bluuebunny/crossref_metadata_2025_split huggingface dataset:
Building a Common Narrative on Employee Performance
Authors: Ramachandran Karthik Nataraj , Al Hosaini Khalil , Al Hammadi Ayesha 
Published: November 2017

Abstract
The objective of this paper is to study the impact of building a common narrative in the performance appraisal system for a large Middle East based corporation in its drive to build a performance driven culture. This study assumes even more significance when taking into account the countries nationalistic culture, which has a high power distance index and high uncertainty avoidance index as per the Hofstede Cultural Dimensions Index. Change management initiative is expensive in nature more so, in a pluralistic environment with multiple cultures as the case of the organization under study. The challenge becomes even more difficult if the change is targeted at the existing cultures in the organization. As the authors were part of the change management initiative, the various stages adopted in moving the organization culture from entitlement to performance are analyzed in detail. The use of common narratives and unified performance appraisal methodology, leadership engagement and Normalization process lead to a demonstrated change in the performance appraisal rating for the targeted group of employees. The impact of the common narratives, lead to a decrease in the rating of exceeding and above categories for managers and above by almost 50 %.What it effectively highlights is that the journey to build a performance driven culture is ongoing and it’s through the common narratives and understanding that the desired outcomes can be achieved. Such a large scale study on the impact of building a new performance culture has not been done in the Middle East before. The learnings would be of immense value to organizations wanting to incorporate such changes in the future. In addition, limited papers have adopted the action research method to observe culture creation phenomena in spite of it offering clear insights due to the involvement of the authors in the culture creation.
Upscaling Chemical Looping Combustion for Enhanced Oil Recovery
Authors: Snijkers F. M. , Jacobs M. , Albertsen K. , Moldenhauer P. , Mattisson T. 
Published: November 2017

Abstract
Chemical looping combustion (CLC) is an innovative technology for heat production with inherent capture of carbon dioxide at minimal energy penalty. Its development is highly relevant since it addresses CO2 capture needed for closing the carbon loop as a contribution to mitigating climate change, one of the big challenges of today's society.
In CLC, oxygen is transferred from an air reactor to a fuel reactor by means of a solid oxygen carrier. Thus avoiding direct contact between air and fuel, and after condensation of water, an undiluted CO2 exhaust stream is obtained. CO2 is more and more considered as a valuable chemical substance for enhanced oil/gas recovery projects as well as for the production of chemicals, polymers or building materials. It can potentially be an option for several types EOR namely were miscible gases for injection are needed, for steam EOR and for CO2 EOR.
Strategic to CLC technology is the oxygen carrier that is in the heart of the process. Parameters such as particle size and distribution, density, porosity, strength, attrition resistance, reactivity, environmental aspects and cost, define the performance of the oxygen carrier. The first generation oxygen carriers were Ni-based. However, due to cost of nickel and toxicity, a search for Ni-free oxygen carriers was conducted with similar or superior performance in CLC. This has lead to the development of Mn-based oxygen carriers, that demonstrate the beneficial oxygen uncoupling effect, with complete fuel conversion as a result. In the EC 7FP project SUCCESS, a promising oxygen carrier based on perovskite calcium- manganite with good fluidisability, high sphericity and high attrition resistance, was upscaled to the industrial scale. In this contribution results are presented obtained with oxygen carriers that have been produced by the versatile and industrial scalable spray-drying technique. Results are discussed that have for the first time been obtained with an upscaled process. The oxygen carriers were fabricated with the industrial spray drying process for multi-tonne scale production in order to accommodate for chemical looping plants of 10 MW and larger.
Advanced Model-Based Optimization of a Natural Gas Liquid Recovery Unit
Authors: Leyland S. , Georgis D. , Marriott J. , Andrade A. , Dara S. , Berrouk A. S. , Al Wahedi Y. , Geuzebroek F. , El Nasr A. S. , Ghanayem N. , Turner A. , Khan M I. 
Published: November 2017

