bluuebunny/crossref_metadata_2025 huggingface dataset:
Delineation and Extraction of Karst and Other Collapse Features in a Giant oil Field, Offshore Abu Dhabi, UAE
Authors: Edwards Henry Ewart , Lakhlifi Assia , Manral Surender , Jan Kamran Saeed , Al Dhaheri Amna
Published: November 2012

Mapping karsts and other collapse disturbances in overburden is a challenge in a heterogeneous carbonate environment, as they are often poorly expressed features on 3D seismic amplitude data due to their inherent complex shapes, lateral variability and contrasting fill material density. Seismic attribute analysis combined with 3D seismic volume rendering and extraction techniques provide a significant amount of detailed information about karst and other collapse dissolution features in a Giant Carbonate Field Offshore Abu Dhabi, UAE. Traditional horizon-based attribute analysis, tedious and time consuming in these scenarios, can also reveal inadequate information about connectivity and volumetric extent of karsts or other collapse features.

Understanding the distribution of these features and connectivity in a 3D sense is crucial for velocity models, structural modeling of surfaces beneath such bodies and operationally as features to avoid whilst drilling to ensure drill-well integrity. A structural framework incorporating the impact of such features can be achieved by volumetric attribute generation followed by delineation and extraction of such features that are connected in a 3D sense.

This paper describes a workflow to carve out karst features dominant within the shallower Paleocene-Late Cretaceous section of the seismic data. It involves multi-trace volumetric seismic attribute-conditioned amplitude data that facilitates improved recognition of these features, providing detailed outlines of their geomorphology and infill. Advanced 3D volume rendering and applying a ‘geobody’ technique helps to discriminate the complex shapes and variability of features from their surrounding rock mass and were used to pick key examples of these features. Using the opacity control, connectivity of the body's outline and connectedness of smaller associated satellite ‘karsts’ can be displayed and extracted. Karst infill material, having slower velocity, causes the reflectors to sag in some places. In such instances a velocity seismic cube was used in this case.
Study Geophysical Response of Middle East Carbonate Reservoir using Computational Rock Physics Approach
Authors: Zhan Xin , Fullmer Shawn M. , Lu Chih-ping , Harris Christopher E. , Martinez Alex
Published: November 2012

This paper provides a new computational rock physics study of middle east carbonate rock. Computed elastic and electrical properties from real rock micro-tomographis and constructed 3D sphere packs build direct link between rock microstructure and its elastic, electrical responses. Multi-resolution CT scans (resolution varying from nanometer to micron) are taken for carbonate core samples belonging to different facies from middle east carbonate reservoirs. Different carbonate petrophysical pore types shows clearly different pore structures (pore shape, size, connectivity). Laplace equation and linear Stokes equation are directly solved on those 3D rock micro-tomographis to compute electrical conductivity and hydraulic permeability using finite difference method (FD). Elastic properties (Vp, Vs, bulk modulus, shear modulus, Young's modulus and Poisson's Ratio) are computed by solving linear stress-strain relationship using finite element method (FEM). To further extend predicting capability, a family of 3D model granular porous media with different porosity, pore (grain) aspect ratio, pore (grain) size distribution, pore connectivity and spatial arrangement are built to represent different carbonate petrophysical pore types. Results for different carbonate facies (Wackestone with roundish micropore system (microporosity); Grainstone, Packstone with interpartical pore (IP) system; Rudstone with vuggy porosity and IP frame) are shown. Measurements on core plugs compare well with modeling results and computed values. We can rigorously determine the pore geometry related parameters in effective medium based model (Xu-Payne model) from numerical computation to interpret and predict log response for upscaling. Finally, AVO seismic forward modeling is built to quantify porosity, fluid saturation and lithology (facies) effect on seismic response for middle east carbonate reservoir. A complete study at pore and core scale, log scale to seismic scale is achieved. Conclusions and recommendations on inverting porosity, fluid saturation and carbonate facies from pre-stack seismic in carbonate reservoir are given at the end.
Physics and Modeling of Gas Flow in Shale Reservoirs
Authors: Alharthy Najeeb , Al Kobaisi Mohammed , Torcuk Mehmet A. , Kazemi Hossein , Graves Ramona
Published: November 2012

