bluuebunny/crossref_metadata_2025_split huggingface dataset:
Effective Training Delivery Mechanism-A Successful Case Study
Authors: Al-Anezi Nayef Abdulla , Al-Daihani Eisa Hadi , Raza Syed Mohammad , Nandi Arun Kumar 
Published: September 2015

Abstract
Training and development is recognized as critical support function of the organization. It has greater impact on assets which are diverse depending on the delivery mechanism. Identifying the most effective training solution to enhance the human resource and eventually organizational capability is only one aspect of delivery mechanism. The main and very critical aspect of delivery mechanism which has two way impacts on the organization is the adequate tools and techniques adopted to implement the learning solutions.
Kuwait Oil Company has introduced a comprehensive integrated delivery mechanism ensuring the quality control at all stages; planning, implementation and evaluation. As a case study, this paper will present the mechanism of two learning solutions/ learning tools (Instructor led training course and on job training). A multidimensional assessment tool kit to determine the effectiveness of the Instructor led courses and on-job training has been established which is a systematic approach of delivery mechanism and that lead to Quality Assessment team to evaluate the effectiveness more accurately. Accordingly, key elements have been identified which indicate the training efficiency. The training efficiency is then checked with knowledge assessment (Gap Filled) with the aim to ensure accuracy. An equation for instructor led and on the job training has been evolved to determine the efficiency of the training delivery mechanism.
The present paper is focusing on effective training delivery mechanism adopted by Kuwait Oil Company for learning solutions ensuring various aspects i.e. meeting the training objective, cost effectiveness and quality control. Defining competencies, ensuring the alignment with business needs, assessing the current competency level of employees and developing action plans accordingly are the main examples of a systematic approach of capability development at planning stage. Such an approach will help the company to meet its strategic target.
To resolve the issue of capability development and the associated challenges, a long-term and genuine cultural change is required to create environments where knowledge sharing is expected and normalized. The solution needs to be driven from the top, with senior management making a visible commitment.
How Culture And Practice Workshops Can Help Developing The Safety Accountability Of Operational Staff
Authors: Kiehl Vincent , Amadeï Christophe , Pradié Emmanuel , Sibout Marie , Boj Claude , Watremez Xavier 
Published: September 2015

Abstract
TOTAL has conducted a global safety culture assessment in its Exploration & Production Affiliates. Further to this assessment, Culture and Practice workshops were organised in selected business units (currently in Total EP Angola) to develop the safety accountability of employees and to promote cooperation of teams.
On each selected site, one-hour sessions were organized each day over a two week period and were repeated three times. They were proposed to all employees, from the Production Operator up to the Site Manager. Each group had a maximum of eight people and ensured that all levels of site personnel were represented.
Two facilitators with multidisciplinary competencies led the workshops: an Occupational and Industrial Psychologist and a former Operational Manager. They gave a common basis to work on the safety culture. They encouraged interactive discussions to bring sense, when required, to the existing safety corporate messages, rules and procedures.
The workshops progressed in five successive stages: (1) Introduction; (2) Teams' request; (3) Highlights; (4) Taking ownership and accountability; (5) Debriefing.
The workshops focused on the meaning and the consistency of existing practices on safety rules and initiatives. Based on open discussions, the participants mentioned the topics on the safety culture important to them. The three main topics were: (1) Risk assessment and management; (2) Exemplarity of management; (3) Accountability of individuals.
The groups debated and proposed to change some working practices to improve the safety culture. At the end of the workshops, they debriefed their work to the Site Management and to Operational Directors, as to commit all the personnel on the proposed changes in practice.
These workshops held both onshore and offshore demonstrated a strong mobilisation towards safety. The dynamics created had a very positive impact on the all personnel behaviour. As a consequence, the Company is using this new and effective approach towards safer operations in Other Business Units.
Drilling the Undrillable: Atlanta Field Heavy Oil in Ultra Deep Water
Authors: Rausis Mauro G. , Pedroso Carlos A. , Salies Jaques B. , Libório Fernando , Moreira Marivaldo B. , Luz Pedro R. , Siqueira Jorge R. , de Oliveira Jessica F. , Marsili Marcelo D. , Nogueira Luiz M. , Heleno Ademir , Domingues Glauber T. , Aguiar Rogério 
Published: September 2015

