bluuebunny/crossref_metadata_2025_split huggingface dataset:
2010 and Beyond: Managing Talent in the New Age
Authors: Qutob Shereen H. 
Published: February 2011

Abstract
The 2009 recession has shifted the global response to our challenge of “attracting” and “retaining” talent. The average retirement age has extended by at least 5 years with the Boomer generation stretching their stay to adapt to the changes and it is a struggle to lure Generation Y and the “Millenial’s” into the workforce.
The investment in people must become a number one priority. Changes in the global conditions should never impact these investments because the “pay off” always outweighs the cost. The industry cannot talk its way out of something it behaved its way into. So now we need to “walk the talk” and really test our resolve to putting people first.
Talent management plays a critical role. The need to strategically identify, attract, develop, and retain our key talent is crucial and will be the competitive advantage in an age where ‘cost-cutting’ is the word of the day. There is a definite struggle between keeping costs down yet having the foresight to make the investments today.
The dramatic cycle we have been through has shined a new light on career development. Employees now know that they need to take the lead on their own progress. No longer are careers made of a linear “up or out” approach. The dynamics of the workforce have changed considerably and we must adjust as an industry and catch up to accommodate our diverse workforce. Careers are now made up of lattices instead of ‘vertical ladders’ so employees can make lateral or downward moves at different points in their career. Careers will now encompass a multi-faceted path that includes moves into different functions, technologies, and geographies.
The career rules that applied in the past decade no longer apply. Organizations must now become as authentic as they can and put their talent agenda at the forefront. The higher the investment in leadership development and feeding the talent pipeline the bigger the payoff for generations to come. Now is the time to energize this new dynamic workforce about working in such a fast evolving industry. Let’s start talking their “talk”. This is the ‘Facebook’, ‘Twitter’ and ‘Linkedin’ generation. The opportunities to engage this demographic are endless and we can only solve the challenge of the looming shortage and “crew change” by changing the way we “think”.
Gen Y doesn’t want to come to work and become CEO the next day, but they want to learn and be mentored. Within the next 5 years over 50% of our workforce will comprise of Gen Y and the traditionalists and boomers will be well on their way to retirement. Today we’re in oil and gas and traditional energy markets; tomorrow who knows? How can we leverage the best of both worlds and groom these leaders of tomorrow to face the ever challenging terrains? The answer will depend on what leadership seeds we have planted that will yield future leaders who are fluent across multiple disciplines and geographies.
Wettability Profile of a Thick Carbonate Reservoir by the New Rise in Core Wettability Characterization Method
Authors: Ghedan Shawket , Canbaz C. Hakan , Boyd Douglas , Corelab George Mani , Haggag Marwan 
Published: February 2011

Abstract
The evaluation of the reservoir wettability is fundamental to the understanding of fluid flow in porous media. Wettability has direct impact on saturation end points and the shape of capillary pressure and relative permeability curves. This will, in turn, directly affect the relative movement of the reservoir fluids and eventually affect the displacement efficiency of oil by the different injected fluids. Having reliable wettability data deems very necessary for reliable predictions of expected oil recoveries under different development options.
The Amott and the USBM tests are the most commonly used methods for quantifying reservoir wettability. Combination of the two methods is also in use. In addition to the elaborate experimental effort and time required for these methods, the USBM method does not recognize very strongly water or oil wet systems, while Amott method fails to distinguish between important degrees of strong water and oil-wetness.
This paper describes a new technique, the Rise in Core (RIC), wettability characterization method based on a modified form of the Washburn equation. It enables relatively quick, accurate measurements of wettability in terms of contact angle and not wettability index as the other methods do. The method is easy to use and requires no complex equipment. During the RIC experiments, core samples saturated with one reservoir fluid are subjected to imbibitions from a second reservoir fluid. As the imbibition process takes place, the core samples weight changes continuously due to adjustments in relative saturations of the two fluids. Monitoring the square of the core mass change with time using a high precision balance, the acquired data is analyzed with modified Washburn equation to determine the cores wettability.
For the sake of assurance, RIC wettability measurements were compared to ambient conditions modified Amott-USBM measurements for a thick limestone oil reservoir using core plug pairs from different heights above the free water level. The results compare well. The RIC technique proved to be much simpler to construct, much faster to perform and much easier to analyze and interpret than traditional methods. Moreover, the method gives the operator a chance to evaluate the uncertainty in the wettability data.
Reservoir Test Optimization in Real Time with New Wireless Telemetry System
Authors: Al-Nahdi A. A. , Abo Elsaud T. S. , Lemenager E. , Loth M. , Mabrouki F. , Acar C. 
Published: February 2011

