bluuebunny/crossref_metadata_2025_split huggingface dataset:
Re-Writing the Rules for Managing Change in ADCO
Authors: Malik Jamal Abdul 
Published: November 2012

Abstract
Managing Change in an Oil & Gas organization like ADCO is a difficult and critical task. It has become more difficult in recent years because of an increase in business & operational risk, change in our society as a whole, the rapidly changing environments within the Middle East and the Oil and Gas industry in particular.
Failure to adequately Manage Change has been the direct or underlying cause of many accidents, injuries and breaches of integrity within the Oil & Gas industry which ADCO operates.
As a result of these conditions, a Management of Change (MoC) project was developed and initiated driven by external forces such as; ADNOC's regulations regarding the implementation of Asset Integrity Management System (AIMS) requirements, internal ADCO issues such as; ADCO's Health Safety Environment Management system (HSEMS) and Senior Managements decision to shift from a Functional to an Asset based organization. All of these factors became the main influences that lead to the creation of a new MoC system, rules, business process and solution, to manage any Technical, Operational. Organizational and Procedural changes arising from adverse or unforeseen circumstances.
Fracture Characterization Integrating Volumetric Geometric Attributes and P-Wave Azimuthal Avo Analysis
Authors: Wang Zhaoming , Zheng Duoming , Zhang Lijuan , Shen Feng , Zhang Yang 
Published: November 2012

Abstract
The Lower and Middle Ordovician paleocave systems form an important type of reservoirs in the Tarim basin, China. To better understand the impact of fractures on the paleocave reservoir development, with acquired wide azimuth 3D seismic data, both post-stack volumetric geometric attributes and P-wave azimuthal AVO analysis are applied to characterize multiscale fracture distributions. In this study, volumetric seismic attributes including dip, discontinuity and curvature are used to identify sub-seismic faults and associated fracture corridors and to describe subtle folds and flexures within the reservoirs. P-wave azimuthal AVO analysis is applied to detecting high angle fractures. Six azimuth-sectored stacks are used to compute P-wave seismic anisotropy from which fracture density and orientation are estimated.
Two major sets of conductive fractures trending northeast and northwest, associated with different tectonic events, are identified using imaging logs from seven wells in the study area. Fractures predicted from geometric attributes and from the P-wave azimuthal AVO analysis are compared. The feasibility of two approaches for characterizing and mapping various types of fractures is investigated. Our results show that geometric attributes can better allow detecting and imaging subseismic faults and fracture corridors. The azimuthal AVO analysis allows detecting zones associated with both large scale fracture corridors and small scale diffuse fractures. However, the poor quality data and local geological structures may prevent from using obtained fracture predictions in a quantitative way. Integrating geometric attributes and azimuthal AVO analysis allows obtaining a comprehensive fracture distribution from fracture networks on the corridor scale to diffuse fracture distributions on the small scale. In this paper, case studies are used to illustrate how these two approaches can be integrated to provide a comprehensive multi-scale fracture distributions calibrated with well data and validated against the conceptual fracture models.
An Integrated Approach for Assessment of in-situ Scale Deposition Risk during Waterflooding in a Giant Carbonate Field, Offshore Abu Dhabi
Authors: Tariq Syed , Samad Saleh Abdul , Aouda Abdel Hakim , Afzal Mohamed , BenGherbia Mourad , Graham Gordon 
Published: November 2012

Abstract
A common flow assurance problem during waterflooding operations is the deposition of mineral scale due to mixing of incompatible brines. Deposition of mineral scale can occur anywhere in the production system (reservoir, near wellbore, wellbore, surface facilities) if certain conditions for deposition of scale are present (composition of mixed brine, dynamics of mixing, pressure, temperature and kinetics). Understanding where and how scale will deposit and its impact on production and operations is important especially for the mega offshore field development projects which use new generation of high value wells (long/multi laterals, MRC) associated downhole equipment (ICD, ICV, etc) and surface facilities. In this paper, we present a systematic approach to assessing the scale deposition risk with an example of the application to a giant carbonate field, offshore Abu Dhabi.
Multiplying Project Success for Future Growth through a Dedicated Project Management Support
Authors: von Pattay Patrick , Morrison Michael 
Published: November 2012