Abstract
Natural gas liquids (NGLs) are the main contributor to the profitability of natural gas processing plants. During the recent period of relatively low natural gas prices, NGLs spot prices have experienced a slower drop remaining relatively steady. Therefore, switching the operation of existing facilities towards a higher NGL production can lead to a more profitable position. In this work, we develop and implement model-based optimization solutions on a selection of NGL plants in order to improve the profitability of the facility.
Such analysis is meaningful only when high-fidelity validated first-principles models are employed within an equation oriented environment using rigorous mathematically formulated optimization algorithms which guarantee that the optimal solution satisfies all safety and operational constraints. In this work, an equation oriented commercial process simulator is utilized which offers unique optimization capabilities of very large and complex process flowsheets.
In this paper we demonstrate the practical benefits of Advanced Model-based Optimization through a case study of an NGL Plant in Abu Dhabi. The workflow is discussed starting from model formulation and validation, to optimization and assessment of the optimal operational strategy. We also discuss how the deployment of such model-based optimization activities can be used to develop operating guidelines that allow operators to drive the plant towards optimal operation and address a range of operational situations; giving them the ability to respond to changes in the plant or economic conditions quicker and with more confidence than previously possible.
How ISO Principles can Simplify Process Plant Desgin, Construction and Maintenance to Deliver Cost and Production Efficiences
Authors: Subahani Ashik , Steven Iain 
Published: November 2017

Abstract
The design of offshore production process plant is a time-consuming and costly activity where in many instances the design of each new plant begins from the ground up. Where suitable designs already exist, their re-use is often prevented due to ownership of Intellectual Property and copyright.
A new methodology, based upon the principles of ISO Modularisation, is offered with the expectation that this methodology can deliver cost savings, production efficiencies and weight savings.
The authors examined existing literature in the fields of both process plant design and modularisation relative to manufacturing. By combining their hands-on experience, the authors are a marine engineer and naval architect, with the findings of the literature review the authors believe a standardisation modularised approach to process plant and design can benefit the offshore industry.
The authors conclude that such an approach could deliver: ○A reduction in design and construction time;○A reduction in design and construction costs;○Introduction of standardised design principles○Introduction of standardisation in pricing for design, construction and assembly;○Ease of maintenance and upgrading;○Advantage during transportation○Safer approach○Reduction in loss of production time via a quicker change of components during overhauls;○Reduction in the cost and constraints of supporting offshore maintenance and○Facilitation of reuse at end-of-life.
The new information presented will reveal a patent pending ISO Modularisation concept with standard x, y and z interface points. This approach, offered as an alternative to the current industry practise of designing process plant from scratch, will deliver a cost-effective method of process plant design, construction and maintenance with financial and efficiency savings.
Evaluation of Miscible Water Alternating Gas WAG Injection by Comparing with Lesson Learnt from an Immiscible Gas Injection Pilot
Authors: Kohata Akihiro , Willingham Thomas , Chen Peng , Al Sowaidi Alunood 
Published: November 2017

Abstract
To sustain the long term production from a giant offshore reservoir, a simulation study evaluating and comparing miscible hydrocarbon (HC) Water-Alternating-Gas (WAG) with a prior pilot test implemented in the field evaluating immiscible HC Simultaneous Water-And-Gas (SWAG) has been carried out. This paper describes the evaluation of recovery uplift for the miscible HC WAG by comparing study findings with actual field results for the immiscible HC SWAG pilot.
In order to evaluate miscible HC WAG potential, sector model simulation studies were carried out and it was concluded that a 11% recovery uplift over base water injection could be achieved by miscible HC WAG. On the other hand, an analysis of the immiscible HC SWAG pilot test including history matching simulation was conducted and it was concluded that immiscible HC SWAG had little impact on recovery uplift. In order to evaluate the differences between the planned miscible HC WAG implementation and the immiscible field pilot test results, the comparative investigation was conducted using sector model.
The area where the immiscible SWAG pilot was conducted was geologically similar to the target area for the miscible WAG. To confirm the geological similarity of the two areas, simulations for immiscible injection using a 5-spot configuration consistent with the immiscible SWAG pilot were carried out for each area. Results indicated gas distribution was similar in the two areas and was in agreement with actual pilot results; hence, it was confirmed that the impact of geologic differences of the two areas was limited. The other differences between the planned miscible HC WAG and the immiscible SWAG pilot were (i) injection scheme (WAG or SWAG), (ii) well configuration (line drive or 5-spot pattern), (iii) well spacing (500 m or 1 km) and (iv) injectant (miscible HC gas or immiscible HC gas). Simulation models capturing each scheme were developed. Through the injection scheme sensitivity simulation studies, it was concluded that (i) WAG, (ii) line drive, (iii) 500 m spacing and (iv) miscible HC gas were preferential to (i) SWAG, (ii) 5-spot pattern, (iii) 1km spacing and (iv) immiscible HC gas, respectively. The combination of these factors resulted in a 21% recovery uplift beyond the prior immiscible HC pilot. Hence, through this work we demonstrate that a reliable evaluation for recovery uplift with miscible HC WAG was achieved through the comparative investigation of the immiscible HC SWAG field pilot test results and the planned miscible HC WAG implementation, including the analysis of the impact of geology, injection scheme and well configurations.
Validating Automated Real-Time Produced Water Composition Measurement Device with Field Produced Water Samples: A Pathway to Field Trial
Authors: Ghorbani N. , Yan C. , Guraieb P. , Tomson R. C. , Abdallah D. , Ben Aouda A. , Odeh N. M. , Al Daghar T. A. 
Published: November 2017