Abstract
A new wireless telemetry system has been field tested in a variety of conditions in Saudi Arabia with excellent reliability. This wireless system enables bi-directional communication between the surface and downhole tools during downhole testing (Drillstem Test (DST) / tubing conveyed perforation (TCP))) operations by using an electro-magnetic signal. The wireless telemetry is used to transmit bottomhole pressure and temperature to the surface and permits control of downhole tools. This paper will describe the operating principle of the wireless system, present examples of how real-time bottom-hole data have been used to optimize the testing operations and summarize the key benefits achieved with this new technology. The real time analysis of well testing data during well flow and shut-in was effective in adjusting the test duration. The wireless telemetry eliminated the need for well intervention, which simplified the operation and eliminated the possibility of loss of data.
Applied Production Completion Using Optimum Number of Inflow Control Devices
Authors: Abdou Medhat , Kshada Ali , Shafiq Muhammad , Ogunyemi Olusegun , Chong Tee Sin , Hadjar Karim , Leung Edmund 
Published: February 2011

Abstract
This paper describes a case history detailing design, planning, completions, testing and production of first Inflow Control Device (ICD) horizontal well in one of field in Middle East. In this field, most of existing wells are openhole horizontal producers. A non uniform production profile across the horizontal section can result in early water and gas breakthrough. This can substantially reduce oil production, create zones of bypassed oil and lower the ultimate recovery. In case of early water breakthrough, it will also accelerate the need for artificial lift for individual wells and require increased water and gas handling capacity requirements.
The area of first row of producers located close to the water injectors are now experiencing increasing water cut in some wells causing the well to decline and die prematurely. Objective from the first ICD installation was to test the technical concept of ICD completion in managing the heel-toe effect and reduce the water cut (multiple water entries) in this well, as a first step to mitigate the down-dip and mid-dip problem. Additionally following objectives were set: reduce water cut, optimize production, extend the life of well, prove ICD technology benefits and use to field wide.
A critical aspect of the process way the modeling, prediction and optimization of both reservoir performance and completion hardware design.
After successful ICD design and installation, well was put on production and tested, following results are achieved: oil rate increased by 100%, Water cut reduced by 18% and well head pressure increased by 30%.
The appraisal and acceptance loop of the completion has been closed by having this well completed, put on production and tested. Approval of concept was achieved and the anticipated benefits were realized by actual performance of the well. Leverage knowledge from this pilot well has provided an insight into ICD capabilities and implementation and has set the stage for other fields.
Successful Well Stimulation Projects Boost Production from Iraq's South Oil Fields
Authors: Al-Hashmi Loayd , Qutob Hani , El-Halfawi Sami 
Published: February 2011

Abstract
As Iraq is striving to increase its oil and gas production after years of adverse conditions, efforts are focused on revitalizing existing oil wells to boost the country's production potential. Similar well stimulation projects executed in other parts of the world may seem routine, but the sheer operation conditions in Iraq make planning and control of these projects a major challenge.
The projects involved the stimulation of 180 wells in two of the oil fields (North Rumaila and West Qurna) in southern Iraq. The scope of work covered rigless perforation, stimulation, gas lifting (when required) and flowing the wells for cleanout before being put back on production. Project planning and management activities were carried out from the Dubai office. Coordinating a project of that magnitude, which involved diverse teams from different companies, requires professional project planning and coordination to enable the project to stay on track and achieve excellent results. Work is based on a clear understanding of the properties of geologic formations in the fields under consideration. Accurate analysis of the rock and reservoir fluids properties was used as the determining factor in the selection of the best suitable stimulation fluid composition and the operation technique.
The operation schedule duration was 9 months. Accurate alignment of facilities (camp and acid mixing plant), Equipment (stimulation and gas lift packages), consumables (acid, additives and wilreline) and personnel (12 different groups including third party service companies) was essential for the successful implementation of the project plan. Through good coordination and communication with various parties involved, the non-productive-time (NPT) was kept to a minimum. Detailed well-by-well review of the candidate wells was essential to select the best candidates for this campaign. Fundamental well data (well design information, formation pressures and formation fluid information) were examined and quality assured before designing the suitable stimulation package aiming for a high success rate of the treatment. The design factors included formation damage caused by fines migration, The information regarding chemical reaction between the rock and the acid was used to design the suitable composition of the pre-flush, main fluid, over flush and diverter fluid composition, Due to the presence of high-permeability streaks, the use of diverting fluid was essential to the operation success as it ensures a uniform coverage of the zone to be treated. Professional analysis of the operation results both on the job and after the job was used to improve the learning curve and obtain better results in the succeeding wells.
This paper shows how a well orchestrated field-wide stimulation campaign can be planned and executed to the highest quality and HSE standards, while managing to complete the project ahead of the completion date.
Production Logging in Horizontal Wells: Case Histories from Saudi Arabia Utilizing Different Deployment and Data Acquisition Methodologies in Open Hole and Cased Completions
Authors: Al-Belowi Ali R. , Al-Mudhi Mohammed A. , Hashem Mohamed , Wah Ong Leak , Arevalo Francisco , Rourke Marvin , El Gamal Tarek , Torne Juan 
Published: February 2011