Gas transport in nanopores is a combination of several flow mechanisms: gas desorption, advection, molecular diffusion, and Knudsen / slip flow. The gas storage in the reservoir pores includes compressed free gas in larger pores and adsorbed gas on the organic and inorganic nanopore walls. While the conventional approach of modeling gas flow in unconventional reservoirs does not capture the relevant physics accurately, it has been successfully used by engineers to match reservoir history and predict future performance. Both single-porosity and dual-porosity approaches have been used in such efforts.

For this research, both a dual-porosity and a triple-porosity finite-difference (FD) model for single-phase flow of a multicomponent gas were developed which include advective, diffusive, and Knudsen flow mechanisms. Numerical solution for a dual-porosity, single-component model with advective and Knudsen flow contribution was validated using a new analytical unsteady-state solution. The multicomponent models account for material balance for all components as well as for the molecular interaction during flow. The purpose is to evaluate chromatographic separation of components during the reservoir life. In this paper, however, only the single-component results are presented. The current results indicate that the models’ performance are consistent with field observations and favor the presence of inter-connected microfractures in the drainage volume surrounding horizontal production wells.
A Predictive Maintenance Strategy based on Real-Time Systems
Authors: Chandran Dileep , Rodriguez Ramon , Anandan Aji , Saber Shehata
Published: November 2012

A Predictive Maintenance Strategy based on Real-Time Systems

Description

The optimization of preventive maintenance forms the backbone of successful proactive maintenance scheduling. This paper describes the components of a real-time information system and the modeling criteria used for a predictive maintenance strategy.

Components of a real-time system

Data Acquisition uses sensors and data conversion to measure, standardize, and transmit the operational parameters and environmental conditions.

Historian databases record the operational parameters over time. The historian database supports multiple data collection points from sensors, rig scheduling, and planned operations in SAP systems using standard protocols.

Modeling and Analysis tools use the information in the historian database to build response models and predict changes in the equipment performance. These tools include data access, algorithmic modeling, visualization, and alarm subsystems.

Predictive Model

The predictive modeling of equipment performance uses equipment specifications, past performance, and current performance measurements. Normal operational windows are used to generate out-of-normal alarms.

All relevant operational and environmental parameters are correlated to create normalized performance curves. The trends are calculated to extrapolate changes in equipment performance and determine future failure points. The maintenance windows are matched to planned operational phases to determine the optimal windows for maintenance.
The Magic of Dynamic Relationships for Project Success
Authors: Subaih Adel Bin
Published: November 2012

This paper shows how individual employee needs and dynamic interactions, relationships and team building initiatives, implemented by ADCO with their EPC CONTRACTOR, have contributed to successfully managing one of their recent projects. The paper looks at the ‘Joining Effort’ of all personnel for a single interactive dynamic team, whilst considering the Project Management areas of Leadership, Management Structure / Change and Conflict Resolution. An added parameter was to ensure the technical production was to a high standard.

From previous projects, major challenges experienced in project management have been many. The issues were all listed with the possible effects project wide.

After all the challenges to the ‘health of the project’ were listed, solutions were identified in the following areas; install strong leadership, management structure/tools in place, one integrated team, taskforce champions, document composition for complex documents, aligning the document production with time, identifying resources shortfall, identifying quality issues, containing cost through design, employee needs and recognition, team building exercises and conflict resolution.

Various theories (Maslow, Hertzberg & others) involving emotional, psychological and motivational areas were investigated. These verified that the solutions put in place should work. The results proved positive. Primary points were; attitude change (self esteem/self-actualization), strong trust and low conflict. These aspects led onto many more beneficial results, especially within the team framework. The added ‘Technical’ parameter looked into the effect of having a technically sound project as compared with a not so technically sound project.

