bluuebunny/crossref_metadata_2025_split huggingface dataset:
Designing an Effective Leadership Development and Succession Strategy to Deliver Value Creation
Authors: Ewers Bjorn , Obied Tamer M. , Braun Philipp 
Published: November 2017

Abstract
One of the most important Human Capital topics at companies today is leadership development and succession planning. Hundreds of millions of dollars are expended each year preparing leaders for today's and tomorrow's challenges, however most companies never see a positive return on these investments because development programs are either not linked to drive business results or success planning is narrowly focused on those directly within sight.
The need for exceptional leadership at all levels has never been clearer. In a recent BCG survey of over 4000 leaders and HR leaders worldwide, respondents highlighted "Improving leadership development" as amongst the highest business priorities. However, respondents also highlighted that "Improving Leadership" was among their company's most significant weaknesses. Among the factors that handicap leadership initiatives are focus on certification versus learning, fragmented talent management systems, and a disconnect between capabilities and business strategy, and how to effectively identify and place rising stars.
BCG believes that the key to sustainable business outperformance is a tight link between leadership and value creation. Either done in isolation of the other leads to inferior, unstable outcomes. Taken together and tightly integrated with value creation, leadership development can be an engine by which companies consistently outperform against objectives—and competitors. Companies with strong leadership and talent management practices increase their revenues 2.2 times faster and their profits 1.5 times faster than companies with weak practices, according to a survey of more than 1,260 companies conducted by The Boston Consulting Group (BCG).
Upstream Data Architecture and Data Governance Framework for Efficient Integrated Upstream Workflows and Operations
Authors: David Richard Mohan , Saputelli Luigi , Hafez Hafez , Narayanan Ram , Colombani Pascal , Al Naqbi Tayba 
Published: November 2017

Abstract
Integrated Upstream workflows require efficient sharing of data across business disciplines involving planning studies, development, operations to carry our effective monitoring, surveillance of their reservoir and operations for better management of reservoir and production optimization. ADNOC requires quality, complete and timely multi-disciplinary data from its operating companies for efficiently monitoring its assets and provide informed directions.
An Integrated Data Architecture and Data Governance Framework is being established to enable efficient deliver data to execute integrated upstream workflows in a multi-disciplinary and multi-vendor technology environment. The framework facilitates to standardize, streamline G&G, reservoir, production, operations data and processes, and enables integrated reservoir management workflows and inter disciplinary collaboration in a multivendor technology environment.
The Framework provides guidance and best practices to build common data architecture foundation for integrated upstream workflows. The framework enables to efficiently govern the data across its lifecycle and makes the relevant business team and data custodians to take responsibility to validate, store and deliver static and real-time data in a timely manner for Integrated Upstream workflows. The framework components form a key foundation element for efficient integrated workflows towards realizing integrate operations, closed loop optimization, full benefit of Smart Field Investment.
Integrated Deployment of Digital Oil Field in Multiple Kuwait Areas in One Platform and Benefits Realized
Authors: Al-Rakyan Sara , Marie Omar Abu , Ledesma Fernando , Heshmat Kareem , Mohamed Assem , Zahourdin Mohamed 
Published: November 2017

Abstract
Instrumentation of artificially lifted wells located North, South-East and West of Kuwait was an essential requirement for real time surveillance of well behavior, and for successful implementation of a digital oil field. The manuscript focuses on challenges and solutions accompanied with setup of a SCADA intelligent software suite and replication configurations applied to remotely monitor and control assets for production optimization purposes.
Meetings have been held with Information Technology, SCADA and Well-Surveillance teams to agree on the technical requirements (server's specifications, network diagrams, well connectivity, data road map, data backup, security measures, disaster backup plan, etc…) The availability of having remote terminal unit built-in in the variable speed drive allowed instant access of real time data with ability to remotely control and modify running parameters for artificially lifted wells. Infrastructure has been built based on the company's standard IT security policies, by segregating network levels from field to domain network.
Well surveillance and field development teams from different areas targeted specific wells to be connected to the smart surveillance solution. Lining up different teams at the same time was a challenge to test, configure and confirm the successful connectivity. Integrating data from different areas/servers in one secure location was our main challenge to overcome. Replication of data was the only solution to assure a security channel that communicates between the different fields in to a single secured location with very limited ports to open and supervise. Wells were fully instrumented and equipped with the required gauges, sensors, and emergency shutdown devices, to evaluate well performance instantly.
Web based setup was the best solution for replicating real time data to the corporate level while keeping it secured and separated from the field network and available for all users accessible through end user system portal. Software acting as a real time data surveillance and historian with the remote access capability created a new level of effective surveillance. Management by exception became available at the corporate level to run failure statistics and identify areas for improvements by utilizing the current setup to optimize production and extend life time of equipment.
Achieving this level of surveillance helped in closely monitoring of well behavior, securely transferring and storing data, identifying operational needs of each field, and was considered as an extra level of surveillance. Successful deployment of the digital oil field in all areas of Kuwait integrated in one secured platform helped in utilizing all equipment available, increasing engineers' effectiveness to improve productivity, increase wells production, meet QHSE (quality, health, safety and environment) standards and reduce human risk.
Studies on Nanoparticle-Stabilized Foam Flooding EOR for a High Temperature and High Salinity Reservoir
Authors: Zhu Youyi , Tian Jing , Hou Qingfeng , Luo Yousong , Fan Jian 
Published: November 2017