Abstract
It is kind of obvious that professional project management is a key success factor and differentiator for any exploration & production company. While revenues result from operations most of company's budgets are spend in projects and most value in the industry is generated through economically and safely executed projects.
Wintershall has a long track record of managing projects successfully. However, the question remains how to multiply these successes for further growth in an increasingly complex business environment. In 2011, Wintershall set up a project management support group providing projects and project managers with the required tools and guidance towards a standardized project management to achieve this goal.
This paper outlines the development of this group from the initialization to the final rollout. It describes the various technical and cultural challenges the project team had to overcome in order to establish a pallet of services tailored to the needs of Wintershall. These range from an online toolbox, on demand coaching to competency management and a social network for knowledge exchange. Finally, the authors reflect on the improvements in project management that have been achieved on several selected projects that the group supports directly.
Drilling and Testing of KOC's First North Kuwait Jurassic Horizontal Well - Case History of Well SA-297
Authors: Al-Saeedi M. J. , Al-Fayez F. A. , Al-Enezi D. , Mahesh V. S. , Al-Mudhaf M. N. , Jaikumar Jaikumar 
Published: November 2012

Abstract
Drilling activities have increased in the State of Kuwait to enable the production of more gas from the Jurassic formations. The wells drilled to these prospects are challenging because of HPHT conditions, sour reservoir fluids and narrow drilling window.
Only vertical and deviated wells have been drilled to date, and in order to augment the production requirements horizontal wells were planned. For effective development of these reservoirs, horizontal well profiles were planned to increase the ability of the wells to access a permeable interconnected vertical fracture network which could result in high productivity and reserve recovery.
After detailed study, well SA-297 was selected as an appropriate candidate for a horizontal pilot project. In this pilot, the objective was to drill the first horizontal well through the Najmah reservoir in the North Kuwait fields. The project, being the first of its kind, posed many challenges. These included: drilling and casing 16" hole at 60° well trajectory to 13,500 ft.; drilling the salt-anhydrite high pressure Gotnia at 60° inclination; drilling a slim pilot hole in the reservoir with K-formate WBM to facilitate positioning of the lateral; plug back this pilot hole and execution of a high DLS sidetrack just below 10 3/4" shoe; casing off formations with borehole stability concerns; drilling 6" lateral hole by geo-steering; tubing plugging concerns during DST testing.
Due to plugging of the tubing during testing, an intervention job was carried out with a workover rig to clear the tubing with coiled tubing in a live well and subsequently retrieve DST tools. This was a unique job carried out for the first time in Kuwait.
This paper will give details on the well construction, the complexities in the drilling operations and technical challenges faced while drilling the directional trajectory and in the special workover operations.
Impact of Mechanical Anisotropy on Design of Hydraulic Fracturing in Shales
Authors: Khan Safdar , Williams Rick , Ansari Sajjad , Khosravi Nader 
Published: November 2012