There is no Magic for creating the project success that everyone is trying to achieve. But probably it could be described as a magic dynamic formula involving the employee, the team and the technical. The project is on time, to budget, of good quality and with safety covered. Being pro-active and identification of possible problems up front, allows solutions to be put in position. Bringing all personnel (the project teams) together, to act as one unit, is a pre-requisite for this to happen.
Improving the Uncertainty Understanding for the Optimal Development of an Abu Dhabi Offshore Green Field
Authors: Lacroix Sebastien , Al Badi Bader
Published: November 2012

Quantifying, ranking and weighting of reservoir uncertainties are a key element in evaluating the development plan of a green field. Due to the limited amount of data and its accuracy, it is of prime interest to assess the risk related to a development plan in terms of potential recovery. Once quantified, mitigation plans or probabilistic optimization can be derived in order to minimize the risk and maximize the recovery.

The risk assessment of the development plan in this study was applied to a new offshore field of Abu Dhabi. The stochastic uncertainty analysis consisted in defining the main variables contributing to the risk on ultimate recovery and ranking them using uncertainty and risk analysis tool.

The results highlighted a strong impact of fault sealing capability and residual oil among other parameters together with a dependency of the parameters’ impact to time. Given these uncertainties it could then be identified that the current FDP was most likely overestimating the actual P50 and that remedial actions shall be put in place to acquire more confidence in the data.

Eventually an optimization under uncertainty provided a better insight on the optimal field rate during the production plateau and required shut-in water cut for producing wells in order to maximize the field recovery.
Engineering, Procurement, and Construction Challenges of Oil and Gas Artificial Islands in the Arabian Gulf, Part 1
Authors: El-Gharbawy Sherif , Sarhan Hazem , Khaled Mootaz , Seddik Sameh
Published: November 2012

Capitalizing on the UAE's wide experience in the field of land reclamation and artificial island technology, the Abu Dhabi oil and gas industry, represented by ADNOC group of companies, is currently deploying an array of islands across Abu Dhabi's Exclusive Economic Zone in the Arabian Gulf for applications such as new field development and the upgrade or expansion of storage and offloading facilities. With favorable water depths and environmental conditions, land reclamation is often a more economical option for the accommodation of offshore facilities than the construction of fixed steel jacket platforms. ADMA-OPCO is currently engaged in applying the technology to projects such as the Satah Al-Raaz Boot (SARB) field development, a 105,000-bpd development comprising 86 wells on two artificial islands. Simultaneously, ZADCO is making progress on expanding drilling from the Upper Zakum field by constructing four artificial islands (UZAI) to increase field production to 750,000 bpd by 2015. While cost and schedule optimization will be realized with the selection of the artificial island option for these mega projects, designers and contractors are facing the challenge of securing or fabricating building materials in huge amounts for the construction of both the land masses and shore protection structures. Creative solutions to procuring these materials are tabled and investigated. Innovative engineering designs are tried and tested both numerically and using physical model tests. The presence of a soft soil layer within the foundation strata of one of the Upper Zakum islands required special treatment to satisfy island performance criteria. Schedule constraints of construction and fulfilling ADNOC's strategic production objectives continue to be the driving forces behind the resolution of all challenges.
Getting the Right Mix of Maintenance Strategies with Historical Facts
Authors: Salim Sajam Ebrahim
Published: November 2012

One of the key aims of any industry, especially petrochemical industry is to ensure safe operation of their plant, distinguished by maximum availability & minimized operating cost. Maintenance measures have been optimized specific to application with increased level of automation. In-spite of these efforts an optimum maintenance management is fatigued with the risk linked to reliability and availability. An orderly method of predictive, condition based and reliability centered maintenance is far from identifying and preventing the victimized failures across the industry. The idea presented is conceptual with practical inclination and in most cases is applicable to any advanced maintenance strategy implementation.