Abstract
The horizontal wells drilled during the last few years are coming to a mature state in different fields and locations. This has created the requirement to evaluate the performance of the wells and determine water sources for proper reservoir management.
In horizontal wells tool deployment, multiple sensor data acquisition and the interpretation of these results is a challenge, particularly when there are long intervals of open hole completions and where fractures are often encountered. The horizontal cased completions use multiple down-hole valves and external packers to provide isolation between intervals.
This paper reviews the two primary deployment techniques of coiled tubing and tractor conveyance and highlights their advantages and limitations for each one. In the paper we propose a general guideline for their utilization.
The case histories in the paper evaluate the different sensors utilized and provide recommendations particularly for low flow rate conditions. Two interpretation methodologies are evaluated and results are compared along with the interpretation from other sensors.
The case studies examples in the paper demonstrate the value of integrating all available information and the value of different data acquisition and evaluation techniques. The conclusions highlight the operational considerations, the data interpretation and added value in the evaluation of well performance to maintain production and improve reservoir management.
RTOC Quality and Excellence Assurance for Well Delivery
Authors: Al-Marzouqi Abdulmohsen Mohamed 
Published: February 2011

Abstract
The objective of this paper is to discuss about ADMA-OPCO Drilling RTOC (Real Time Operation Center) and how it is developing to be capable of monitoring offshore rig operations and improve its performance. The paper will describe a lot of topics about workflow process such as pre-drilling planning and schedule of critical operations which need to be observed on real time. Also the development of real-time optimization process is been focused to be used in near future in the daily drilling activates since it could reduce the drilling cost and minimize probability of encountering problems due to working with optimized parameters. Moreover in this paper the stages to build a high technology center to provide well value assurance will be reviewed The main aim of the RTOC is to minimize the NPT (Non Productive Time) by having 24/7 monitoring services to provide an immediate response and action for any risk that may occur and this will lead to a successful management of all rig operations. Finally the review of ADMA-OPCO RTOC case histories and achievements of 2009-2010 periods will be reviewed and discussed in this paper.
Distribution of Asphaltene Deposition in the Rock Samples by Gas Injection
Authors: Okabe Hiroshi , Takahashi Satoru , Mitsuishi Hiroshi 
Published: February 2011

Abstract
Asphaltene related experiments for the samples from a Middle Eastern reservoir were conducted to assess potential problems in association with asphaltene precipitation caused by gas injection. The study involved three parts, (1) characterization of asphaltene precipitation and identification of problematic areas, (2) quantitative analysis of asphaltene deposition and its numerical modeling (3) field-scale simulation with the developed asphaltene model. Asphaltene phase behavior was measured to understand the relationship among pressure, temperature and asphaltene precipitation due to gas injection. Asphaltene onset pressure was monitored by Solids Detection System (SDS) to estimate Asphaltene Deposition Envelope (ADE), which was the useful measure to predict the risk of asphaltene deposition. The gas injection experiments confirmed asphaltene deposition in the core samples and the permeability reduction. The asphaltene content of the effluent from the core was reduced due to the deposition in the core and the amount of the deposition profile along the core sample was measured. It was found the heterogeneous distribution of the asphaltene deposition along the core. CO2 injection made relatively large amount of asphaltene deposition near the inlet of the core as the CO2 contacted oil at the upstream of the core and the mixing and dissolving to the oil were continued. Consequently, the permeability was reduced due to large deposition at the upstream. However, it did not severely affect on permeability when the asphaltene was equally distributed in the core. The laboratory-measured asphaltene precipitation and its effect on the permeability were modeled by the equation of state (EOS) and the lattice Boltzmann method (LBM). The model was used to understand field-scale behavior by the flow simulation model and it predicted asphaltene deposition around the wells. Asphaltene deposition profiles were different under near miscible and miscible conditions. The miscible conditions had more severe permeability damage around producers although the damage was barely observed around injectors. The permeability reduction was observed after the gas breakthrough. The study covers the laboratory measurements and the numerical modeling. It shows the detail analysis of asphaltene related experiments and modeling is important to identify the risk of asphaltene deposition induced by gas injection, especially CO2 injection.
Impacts of the Number of Perforation Clusters and Cluster Spacing on Production Performance of Horizontal Shale Gas Wells
Authors: Cheng Y. 
Published: February 2011