Abstract
Foam is a mixture of gas and water where the gas is dispersed as bubbles in a continuous liquid phase. Foam flooding is one of chemical enhanced oil recovery (EOR) technologies by using foam fluid's "Jamin effect". Field tests showed that the EOR performances of foam flooding depend largely on both foamability and stability of foam under reservoirs conditions. To enhance foam stability, high molecular-weight polymer as stabilizer was generally introduced into foam solution. However, in high temperature and high salinity (HTHS) reservoir condition, this function of polymer was limited being the degradation of their large molecules. Therefore, it is necessary to call for an alternative stabilizing agent. DL offshore oilfield is one of HTHS reservoirs with reservoir temperature of 100-120°C and salinity of 34,370 mg/L, which has entered high water cut stage. The selection of EOR technique is very important for future development of such reservoirs. In this case, foam flooding with nanoparticle replace polymer acted as foam stabilizer was proposed. Nanoparticle-stabilized foam formulation was studied under the target reservoir conditions.
The nanoparticle-stabilized foam formulation was screened by static bulk foam tests. Though foaming agent and nanoparticle types screening tests, the effect of nanoparticle on the stability of foam system was investigated by measuring the foam properties of the foamability (foaming volume) and stability (drainage half-life). The distribution of nanoparticle size was analyzed. The injectivity and resistance factor (RF) of nanoparticle-stabilized foam fluid were studied on core flooding. Core oil displacement experiments of nanoparticle-stabilized foam flooding were conducted at the reservoir condition.
From the nanoparticle-stabilized foam system screening tests, α-olefin sulfonate (AOS) and fluorocarbon surfactant as foaming agent and clay nanoparticle as foam stabilizer were selected. The results showed that clay nanoparticle could greatly enhance drainage half-life of the foam system. More dense foam was formed in nanoparticle-stabilized foam fluid. Injection experiments of nanoparticle-stabilized foam on core showed a good injectivity when core permeability was more than 200 mD. RF of foam fluid showed that nanoparticle-stabilized foam had good mobility control function. EOR effect evaluation on core flooding indicated that foam flooding could contribute 17%-21% of OOIP incremental oil recovery under good operating protocols.
The experimental results were considered to be technical feasibility and effectiveness of nanoparticle-stabilized foam flooding EOR methods for DL reservoir, which might present further understanding for nanoparticle-stabilized foam flooding EOR field application on the HTHS reservoir.
Drilling Problems Detection in Basrah Oil Fields Using Smartphones
Authors: Saleh Ibrahim Abdul-Salam , Mahdi Bashar Saadoon , Al-Jawad Mohammed Saleh 
Published: November 2017