This paper initially intends optimizing maintenance plan accounting best practices and established measures which allows experience and findings in multiple plants to be explored by all participants on a common platform. Secondly, tagging a historical database on critical equipment's unexpected failures and its root causes in CMMS helps realizing health-focused maintenance. Such failure mode analysis greatly minimizes chance for failure re-occurrence. This concept, Factual maintenance, is a plant-neutral maintenance strategy which adds value to their competitive position in significantly reducing surprise failures and considerable improving MTBF.

The best practice of factual maintenance is during acceptance testing and commissioning. Identifying defects from manufacturing or installation or due to unintended mode of operation is not unusual during acceptance process. Maintaining critical or application specific facilities during O&M phase shall adopt cross plant experience rather restricting to sole type of maintenance practiced.

The paper analyzes the current maintenance strategies & how embedding history based knowledge and linking operators into work management will yield most efficient risk reduction. There is no single maintenance strategy suiting all situations, however a blend of maintenance management strategy shall be required for plants with multi critical equipments with varied life span. A right amount of preventive maintenance as well as predictive maintenance is required along with a FMEA to minimize unexpected failures. Structuring a maintenance program based on equipment needs and priorities together with best practices and lessons learned across the varied sites yields greater maintenance effectiveness & asset reliability.
Pipeline Integrity Management
Authors: Wenman Tim , Dim Joe
Published: November 2012

Various worldwide, high profile asset integrity incidents have heightened attention to the integrity of pipelines in recent years.

Setting Shell's corporate strategy for Pipeline Integrity provides interesting opportunities for capturing best practices from a diversity of operating units and environments from around the globe - from the frozen arctic like conditions of Sakhalin, to highly sour service in Canada, the tropical climates of Brunei and Malaysia, and operational challenges in Nigeria to increasingly regulated environments in the USA and North Sea.

Key components of an effective Pipeline Integrity Management System (PIMS) include:

Organisation/Roles and Responsibilities, Standards and Procedures, Competencies and Technical Authorities, Asset Registration, Risk Assessment, Maintenance & Integrity Work Plan, Data Management, Integrity assessment and verification, Reporting of Compliance and Integrity Status, Management of Change, Emergency Response, Reviews and Audits.

This paper will discuss the framework for effective Pipeline Integrity Management within Shell to ultimately meet the aspiration of "Our [pipeline] assets are safe and we know it" and can show it to the various stakeholders.
Gaussian-based Estimation of Distribution Algorithms for History Matching
Authors: Abdollahzadeh Asaad , Christie Mike , Corne David
Published: November 2012

Numerical reservoir models are used to predict, optimise and improve production performance of the oil and gas reservoirs. History matching is required to calibrate reservoir models to dynamic behaviour of the reservoir. On the one hand, historymatching does not have a unique solution and multiple models can fit observation data, on the other hand, history-matching is a tedious and time-consuming trial and error process as it involves numerous reservoir simulation runs. Modern history matching techniques use optimisation algorithms aim at providing a set of good fitting models in an efficient time.

Many optimisation algorithms are applied in history-matching. Of them, Evolutionary Algorithms (EAs), inspired by natural evolution, do not use gradient information from the optimisation problem and only require the fitness function, usually defined as the sum of squares root deviation of model response from the observation data. Estimation of distribution algorithms (EDAs) are a novel class of EAs developed as a natural alternative to genetic algorithms in the last decade. To date, many EDAs are introduced which differ in the probabilistic model that guides the search process. Most of the EDAs are designed for discrete problems and require discretisation of search space when used for continuous problems, e.g. in history matching. In some cases, discretization error can be significant and deteriorate the search process.