Abstract
The development of heavy oil (14 API) in ultradeep waters (1550 m), in a reservoir 800m bellow mud line is a technological challenge all over the word. This paper will present the solutions applied successfully to drill, gravel and test two horizontals wells under these extreme conditions.
Atlanta field is a post-salt oil field located offshore Brazil, in the Santos Basin, 150 km south of Rio de Janeiro. The water depth has approximately 1550 m, the reservoir sits 800 meters bellow the mudline, has an unconsolidated sandstone with an average 38 % porosity with high permeability and a 14 API oil. This paper presents most of the challenges the operator had to overcome to drill, gravel and test two wells already with great success. Both wells have a casing program composed by 36″/16″/11 7/8″ and an horizontal section of 800m drilled in 9½″. Due to the 14 API oil the artificial lift method chosen was ESP (1500 HP) installed at an inclination of 75 degrees of the well. To install the pump the well profile was built with a slant section of 100 m with maximum DLS of 1 degree/100ft to avoid fatigue during the operation, but also a maximum dogleg of 5 degree/100 ft to avoid damages to the pumps while running into the wellbore. To be able to achieve the constrains imposed by the ESP, from mud line at 1550 m to the top of the reservoir at 2330 m the well profile design had to achieve a 43 inclination during the riserless drilling section of the well, the techniques applied are described in details in the paper. The next challenge was to drill the horizontal section with a very narrow margin from collapse to fracture of the well, all the procedures regarding drilling fluids and drilling techniques are presented. The 800m horizontal section was drilled in 9½″ to allow the use of 6 5/8″ premium screens to increase production. To guarantee a minimum content of sand in the produced oil with the objective of increasing the life of the ESP the well was gravel packed. Due to a small fracture gradient of the previous shoe 11 7/8″ the gravel was performed successfully with a special propant with very low weight, again the details are presented. The wells were tested with two different positions of the pump: one at the bottom of the well, and other at the sea level just above the BOP. The objectives of the test were to compare the performance of the reservoir with the pumps in two different positions, but also to study the flow assurance problems that may occur after programmed or non programmed stops of the future production system. All the results and main conclusions are presented.
The excellent results obtained from the drilling, gravel and testing of both wells, which are presented in this paper, confirms the potential of Santos basin’s Atlanta field.
Dynamic Multiphase Process Simulation as a Powerful Tool to Sustain Production: A Real Case Application
Authors: Riccio Gaetano , Di Sarra Andrea , Bianco Amalia , Dibello Francesco , Masi Silvia 
Published: September 2015

Abstract
The full potential of simulation has, to date, not been fully exploited for numerous reasons, including but not limited to lack of awareness of this computational approach. Nowadays, steady state simulators that model operating plant are used as the custom-made tools to predict global performances, even though they are not able to mimic ‘real’ process behaviour.
The work described herein introduces dynamic process plant models as an efficient way to simulate time-dependent variables, handling changeable ‘real-time’ operating conditions.
A stabilization unit was the object of an engineering study with the intent to sustain production, enhance energy efficiency and safety of operations through low-cost computational technology. The entire process plant was modelled and tuned with commercial simulator equipped with a dynamic suite. The latter requires equipment data and real geometry to simulate operating conditions upsets, feed or composition change in a transient way. Once the steady state model is matched, the switch to dynamic environment allows the user to model upset of input variables and to study system response. It guarantees to adapt the entire process in a new and more efficient configuration by optimization of the control system.
Steady state simulations are very fast and use continuous, time-interval based, steady-state approximations, requiring the least effort to set up and calibrate. Contrariwise, they are not able to simulate transient phenomena and control system responses, thus limiting simulation capabilities to provide representative conditions of the real plant behavior.
Considering that cost to benefit ratio is rapidly moving in favor of computerization, the implementation of dynamic simulations in process industries represents the best way to achieve complex targets. The presented case study demonstrates the strength of this approach and its influence on optimal monitoring and control of process plant performance.
Other benefits have been shown on real time optimization, including operational troubleshooting and field operating cost reductions.
‘Fine-tuning’ is the resume word of this work and represents the way to efficiently achieve complex targets, moving Oil & Gas toward applications that have otherwise been characterized only for petrochemical or complex plants.
Currently, the global energy world is facing even more complex scenarios, which technical engineers must address in order to confront the new challenges ahead.
Effects of Downhole Parameters on Horizontal Milling Applications
Authors: MacZura J. M. , Miller M. , Scuadroni N. , Daley D. 
Published: September 2015