Abstract
Multi-stage hydraulic fracturing has become the key technology to complete horizontal wells in shale gas reservoirs. In each stage, multiple perforation clusters are used to create multiple transverse fractures. How to place these clusters significantly affects both the short-term and long-term production performance of horizontal shale gas wells. The author’s previous work has demonstrated that when more than two fractures are created, mechanical interaction among fractures creates strong stress concentrations around the inner fractures. As a result, the fractures between two edge fractures, i.e., sub-center and center fractures, are limited to dilate, and their widths are much less than the edge-fractures’ width.
In this paper, reservoir simulation models were constructed by quantitatively incorporating the findings of the author’s previous work to investigate the impacts of the number of perforation clusters and cluster spacing on production performance of horizontal shale gas wells. The paper illustrates that with the same cluster spacing, the scenario with more clusters has lower ultimate gas recovery because of increased number of less-effective inner fractures. Given the same lateral length of a horizontal well, although reducing cluster spacing increases the total number of fractures, smaller cluster spacing doesn’t necessarily improve well performance. An inadequate small cluster spacing can actually lead to more less-effective and ineffective fractures, and therefore lower gas rate and ultimate recovery.
Applying Innovative Production Modeling Techniques to Quantify Fracture Characteristics, Reservoir Properties, and Well Performance in Shale Gas Reservoirs
Authors: Miller Mark A. , Jenkins Creties , Rai Rakesh 
Published: February 2011

Abstract
In order to more accurately characterize reservoir and hydraulic fracture properties from well performance, a workflow has been developed that effectively integrates variable quality data from a variety of sources. This workflow applies analytical techniques designed specifically for shale gas wells followed by as-needed numerical modeling. The analytical techniques can be applied to multiple wells through time to: a) identify groupings of like-performing wells, b) detect wells with anomalous behaviors, c) develop hypotheses about production mechanisms, and d) choose specific wells for more detailed analysis and numerical modeling. Numerical modeling provides the functionality needed for complex mechanism forensics, performance forecasting, and completion optimization studies.
Conventional numerical models typically use finite-difference grids, but these are neither sufficiently complex nor sufficiently flexible for shale gas reservoirs. For this reason, a finite-element modeling technology has been applied that places a large number of closely-spaced nodes near hydraulic fractures, "where all the action takes place" in the early life of a well. The finite-element technique also allows complex fracture geometries to be modeled.
This workflow, incorporating analytical and numerical solutions, has been applied to multiple shale gas projects, including industry consortia in the Haynesville (US) and Montney (Canada) shales and individual operator projects in the Woodford (US), Horn River (Canada), and Marcellus (US) shales. Through the application of these techniques, fracture and reservoir properties have been characterized and uncertainty associated with forecasted well performance has been reduced. This work has profound implications for quantifying gas reserves, understanding those factors responsible for variations in well performance, and for optimizing well spacing, lateral lengths, and completion techniques.
Improving the Recovery of CO2 Injection in Sarkan Oil Field Reservoir in Iran by Selecting the Reasonable Dispersivity Coefficient for Injection Process
Authors: Kamalipour M.. , Farouq Ali S.M.. M. , Shahrabadi A.. , Jamialahmadi M.. , Nabimeybodiy J.. , Rostami A. Jannat 
Published: February 2011

Abstract
Evaluation and improvement of sweep efficiency are important issues of miscible displacement process. Miscibility is controlled by physical dispersion during miscible processes. It comprises of two parameters: diffusion and mechanical dispersion. Unfortunately this parameter is usually ignored during simulating the miscible processes which would be considered as an enormous source of error. Results show the existence of three regions at which each component of physical dispersion controls the miscible CO2 injection. For dispersivities between 0.123m to 0.175m the miscible process is controlled by physical dispersion mechanism while dispersivities lower than 0.123m specifies a region controlled by diffusion in the field case. The third region is the region for dispersivities greater than 0.175m and the main parameter affecting the miscible process in this region is mechanical dispersion. This study discusses the the effect of this parameter on recovery, mixing zone length and breakthrough time of injecting CO2 in a natural fracture reservoir in Iran.
Jiangsu Oilfield’s Carbon Dioxide Cyclic Stimulation Operations: Lessons Learned and Experiences Gained
Authors: Yang F.. , Deng J.. , Xue Y.. 
Published: February 2011

Abstract
The first carbon dioxide (CO2) huff ‘n’ puff experimental project was conducted in 1997 in Jiangsu oilfield, China. This paper reviews design and performance data on 70 CO2 huff ‘n’ puff projects conducted in different wells in Jiangsu oilfield from 1997 to 2004. For the Jiangsu reservoirs with light crude oils, reversal of production damage and enhancement of oil swelling aided by gravity drainage are believed to be the most significant mechanisms contributing to increases in oil recovery. The objective of this paper is to examine important parameters, best practices and lessons learned that contributed to the success of CO2 huff ‘n’ puff operations and their use in further improvement in CO2 huff ‘n’ puff projects.