Abstract
Basrah oil fields contain many unresolved drilling problems, some of which are treated with difficulty, inefficiency, and sometimes leading to a more complex problem. These inefficient problems handling procedures lead to a longer Non-Productive Time (NPT). This lack in efficiency often comes from inadequate preparation, or the slow decision making in the detection of the drilling problems. The main objective of this study is to provide the optimum solutions for the drilling problems in Basrah oil fields on smartphones to achieve credible and quick treatments anywhere on the field.
Tracing of the problems, the gathering process of the field data, and the analysis of the field procedures to treat a problem, all of which were difficulties and challenges faced. Field data deficiency was confronted in many stages.
Throughout this paper, strategies of treatment procedures for the problems that could be encountered while drilling in Basra oil fields are discussed such as Dammam formation's losses, Tanuma's shale instability, Mishrif's special treatments so as not to damage the reservoir, and many others. Discussion of every formation that is drilled from the surface to Mishrif formation will be carried out with the explanation of the problems that was faced in offset wells, in addition to the problems that have a possibility to happen in each formation. The treatments for each problem were based on past field experience and standardized procedures. All of the formations, the problems, and the treatments are constructed in an application called Problems Detector 1.0 (PD) that functions on smartphones that obtains a familiar user interface and can be used anywhere on the field. Two advanced programming techniques are used to construct PD using an Object Oriented Programming language (OOP) that is java, they are the classify algorithm and a well secured database used to enhance the application's capabilities to detect problems and secure the wellbeing of the data that are mounted in PD, respectively.
As a result, a full database of the drilling problems in Basrah oil fields has been constructed. All the problems that could be tackled while drilling with the possibility of their occurrence, the causes of these problems, the indications of the problems on the rig, and the treatment of each problem were all parts of the database set in PD.
Smart phones showed very high efficiency and speed in determining the problems and presenting the solution which can be used on field by the drilling engineer and/or the driller, therefore; the presentation of smartphones to the petroleum industry has proven its importance and value.
Big Completions to Recover More Hydrocarbons from Oil Producing Wells with High Water Cut in Prolific Reservoirs - A Paradigm Shift
Authors: Channa Zohaib , Ahmad Fazeel , Khan Muhammad Navaid , Nofal Salman. F. , Al-Hosani Ibrahim. A. , Al-Shehi Omar Y. , Al-Neaimi Ahmed K. 
Published: November 2017

Abstract
The selection of optimum tubing size is one of the most critical steps in achieving the desired well productivity and prolonging the well life to maximize the hydrocarbon recovery; and it becomes more important for the naturally flowing well. It is a common industrial practice to reduce tubing size for extending the well life when a naturally flowing oil or gas well ceased to flow post experiencing the water breakthrough. Contrary to this general belief, an extensive piece of work has been carried to assess the well performance in high productivity (prolific) oil reservoir. In this paper, an actual case study is presented which demonstrates the overall better performance of a well completed with the bigger tubing size in a high productivity (prolific) oil reservoir. The study also compares the performance of the well completed in low productivity reservoir in the same field, which shows that the use of the bigger tubing size is a better option for sustaining the well life, hence negating the traditional industry belief of reducing the tubing size post water breakthrough into a well, regardless of the prevailing reservoir characteristics.
Accurately Locating Casing Collars in Real Time with Drill Pipe Deployed Gamma Ray Density Measurement
Authors: Dorsett Ashton , Lopes Priscila , Fang Lei 
Published: November 2017

Abstract
Ability to identify casing collars in real-time is critically important for whipstock casing exit operations, because milling through casing collars could cause significant loss in rig time, excessive damage and even failure of downhole equipment, and potential blockage of the exit window by casing collar spinning. Running wireline to identify casing collars is the typical solution to address the challenge, but incurs additional rig time and cost. This paper present a new technology to locate casing collars in real time with Gamma Ray density measurement, deployed on drill pipe, eliminating the need for a dedicated wireline run. Multiple case histories of field testing the technology in North Sea, covering a wide range of casing sizes from 7-in and 18 5/8-in, are presented as well.
The Gamma Ray density measurement is used for identifying casing collars by detecting the differences in density readings between collar and casing. Gamma rays are continuously emitted from a nuclear source as the density tool moves in the wellbore, and the readings of the near and far detectors, after signal travels through and interacts with casing and formation, are interpreted to calculate density. Density readings are transmitted to surface in real-time through mud-pulse telemetry and are processed to visualize casing collar locations in a log.
The new technology was successfully field tested in North Sea in multiple wells covering a wide range of casing sizes, from 7-in up to 18 5/8-in, with different depths and inclinations. The operational processes and results from the field tests are discussed in this paper. The casing collars were successfully located in each field test, proving the robustness of the technology over a broad range of application parameters. It was discovered from the field tests that the bottomhole assembly (BHA) configuration, tool orientation, tool string rotational speed, sensor standoff and logging speed are critical to clearly identifying casing collars.
This paper presents a new method of using the drill pipe deployed Gamma Ray density measurement to detect casing collars in real-time to optimize whipstock placement for improved reliability and efficiency of casing exit operations. It also provides the best practices of applying the technology in a wide range of well and casing configurations.
Abu Dhabi Structural Evolution and Its Implications for Exploration
Authors: Richard Pascal , Zampetti Valentina , Volery Chadia , Gesbert Stephane , Krayenbuehl Thomas , Spaak Michael , Murzin Shamil , Neves Fernando , Hosani Sabah Al 
Published: November 2017