Abstract
The increasing lateral lengths of wellbore and additional composite frac plugs (CFP) per well has created a need for a more efficient and aggressive post frac millout of plugs using coiled tubing (CT). Economic post job analysis has shown some advantages and drawbacks of using larger diameter coiled tubing and more robust tools, all while developing a better understanding of the impact to the operation. Several complexities exists downhole that are not well understood. Attempts to comprehend downhole conditions are limited by past experiences, pre-job software modeling, and post-job matching through the uses of surface parameter but not actual downhole data.
Monitoring downhole forces applied when performing post frac milling operations, through the use of a memory sub, gives a better understanding of forces that are actually transmitted from the tools to the CFP in the actual wellbore environment. Thru tubing tools selection is based on actual downhole data which translates to an overall increase in efficiency of the operation.
A closer look at the actual downhole parameters, when performing operations with larger diameter CT and extend reach tools, lead to findings that the weight on bit (WOB) applied to a plug in the lateral of a well can be as high as 15,000 lbf. This amount of force far exceeds what is applied at surface and what conventional software modeling shows. This also greatly surpasses the recommended WOB while drilling the CFP. Applying substantial downward force to the CFP results in movement of the plug prior to being completely milled up, which causes significant operational issues. These same forces that cause the aforementioned issues are necessary to aid in having consistent mill times throughout the operation, enough WOB to get CT to reach measure depth (MD), and produce an operation that is completed in a timely and economically sound manner.
Uncertainty and Risk Management Plans are Critical for Team Alignment and Better Decision Quality
Authors: Sawiris R. , Howes C. S. , Rodriguez J. A. , Foley W. L. 
Published: September 2015

Abstract
The Uncertainty Management Plan (UMP) and Risk Management Plan (RMP) processes are an integral component of Reservoir Management and Project Management at Chevron. The UMP and RMP are key to safely deliver and improve the movement of Resources to Reserves to Production (R2R2P) and the maturation of Organic Resource Opportunities (ORO) in a timely and economical manner.
The UMP helps project teams identify key uncertainties and develop robust work plans to resolve these uncertainties in order to improve decision quality and maximize value to the company. The RMP helps project teams identify key technical, mechanical and commercial risks, and develop appropriate mitigation and contingency plans for these risks. The RMP will also help the team identify and address process safety risks related to subsurface integrity issues. The UMP and RMP drive development plans, technology plans, surveillance plans, operating plans and resource loaded work plans. This is even more critical at the current low oil prices where many projects become economically challenged; we need to focus our efforts and resources to be decision driven and value driven.
We will compare and contrast the concepts of uncertainty and risk and present case studies of how the UMP and RMP were successfully used on a variety of assets. We will also discuss some of the pitfalls, lessons learned and best practices.
Treating Acid Mine Drainage for Use as Source Water: A Pilot Study
Authors: Beers T. , Heinrichs M. R. , Lane A. E. , Peterson R. K. 
Published: September 2015

Abstract
This project’s focus is to evaluate an Acid Mine Drainage (AMD) treatment technology for the purpose of providing treated mine drainage as an alternative source of water for hydraulic fracturing operations. The liquid-liquid extraction based technology allows the conversion of a previous environmental liability into an asset while reducing stress on potable water sources. This is a patented technology based on well understood and widely applied solvent extraction processes and has three distinct stages—water purification, metal recovery, and sulfate recovery—and produces three distinct and potentially useful byproducts. Water is able to be treated to reduce sulfate levels to less than 100 mg/L sulfate, and is able to remove most metals associated with mine drainage, including iron and aluminum, to low levels while maintaining high levels of water recovery.
Laboratory testing was conducted to optimize operational parameters of the technology specific to the AMD at the demonstration site located in Sarver, PA. Laboratory optimization of the process informs field testing as to the preferred operating configuration and parameters for the site specific water chemistry. System variables which would be difficult to test in the field, such as the number of extraction stages required or the optimal formulation of extractant were tested in the laboratory and system setpoints for the field pilot demonstration unit were identified. Following laboratory testing, a series of test runs were conducted in the field on a 100 gallon-per-minute pilot demonstration system. Field testing showed that the field system was able to remove sulfates to the levels required while operating under steady state conditions. Field results were correlated with laboratory results. Future field testing to be conducted in phase II of this project will include two distinct test campaigns to evaluate both the sulfate removal efficacy of the system as well as identify optimum economical operating conditions.
Scale Squeeze Fractured Reservoirs in the Bakken, North Dakota
Authors: Cook S. , Lu H. , Cutler J. , Haugen C. , Cenegy L. , McAfee C. 
Published: September 2015

