torsional vibration events are critical to the tubular design for ERHWs and should not be ignored.
This study in this paper incorporates torque and drag, buckling and vibration models into the Newton second law of motion/instability in order to derive an integrated dynamic equation for torque and axial load distribution along tubulars in ERHWs. This study also uses theories of unbalanced centripetal force and fluid added-mass to quantify the magnitude of the normal contact load generated during lateral vibrations of a near-straight tubular section in an ERHW. The developed equations can be used for calculating axial load and torque transfer along drilling and completion tubulars depending on assumptions of hydraulic effects, buckling and inertia terms. Results show that the occurrence of downhole dynamic events contributes a relatively higher percentage to torque transfer than they do to axial load transfer. Also, when all the downhole dynamic events occur together and the critical buckling loads have not been reached, torque and drag events contributes the major portion of the axial load transfer followed by lateral vibrations.
The dynamic equations developed in this paper are validated using data from one of the world longest ERHWs. This study will lead to better tubular design through the minimization of failures, non-productive times, and ultimately reduced total drilling and completion costs.
Engineering Aspects in the Design and Implementation of Onshore Smart Oil Fields
Authors: Hafez Mohamed , Jakeman Simon , Al Azawi Bahir , Ur-Rahim Ihtisham , Khaled Moutaz 
Published: November 2012

Abstract
The Smart Field concept is deployed through disseminating elements of tools and infrastructure integrated to bring a level of smartness that can improve the performance of an oil field asset in a sustainable way.
The design and implementation of these tools and infrastructure underpinning smartness can however differ based on the oil field conditions. Green fields for example, can be engineered up-front to leverage all tools and deliver Smart Field value from the beginning of the asset's life. On the other hand, smart field tools and infrastructure for brown fields would be selectively designed and implemented based on several engineering and economic considerations.
The main functionalities of onshore Smart Field are remote operation, real time information and Collaboration realized by the following tools and infrastructure:
Subsurface Measurement Subsurface Flow Controls Wellhead Instrumentation Telecom Infrastructure SCADA and Control System Fields to HQ Connectivity Collaborative Work Environment
This paper outlines the engineering aspects to be considered in the selection, design and implementation of tools and infrastructure for onshore Smart Fields.
Optimized 3D Seismic Design Geometries for High Density Surveys
Authors: Ajlani Ghiath , Boukhanfra Fawzi 
Published: November 2012

Abstract
Despite the fact that wide azimuth land 3D seismic acquisition was introduced a couple of decades ago, the use of sparse 3D seismic designs continued for some time to be dictated by economic and technical limitations leading to poor quality and noisy seismic data. These design shortcomings were exacerbated by source and receivers arrays that failed to fully avoid aliased organized noise such as ground-roll and guided waves compromising the integrity of processing, imaging and reservoir characterization results.
To meet these challenges and motivated by increased demands for high resolution seismic data, leading-edge high-density and highresolution recording systems were developed potentially capable of recording as much as one (1) million channels at 2ms sampling rate. To optimize productivity and economics these recording systems have been combined with technologies that allow for shooting above 20,000 vibrator points per day and reaching very high trace densities. These technologies offer the possibility to deploy symmetric wide azimuth land source and receiver high density geometries and acquire non aliased signal and noise benefiting from all offsets and azimuths.
Black Oil, Heavy Oil and Tar in One Oil Column Understood by Simple Asphaltene Nanoscience
Authors: Seifert Douglas J. , Zeybek Murat , Dong Chengli , Zuo Julian Y. , Mullins Oliver C. 
Published: November 2012