Abstract
ADNOC and Shell are currently joining efforts to rejuvenate the exploration portfolio of Abu Dhabi. A country-wide integrated petroleum system study is being carried out to identify new play concepts and opportunities. One of the foundations of this study is the understanding of the structural evolution and its impact on prospectivity.
A structural evolution model has been developed using 2D and 3D seismic data and the country has been divided into structural domains. The extent and quality of the seismic dataset provided a unique opportunity to investigate the country wide structural evolution. Special care has been taken to generate seismic attribute volumes that enhance sedimentary features and fault visualization. This allowed the detailed assessment of fault displacement. In addition, mapping of the edge of carbonate platforms through time at the country scale allowed the identification of long wavelength tilts of the Arabian plate in Abu Dhabi. These observations have been linked to the regional phases of deformations. The most important phases of deformation that affected the trap formation are the Jurassic rifting, the Late Cretaceous transtension, and mid Tertiary compression.
The country has been divided into specific structural domains using existing structural features. These structural elements comprise NS and NW-SE striking basement features, forced folds associated with basement features, drape folds associated with salt domes, and NW-SE and NNW-SSE conjugate sets of transtensional faults zones associated with pop-up structures.
With the help of sandbox experiment analogue models as well as field analogues from Oman, we propose that the Late Cretaceous transtensional faults are decoupled from basement and do not root into any deep basement faults. We also propose a series of conceptual 3D fracture diagrams per structural domain.
Seismic Stratigraphy and Depositional Evolution of the Mishrif Formation in Western Onshore Abu Dhabi
Authors: Perrotta S. , Zampetti V. , Chaari G. , Krayenbuehl T. , Braun M. , Franco B. J. , Neves F. , Kobaisi A. Saad 
Published: November 2017

Abstract
A sequence stratigraphic study of the Cenomanian-early Turonian Mishrif Formation has been carried out in the SW of the United Arabian Emirates (UAE) in order to understand the evolution of the reservoir distribution and occurrence of potential stratigraphic and diagenetic traps in the UAE.
The study has used an integrated reservoir approach that includes regional geology, seismic stratigraphy together with well data. The use of the core data and logs has allowed identification of facies changes, key stratigraphic surfaces and a number of a few feet thick dense intervals that show a relatively high lateral correlatibility, which appear to be below the seismic resolution. The use of seismic attributes together with the well calibration has been crucial to define seismic facies and their lateral and vertical distribution.
Results from this study allowed recognition of several smaller scale 3rd order cycles, which are comprised in a larger 2nd order genetic sequence. Each small-scale cycle is bounded by a sequence boundary overlain by a flooding event made up of a thin dense interval which shows an increase in argillaceous content and locally chert. These sequences are characterised by an eastward progradation from muddy inner ramp facies passing upwards to rudist-rich patch reef/mixed skeletal shoal complexes developed in an inner to mid-ramp depositional setting. This latter setting appears to be best developed in the uppermost large-scale sequence, below the regional unconformity that separates the Mishrif from Ruwaydha and Tuwayil formations. Highly porous facies appear to decrease seismic velocity.
The integrated approach presented here captures the variety in depositional environments, architecture, geometry and reservoir heterogeneity, which results in higher likehood to identify stratigraphic and diagenetic traps.
Furthermore, the recognition of seismic characteristics of the Mishrif reservoir may be used as a tool to predict the distribution and evolution of units that create velocity variations in the Mishrif Formation and which affect the structural definition of deeper reservoirs as the Shuaiba Formation.
Well Abandonment of Offshore Aging Gas Fields Using New Section Milling Technology Reduces Time and Costs to Set a Permanent Barrier- A Case Study of Section Milling 100 ft of 13-3/8" Casing to Set Cement Plug
Authors: McTiffen Dean , Iversen Glenn Tore , Smalley Michael , Haq Mohammed Aleemul 
Published: November 2017

Abstract
In recent years plug and abandonment (P&A) technologies are receiving greater attention around the world as more and more fields reach the end of their productive life. Permanent P&A is done with the objective of the well being sealed and isolated forever. Over the years the market for permanent P&A has grown into estimates of several billions of dollars. There are thousands of wells world wide, both onshore and offshore, that require P&A operations to safely abandon the erstwhile producing asset while maintaining environmental regulations and standards. Since the P&A operations do not result in increase in revenue or any asset value, the attitude of almost all operators is that the least amount be allocated towards this operation in the well life cycle plan. This means that newer technologies must be developed in order to increase efficiencies and reduce the overall costs and foot prints for P&A operations. Many times existing conventional technologies do not fill in these requirements, and thus there is a need to develop and deploy newer downhole technologies.
This paper will discuss well abandonment P&A introduction, methods for preparing a well before setting cement plugs, a brief comparison between different methods, development of section milling technology to dual string, field application on an offshore gas field abandonment campaign, and finally conclusions regarding this new and emerging dual string milling technology.