Abstract
Shale formations have laminated structures that result in directionally dependent mechanical properties. Conventional completion design approaches do not consider the material anisotropy or the laminated nature of shales. This can result in an underestimation of stresses, and lead to incorrect conclusions about the lateral landing points and the perforation intervals. In this paper, the authors demonstrate the importance of considering the anisotropy in the completion design using a case study from the Horn River Basin (HRB), the largest shale gas play in Canada. Shale formations in the HRB are strongly anisotropic with horizontal to vertical Young's modulus ratios varying from 1.2 to 3.5. Field data from the HRB is examined to evaluate the impact of mechanical anisotropy on break down pressure, fracture initiation and fracture containment. Numerical simulation of the completion design was conducted using a planar 3D fracture model.
Results of the numerical simulation indicate that the mechanical anisotropy greatly influences the minimum horizontal stress which in turn impacts the fracture containment and fracture geometry. Strong mechanical anisotropy results in lower fracture initiation pressures and lower tortuosity at the wellbore face. Consequently, selecting the landing point in sections with high anisotropy will minimize the fracture initiation problems. The authors conclude that the heterogeneous and anisotropic nature of shales needs to be properly characterized and taken into account when making decisions on lateral landing points and completion design.
Application of Inflow Control Devices to Maximize Oil Recovery in a Vertical Multilayer Well, South China
Authors: Tran Thanh Binh , XiaoPing Zou , Xiang Tian , Soendoro Feddy Himawan , Bolanos Nelson , Fould Jeremie Cyril , Ibrahim Muhammad Nasir , Guo Zhang Xing 
Published: November 2012

Abstract
In an offshore oil field in the southern East China Sea, the formations are sandstone and consist of six horizons, with specific flow unit characteristics and different aquifer support strengths. The operator intended to optimize the production with a permanent simple completion, in commingled production. However, the differences in reservoir properties and aquifer support presented a challenge for maximizing the oil recovery and delaying the water cut without resorting to well intervention.
Passive inflow control device (ICD) technology was used to balance the influx from the different formations and hence maximize oil recovery while delaying the incremental water production, and production data validated the benefits of the application by showing a water cut of 50%, in contrast to the expected value of 90% (without the ICD completion), with the same estimated amount of cumulative oil production.
Such a benefit is accrued by restricting fluid withdrawal from high-conductivity zones or with strong water drive, while providing enhancements to contribution from lower conductivity zones or zones with weaker water drive.
This method is not new in itself, but it has not been used before in a permanent completion system where well interventions had not been planned. Multiple production iterations using numerical reservoir modeling of several completion options were performed and showed a 31.3% oil recovery improvement over the base scenario (all zones commingled without flow control devices).
Advancements in the Abrasion Resistance of Internal Plastic Coatings
Authors: Lauer Robert S. 
Published: November 2012

Abstract
For more than 60 years, internal plastic coatings have been used for corrosion protection on tubing, casing, line pipe and drill pipe. One of the historic concerns with the use of internal plastic coating is the threat of mechanical damage and subsequent corrosion cell generation. Through the earlier years of usage of internal plastic coatings, applicators relied solely on enhanced surface preparation and adhesion to ensure minimal exposure of the steel substrate if damage were to occur. Even with this minimization, the potential for corrosion was still a concern for some. Due to this, a focus on developing internal coatings that offered higher degrees of abrasion resistance was initiated. At this time, several materials have been developed that offer abrasion resistances up to twenty times greater than what had previously been seen. These abrasion resistant materials allow internal coatings to be used in applications that were previously filled with alloys and GRE liners. These applications include: production/injection wells that rely on frequent mechanical intervention, rod pumping wells, completion string systems and environments containing high amounts of entrained solids. This paper outlines the development of these products including the different chemistries used and their abrasion resistance, impact, laboratory evaluation of their abrasion resistance and initial case histories of applications where internal coatings have historically been excluded.
Validation of Coriolis and V-Cone Meters Using Multi Phase Flow Meters (MPFM) in ADCO's North East BAB (NEB) Field - A Case History
Authors: Al-Hammadi Ibrahim Thani , Handak Aly Samir , Khan Mohamed Navaid , Gurses Hakan , Baslaib Abdullah , Younes Kamel Mohammad 
Published: November 2012