Abstract
A Jurrasic oilfield in Saudi Arabia is characterized by black oil in the crest and with mobile heavy oil underneath and all underlain by a tar mat at the oil-water contact. The viscosities in the black oil section of the column are fairly similar and are quite manageable from a production standpoint. In contrast, the mobile heavy oil section of the column contains a large continuous increase in asphaltene content with increasing depth extending to the tar mat. The tar shows very high asphaltene content but not monotonically increasing with depth. Because viscosity depends exponentially on asphaltene content in these oils, the observed viscosity varies from several to ~ 1000 centipoise in the mobile heavy oil and increases to far greater viscosities in the tar mat. Both the excessive viscosity of the heavy oil and the existence of the tar mat represent major, distinct challenges in oil production. Conventional PVT modeling of this oil column grossly fails to account for these observations. Indeed, the very large height in this oil column represents a stringent challenge for any corresponding fluid model. A simple new formalism to characterize the asphaltene nanoscience in crude oils, the Yen-Mullins model, has enabled the industry's first predictive equation of state (EoS) for asphaltene gradients, the Flory-Huggins-Zuo (FHZ) EoS. For low GOR oils such as those in this field, the FHZ EoS reduces to the simple gravity term. Robust application of the FHZ EoS employing the Yen-Mullins model accounts for the major property variations in the oil column and by extension the tar mat as well. Moreover, as these crude oils are largely equilibrated throughout the field, reservoir connectivity is indicated in this field. This novel asphaltene science is dramatically improving understanding of important constraints on oil production in oil reservoirs.
A Novel Approach to Measuring the Quality of Well Integrity Performance in ADMA-OPCO
Authors: Al-Marri Faisal M. , Abdalla Hussein S. , Hussain Ashiq , Chishti Khalid 
Published: November 2012

Abstract
Several papers have been written to discuss various aspects of well integrity management such as technical standards, new software for data management, different approaches for risk management and using new technology to improve the operational efficiency. However, the literature lacks insights about how to measure the performance quality of well integrity operations. Measuring performance quality serves several objectives; it provides an insight into the overall performance; it highlights successful initiatives that could be expanded; and it identifies key areas for further improvement.
This paper presents one approach to measure well integrity performance quality using a Quality Index (WIQI) in a manner similar to that adopted by other industries. The Quality Index samples key activities such as planning, execution, monitoring and review to collect parameters that are consolidated in a weighted index to reflect performance quality. The paper will discuss ADMA-OPCO experience in adopting the new index and the impact it had on its operations.
Compression Solutions for Co2 Enhanced Oil Recovery
Authors: Dekker Gerrit Jan , Keim Benjamin , Mathijssen Gaston 
Published: November 2012

Abstract
A narrative on injection of CO2 for enhanced oil recovery considering the advantages of the integrally geared compressor over the single shaft compressor, and using the Siemens hermetically sealed canned motor-compressor in the process of separating export gas and CO2 for reinjection.
When injecting CO2 for EOR we have investigated the most important market requirements to identify the best solution from the existing portfolio of turbo machinery, when comparing a standard single shaft inline compressor to an integrally geared compressor, and have concluded, based on economics, efficiency, and power consumption, that integrally geared turbo compressors incorporate the optimum design concept for economic CO2 compression.
When re-injecting the produced gas after oil and gas separation there is a mix of saturated CO2 and hydrocarbons and other contaminants possibly containing hydrates, mercury and H2S. Gases and components which are preferably contained in the process equipment without possible leakages to the atmosphere due to seal leakages or malfunction of the compressor units dry gas seals. With the above in mind we developed a sealless (no dry gas seals) compressor which could add strategic benefits and eliminate the need for continuous flaring and venting of the seal gas and barrier gas to the atmosphere. And in conjunction with a fully categorized material selection provide the best solution with high availability and reliability.
Combined with the increased robustness of the overall system with less instrumentation and auxiliary systems and thus less spurious trips and downtime it is obvious that the integrally geared turbo compressor, STC-GV, in combination with the hermetically sealed compressor, STC-ECO, has the potential to considerably contribute to minimizing the environmental foot print, higher reliability and lower OPEX in the Oil & Gas operations especially in the process of mixed flow dirty gas separation found in the CO2 reinjection application.
Experimental and Numerical Modeling of Double Displacement Oil Recovery Process in Tight Fractured Carbonate Reservoirs
Authors: AlSumaiti A. M. , Kazemi H. 
Published: November 2012