Gaussian-based EDAs use characteristics of Gaussian distribution for multivariate continuous problems. i.e. they make use of mean and covariance matrix of the variables in the promising solutions to generate new solutions which fit better the observation data. In this paper, we introduce and for the first time apply four Gaussian-based EDAs to assisted historymatching of a standard synthetic case. We show our proposed algorithms may produce results more accurately and more efficiently for the continuous problems.
Re-Writing the Rules for Managing Change in ADCO
Authors: Malik Jamal Abdul
Published: November 2012

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

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

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

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

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

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

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

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

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

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

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

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
Multilateral Drilling Under Challenging Conditions
Authors: Hariri Nour , Al Subhi Isehaq , Al Sharafi Mohamed , Nasrumminallah Nasr , Al Balushi Said
Published: November 2012

Since early 2010, one of the producing oilfields located in North of Sultanate of Oman required drilling optimization to sustain the development of the field and triple its production. The objective was to drill infill wells to maximize the reservoirs’ ultimate recovery. A secondary objective was to replace some of the mechanically completion-failed multilaterals with new horizontals. A six-well campaign was launched aiming to improve the well delivery and reduce the authority for expenditure (AFE) costs. The campaign targeted the drillability of the wells with major collision risks, hole cleaning and casing running in unstable shale formations, and well placement in a 2 m thickness reservoir eliminating unnecessary sidetracks.
High-Resolution LWD Resistivity Images for Carbonate Facies Identification and Geosteering
Authors: Mahiout Said
Published: November 2012

Accurate placement of the borehole within the reservoir and identification of features impacting producibility are key elements for success. Experience to date, shows that the drilling environment offers a good platform for high definition electrical borehole imaging. At the time of drilling, invasion and borehole wall rugosity are often minimal and electrical images generated by sensors that rotate with the drill string provide a full coverage of the borehole. It also provides an opportunity for real-time geological analysis while drilling and the decision making that is unavailable with wireline. Detailed analysis of images reveal discrete sedimentological and textural features aiding facies recognition in carbonate reservoirs. These facies can be up-scaled to facies associations and eventually used for depositional environment interpretation. This leads to wider prospect delineation and confirmation of the local geological model. The study also demonstrates the strength of early geological information in high-resolution for reducing geological uncertainty at an early development drilling program.

We show case studies from several carbonate reservoirs in which high resolution electrical images have been acquired in conjunction with reservoir navigation (well placement). From post well analysis, we can define the key criteria that help in recognition of reservoir position; correlatable sedimentary surfaces and image facies/patterns. We test the distribution of facies and sedimentological features that can be recognised in horizontal boreholes by comparison to vertical offset wells, in addition to automated facies recognition from image log responses. The development of a Sedimentary or carbonate facies steering technique using high-resolution images with a predictive and real-time interface will reduce uncertainties related to and better aid geosteering within the desired "sweet-spot" of a variety of clastic and carbonate reservoirs.
Pore Pressure Prediction Challenges in the Middle East Region
Authors: Khazanehdari Jalal
Published: November 2012

In many hydrocarbons-prone provinces of the world (the North Sea, Gulf of Mexico, West Africa, Caspian and other areas) abnormal pore pressures have now been widely observed. Accurate assessment and prediction of pore pressure and fracture gradient formed an essential part of the planning process particularly for exploration and deep drilling where no or limited pressure data are available.

Although the fundamental objective for pore pressure imaging is to provide pressure data ahead of drilling, the pore pressure analysis should be carried out at different stages of the drilling: (i) Pre-drill (using seismic and rock models), (ii) while drilling (act as support and update using real-time data) and finally (iii) post-drill (support role and improve pressure evaluation of an area).

An estimation of pore pressure can be obtained from seismic velocities where disequilibrium compaction is the dominant pore pressure mechanism during all the three mentioned stages (pre-drill, while drilling and post-drill) by using a velocity-to-pore pressure transform. However, the borehole or/and surface seismic velocities must be the true estimation of the interval velocity of rocks as well as of adequate resolution particularly for well planning purposes. In case of presences of other pore pressure mechanism such as hydrocarbon generation, Osmosis, etc, the industry still does not have a established method(s) for pore pressure prediction and often such mechanism are ignored due to their complex nature and lack of predicative methods.

Here, after reviewing the pore pressure challenges and mechanisms in the Middle East, we discuss the importance of the key pore pressure mechanisms such as; disequilibrium compaction, fluid migration, hydrocarbon generation.