Abstract
Scale inhibitor squeezes are common for scale prevention in conventional reservoirs, but similar applications into fractured reservoirs are unusual and the mechanism of inhibitor transport and retention is not fully understood. This paper discusses the selection and field application of a scale inhibitor for the Bakken, North Dakota fractured reservoirs. The Bakken development is a hydraulically fractured reservoir where calcium carbonate and iron carbonate scaling pose a threat to productivity, necessitating the deployment of preventative scale inhibitor treatments. The results of a comprehensive inhibitor testing program, including compatibility, formation damage studies, dynamic tube blocking and static adsorption testing are presented, providing an overview of the product selection criteria for the fractured reservoir. This paper demonstrates how production-, completion- and laboratory-derived data were used with treatment modeling software to enable the successful application of a scale squeeze into the Bakken formation. Complex Bakken completion orientations made the use of conventional modeling programs a challenge and a number of assumptions that were made are discussed in the paper. The final part of the paper reviews the squeezes performed on three Bakken wells, and discusses relative performance against the modeled treatment predictions. The scale inhibitor retention in the reservoir is documented, and possible mechanisms are discussed.
Searching for Energy Policy Alternatives
Authors: Blaskovich Frank 
Published: September 2015

Abstract
Energy policy resides in a socio-economic system that has many interconnected elements, feedback loops and delays that create behavior that is not easy to understand or manipulate to achieve desirable outcomes. This paper suggests a new approach to energy policies that tries to minimize stakeholder regret regardless of future surprises. We built a model to study the relationships among energy producers, government and society to develop taxation policies that would benefit all stakeholders fairly. Our focus was on oil, but is extendable to other forms of energy. The goals were to find policies that would encourage energy development, provide for the public's energy needs and enable government to safeguard society's well-being.
We used regret analysis to find the best stakeholder policies as well as compromises that would benefit all fairly. This defined the range of acceptable solutions. We then used regression trees, differential evolution and genetic programming to develop policy algorithms that worked regardless of the future behavior of policy drivers such as oil prices, oil reserves and well productivity for all stakeholders (energy providers, government and society).
Sound energy policy requires creative insights into how complex systems function. Traditional techniques that tend to focus on one or a few aspects of the problem rarely succeed for long and often can create more problems than they try to solve. Looking at policy levers individually did not work as well as considering all policy levers simultaneously. This resulted in a complex set of interrelated policies that achieved a much better result than would be achieved with other approaches. We found that the feedback loops in the model could either work together or be in conflict under different conditions. Understanding system behavior required techniques that focused as much on the structure (i.e., how key features interact) as on the individual components.
A key feature of the new model was that it considered the impact of and on society of policy decisions. This was an iterative process and the best policies changed as additional complexity was added to the system. We also compared our results to actual government policies to validate the benefits of our approach.
A Competency Framework for Petroleum Engineering University Graduates
Authors: Aggour T. , Donohue B. R. , Donohue D. A. 
Published: September 2015

Abstract
Academia has a long history of collaborating with the oil and gas industry to ensure that graduates are well prepared to succeed in the workplace and contribute to their new employers. Industry extensively utilizes competency models as part of a process to manage and assure a competent workforce. The first level of job titles represented by industry competency models usually defines positions with two to three years of experience, progressively building up to more experienced job titles. It is logical to extend this methodology backward into academia, representing the expectations of entry-level new hires. This paper describes an initiative that builds on previous efforts by developing a rigorous competency framework for petroleum engineering graduates that covers the expected technical and behavioral competencies for new graduates at a high level of detail. The resulting framework has measurable competencies and can be utilized to great benefit by all stakeholders involved in the industry.
Academic programs can utilize the competency framework as a reference to influence curricular decisions and assessment protocols, helping to more effectively prepare graduates for their future roles and document the quality of their graduates.
Students will have a clear understanding of the expectations of them upon entering the workforce and have an opportunity to identify and remedy any gaps during their studies to improve their employment prospects upon graduation.
Potential employers and recruiters will now have a valuable new quantitative screening tool that can be used to compare the technical qualifications of graduating applicants and help match them to roles best suited to their technical competencies.