Abstract
Waterflooding has been the most popular post-primary production approach for improving oil recovery. In fractured reservoirs with large structural relief, gas injection can produce much of the post-waterflood remaining oil by gravity drainage. Oil recovery by gas-invoked gravity drainage in waterflooded reservoirs is known as the double displacement process (DDP). One major reason, among many, is that the three-phase relative permeability residual oil saturation endpoint is generally smaller than the residual oil saturation endpoint for the water-oil displacement.
Field data indicate that the DDP has been successful in single-porosity sandstone formations. Intuitively, one can expect that DDP should produce similar results in reservoirs with ample intercommoned vertical fractures, which is the objective of this work. With the aid of tests on tight reservoir cores from a major Middle East carbonate reservoir, this study focuses on evaluating the DDP in fractured carbonate reservoirs where the wettability ranges from neutral to oil-wet conditions. The scope of the study includes: (1) assessment of the DDP experimentally in fractured cores using a high-speed centrifuge, (2) simulating the experiments numerically, and (3) upscaling laboratory results to field applications.
Results from water-oil gravity drainage tests followed by gas-oil gravity drainage in fractured and unfractured cores are presented. We also show numerical simulation results of matching the experiments using both transfer function and 2-D numerical simulation, and how results from our study can be used in field applications.
Typical waterflood oil recovery from 0.1-md to 2-md fractured carbonate cores has been noted to be around 38% of the initial oil in place while incremental additional oil recovery for gas-oil gravity drainage is nearly as much as the recovery from water.
BP North Sea Gas Injection Projects: Sustaining Offshore Production
Authors: Brodie James , Zhang Pinggang , Mellemstrand Hetland Sigrun , Moulds Tim , Jhaveri Bharat 
Published: November 2012

Abstract
BP has been operating gas injection projects in a variety of challenging environments throughout the world for more than three decades. Numerous innovative techniques have been used to optimize oil recovery and the results have been reported in a series of publications.
The focus of this paper is the North Sea, where BP operates offshore miscible gas floods in the Magnus and Ula fields and an immiscible gas flood in the Harding field. Tertiary miscible WAG in Magnus began in 2002 and its impact on reservoir performance is significant and well understood. More than 112 Bscf of gas have been injected into three mature panels, yielding 11.5 mmstb of oil at a very high net efficiency of 3.5 mscf/stb. The contribution of EOR to total field production has increased to 40% by 2010. In Ula, tertiary miscible WAG started in 1998 and has played a key role in arresting production decline. More than 23 mmstb of oil has been recovered by gas injection, which accounted for 60 – 70% of total field production in 2010. Key to the success of both projects has been securing a source of miscible gas and pursuing an active surveillance and reservoir management programme to monitor and optimize the flood.
The success of the North Sea projects is partly based on the experience of operating the world's largest miscible gas flood at Prudhoe Bay (Alaska), where conventional and unconventional techniques have been successfully applied in a variety of different settings. The knowledge acquired in Prudhoe Bay has been shared with other assets, including the North Sea, through a series of managed moves and master classes.
Miscible gas injection has generated considerable benefits for BP over the past three decades and will continue to do so in the future. The potential availability of large sources of CO2 in the future, through carbon capture, could help maintain a leading role for miscible gas injection for years to come.
100MBD Interface and Shutdown Management
Authors: Binthabet Hussain Ahmed , Cochrane Marc , Pettigrew Michael 
Published: November 2012