Abstract
Oil and Gas industry began to take attentiveness in developing Multi Phase Flow Meters (MPFM) in the early 1980s as the remote data access and improved performance with more compact mobile testing systems were the key features of the required technology. MPFMs were initially used in offshore industry; however, presently their applications are prolonged to land and even subsea installations.
For over ten years, Abu Dhabi Company for Onshore Oil Operations (ADCO) has been using MPFM in several oil fields and concession areas. Being relatively the furthermost recent developed field, clustering options, and full application of i-field concept including collaborative environment (CWE); North East Bab (NEB) Asset is crowned for being the frontrunner in adopting the up-to-date technologies among other ADCO Assets.
NEB full field development was custom-built in 2005. Fifteen (15) number of conventional three phase test separators were put together for reservoir surveillance and production testing requirement and were lately refurbished and upgraded with Coriolis and V-cone meters rather than originally installed turbine meters. During this period, two portable MFPMs were contracted out in order to achieve the annual testing KPI and prospect was taken to validate the Coriolis and V-cone meters of the refurbished test separators using MPFMs’. This project facilitated instituting better communication protocols along with comprehensive collaborative workflow between NEB Asset and the service provider that resulted in successful completion of the revamping project. This as well had tremendously encouraged ADCO (NEB Asset) to permanently include MPFM flow metering applications in the upcoming future developments.
This paper aspires to share the valuable experience gained by utilizing the MPFM in NEB Asset for different flow metering applications, and to establish the technology adoption guidelines for other field operators.
Exploring the Pre-Khuff: Technology and Play Based Driven Gas Exploration in Qatar
Authors: Harvey Craig , Molinaro Matteo , Zahran El-Demerdash Mamdouh El-Sayed , Taylor Andrew 
Published: November 2012

Abstract
In 2010, Qatar Shell Upstream International B.V. (QSUI) re-entered Exploration in Qatar focusing on the relatively deep conventional Pre-Khuff gas plays with a view to discover additional hydrocarbons in the State of Qatar. The Pre-Khuff plays pose two main challenges; firstly the geophysical challenge of being able to image the deep Pre-Khuff structure and hence trapping configurations and secondly the geological challenge of being able to realistically predict reservoir and top seal quality. This paper highlights the approach to geological issues associated with Pre-Khuff exploration and how technologies were deployed to address pre drill exploration challenges in the venture.
Significant uncertainty exists in relation to the deep structure of the Qatar Arch particularly when in the region the Pre-Hercynian package has been shown to be structurally different to the overburden. 2D seismic reprocessing has helped to significantly improve seismic imaging encompassing clear improvements in seismic data quality with better reflector continuity and elucidation of structural and stratigraphic complexity. The overall structure of the Qatar Arch and the trap styles in the Pre-Khuff are assessed using a combination of gravity anomaly data and interpretation of 2D seismic profiles, while incremental restoration of 2D seismic lines provides insight on the timing of trap formation.
The Devonian Jauf and the Permo-Carboniferous Unayzah plays are primary targets in Block D. Key petroleum system risks are taken as top seal retention, reservoir quality and charge timing and migration. To address these geological factors, data has been re-assessed and new work undertaken on stratigraphic definition, depositional models, reservoir quality prediction, integrated charge evaluation and seal integrity of the Pre-Khuff. Pre-Khuff top seal effectiveness in the focus plays have been assessed through MICP analysis and demonstrates that the relevant seals can hold back significant gas columns. Revised depositional models, based on core observations, have been used to extend potentially successful play fairways into Qatar. New petrographic analysis programs address the diagenetic controls on reservoir quality and their relationship with depositional environments aiding the prediction of potential net viable reservoirs at depths greater than conventional cementation floors. Integrated charge evaluation using basin modeling and geochemical techniques comprising Compound Specific Isotope, TOC, visual kerogen and chitinozoan reflectance analysis suggests a working petroleum system for Pre-Khuff reservoirs. 1D basin models suggest the Pre-Khuff on the Qatar Arch has received gas charge over the last 100 Ma but despite these favorable conditions, a key risk remains the presence of effective vertical migration pathways (i.e. faults) from the source rock into the prospective reservoirs.
Imaging the Pre-Khuff: Changing the Game with Innovative Seismic Technology
Authors: Molen Matthijs van , Wicker Jörg , Gouldesbrough Stephen , Zeylmaker Lammert , Strijbos Floris , Duijndam Bart , Joe Osman Yahaya 
Published: November 2012