Abstract
ADMA-OPCO's approach, 100MBD Interface and Shutdown Management
In 2006, ADMA-OPCO embarked on a programme to increase the oil production from one of its offshore fields by 100 MBD. This involved a portfolio of 8 projects consisting of, on both offshore and onshore facilities and a drilling programme covering 40 wells. In addition to oil, ADMA OPCO also manages the offshore gas network and all offshore gas irrespective of source flows through its facilities. Therefore, any shutdown of gas facilities could impact gas and oil production from other offshore companies operating in the waters of the UAE, which has the potential to impact a significant portion of the offshore oil production in the UAE.
This paper will outline how ADMA OPCO managed the interfaces between projects, existing facilities and sister companies to both maximise oil, gas production facilities availability, and minimise hydrocarbon lost opportunities during shutdown and interventions whilst delivering the 100MBD Project portfolio.
The main areas of discussion will be
Organisational structure – ADMA OPCO set up a new organisational division, which included new focused teams dedicated to management of projects; minimising losses; programme & interface management. Case study – the paper will detail how a specific event was managed involving several projects interfacing with offshore and onshore facilities with the potential to impact oil production and how total shutdowns were eliminated and oil losses were reduced by over 75%
The success of this initiative resulted from focusing on
Identifying and quantifying potential shutdown reduction opportunities. Identifying opportunities to minimise plant preparation and return to service times. Optimising plant configuration to maximise production opportunities during intervention. Identifying any works or modification required to accommodate identified production opportunities
Application of methodology
This methodology is applicable to any Brownfield intervention covering one or more work fronts or projects, and has a demonstrated successful outcome
Engineered Internal Downhole Coating Solutions for Corrosion & Deposition Control in Downhole Production Tubulars
Authors: McKeen Laurence W. , Hofmans Jurgen , Nelissen Joke 
Published: November 2012

Abstract
During the last decade, DuPont™ has been developing an engineered fluoropolymer based internal downhole coating system, for downhole production tubes. This development work came as a response to critical needs expressed by major oil and gas producers in Europe, the Middle East and Northern / Latin America, in order to have a polymeric based coating solution that could be applied internally in downhole production tubes for the purpose of:
Offering an enhanced corrosion resistance in HP/HT (8000 psi / 350 Deg F) sour and sweet corrosive environments Reducing substantially difficult type of organic and inorganic depositions, such as asphaletene, paraffin and BaSO4 scale.
The ultimate objective of this exercise is to offer the oil and gas industry a reliable and sustainable static solution that would not require costly intervention for wells clean-up and maintenance and also to reduce the number of workovers required on oil and gas well producers, which would ensure lower production cost.
In order to develop such a new polymeric solution, a new approach versus the resin matrix design had to be used. The new coating system has an effective combination of a very low finished surface energy coupled with an improved pressure / temperature design envelope. Given the inherent design envelope limitations of current coating systems used by the oil and gas industry, fluoropolymers were selected in order to develop such a new internal downhole coating system.
The high thermal stability and high flexibility of fluoropolymer-based materials provide a significant advantage in terms of mechanical properties retention in high pressure and high temperature environments, which is a must for an effective internal corrosion control. On the other hand, it has the lowest sticking tendency versus difficult type of organic and inorganic depositions, such as asphaltene and BaSO4, which provides an opportunity for a new cost effective approach in terms of maintaining oil and gas producing wells prone to such problems.
Achievements and Expected Challenges of the Current Maintenance Strategy
Authors: Elmi Mokhtar 
Published: November 2012

Abstract
The importance of maintenance in the oil and gas industry is well recognized and as such every year great sums are spent on reducing turnaround and mean time between failures while all the more increasing equipment availability and achieving acceptable levels of work force certification. ADMA-OPCO as one of the world's largest companies in the upstream sector of the oil and gas industry has managed to utilize various available technologies to achieve high standards of maintenance. However, the field of engineering maintenance and reliability is an ever evolving one and due to many factors such as aging machinery and the expansion of operations, the company's underpinning maintenance practices and strategies require constant review and update. For this purpose the paper will present a review of the company's achievements in this regard as well as outlining solutions for future challenges. The findings will be based on scrutinizing current practices such as the utilization levels of the computerized maintenance systems in use in ADMA. Moreover, this paper will endeavour into finding out how well the company's maintenance strategy is adhered to and the major constraints that hinder its smooth execution. Age of the rotating equipment plays an important factor in the levels of maintenance they require; therefore this paper outlines the effect this has on the maintenance strategy and the likely future consequence of this factor taking into account the challenges ahead.