Abstract
This paper highlights QSUI's approach to rapidly addressing the geophysical challenges associated with Pre-Khuff exploration. Based on legacy seismic data, significant uncertainty exists in relation to the deep structure of the Qatar Arch, particularly when in neighboring countries the Pre-Khuff has been shown to be structurally different to the overburden. Legacy seismic data shows reflectors below the Khuff which appear to mimic the Khuff and overburden structure. It is well known that seismic data in parts of the Middle East suffer from multiples which can exhibit amplitudes stronger than the primary reflectors. Recent work by QSUI suggests that existing seismic data is dominated by multiples at Pre-Khuff levels which make mapping Pre-Khuff structures challenging. One of the key exploration challenges facing QSUI is the ability to remove the multiples from the strong carbonate overburden interfaces to image the relatively weak primary reflections from the deep Pre-Khuff clastics.
In order to identify and understand the main generators of coherent seismic noise, QSUI has undertaken seismic modeling using VSP data, legacy shot records and full-waveform synthetic modeling. Results of this work steered the reprocessing of existing seismic and the design of a 3D Ocean Bottom Cable (OBC) seismic survey. The expectation is that the tailored seismic acquisition together with state-of-the-art processing algorithms will significantly improve the Pre-Khuff imaging and allow QSUI to select optimal well locations.
During preparation for the 3D OBC survey it became apparent that the level of potential hazards associated with shallow water acquisition warranted collection of high-accuracy bathymetry data. Traditional methods of ship-based multi-beam echo-sounder surveying, or aeroplane-based LiDAR measurements would have incurred significant HSSE exposure and would not have been available in time to be included in the tender documents for the seismic acquisition. As a result, QSUI deployed a new technology of satellite-based bathymetry estimation with significant operational benefits. This is the first time such technology has been used in the Middle East. Calibration of the resulting data set demonstrated that results are of sufficient quality for the design and operational planning of the seismic survey.
Technology Applications in Kuwait Oil Company to Reach Objectives Set in 2030 Strategy
Authors: Figarella Leo , Al-Mezel Fayez 
Published: November 2012

Abstract

Description
Since 2006, Kuwait Oil Company (KOC) has been implementing an ambitious production capacity growth strategy, aimed to develop an oil production capacity of 4 mmbd by 2020, and a non-associated gas production capacity of 2.5 bscfd by 2030.
Delivering these oil & gas production targets will require the development of new reservoirs and the optimization of existing ones. Lower API gravity, higher sulphur content in both oil and gas to be produced, the need to comply with more strict environmental regulations to reduce greenhouse gas emissions, together with increasing costs of materials and specialized services, all point towards an extraordinary efforts in terms of financial resources needed, development of execution capacity, implementation of organizational changes and optimization of internal processes, and application of advanced technologies.
This paper will describe the governance changes and new processes being implemented in KOC, such as the Programme Management Office and the Integrated Planning and Performance Management, as well as the application of new technologies to maximize production from existing reservoirs, including high resolution seismic, multilateral wells, Passive Inflow Control Devices, integrated digital fields and enhanced oil recovery.

Applications
As challenges faced by KOC are common to most oil & gas companies operating in the Middle East, sharing lessons learned in the implementation of governance changes and application of new technologies may be in the interest of participants of this event due to potential application on their respective companies.

Results and Conclusions
This paper will provide an estimation of expected gains in process optimization and oil & gas production increases as a result of the implementation of organizational changes and application of advanced technologies, with the primary objective to achieve production capacity goals set in KOC 2030 Strategy