Abstract
Mineral scale formation in the oil and gas industry can be detrimental to production and injection wells, and facilities yielding production losses and integrity issues. In order to manage scaling risk during operation, knowledge of production rates, GOR, WCT%, and hydrocarbon and produced water compositions along with reservoir pressure and temperature are required. Scale management relies on accurately monitoring produced water composition. In addition, the timing of changes in water composition is critical to proactively protect the production system from scaling. Preventing scale formation results in significantly reduced production loss, optimized chemical dosage, and fewer well interventions, consequently lowering OPEX and mitigating HSE risks. This paper documents advancements made since the last year publication by the authors on the real-time produced water composition measurement device. The device can automatically collect a discrete production fluid sample at the wellhead while keeping the pressure and temperature of sample constant, separating produced water from the bulk phase and measuring multiple properties: pH, alkalinity, strontium, barium, calcium, sulfate, total hardness, and total dissolve solids (TDS) at the pressure and the temperature of sampling point without degassing. It also reports the pressure and temperature of sampling point. This paper illustrates calcium automated measurement properties developed and a validation of the laboratory prototype by testing the device with four produced water samples from different formations: i) Permian Basin, ii) Bakken, iii) Eagle Ford; and iv) synthetic produced water from an oil field in Abu Dhabi. Results show excelent performance of the device for calcium measurement. For example, the mean of the device measured value for calcium based on internal calibration, was 42.84 mg/l with a standard deviation of 0. 084 compared with the laboratory reference method ICP-OES measurement of 42.63 mg/l, which shows very accurate measurement of calcium. This paper presents the reliability and repeatability of the device in addition to the results accuracy compared with ICP-OES and traditional laboratory analysis methods. The results obtained from production fluids were promising. Laboratory validation is the last step before field testing the device. The success of the laboratory validation stage is crucial as the device progresses through final design changes ahead of field trials. Measuring produced waters with different salinities promote the device reliability and fills the gap between synthetic water composition measurement in laboratory and the field trial. The device was developed to enhance reliability of water properties measurements, provide real-time measurements, and reduce downtime and costs associated with workovers, interventions, and sampling.
Strength and Deformation Capacity of Lined Pipelines using Advanced FE Modelling
Authors: Bartolini Lorenzo M. , Bruschi Roberto , Marchionni Lorenzo , Parrella Antonio , Vitali Luiinog 
Published: November 2017

Abstract
DNV GL has recently carried out a JIP to propose rational design criteria for clad and lined pipes. Attention has been paid to pressure containment, local bucking/wrinkle, fracture and fatigue limit states. In DNV GL JIP design guideline, a strain criterion for the liner wrinkle limit state is proposed. The criterion is based on experimental test results and it does not include any safety factor. Advanced FE Model, purposely calibrated through dedicated experimental tests, can be developed to quantify the strength and deformation capacity of lined pipes considering installation and operational loads, pipeline geometry and fabrication technology and tolerances.
The FEM analyses well reproduced the behavior of clad/lined pipelines subject to combined loads. The presence of liner contributes to the overall pipeline strength and deformation capacity, although introduces an issue due to the risk of wrinkling and detachment from the baking steel. For lined pipes with no or low internal pressure, the liner will normally separate, i.e. wrinkle, from the backing steel prior to reaching the local buckling capacity of the backing steel alone.
Advanced FEM analysis approach can be very helpful for lined pipe strength and deformation capacity assessment, aiding engineer during the design process. The accurate reproduction of failure modes under combined loads can drive engineers through a proper design of clad/lined pipe in offshore extreme environment/loading conditions.
New Shear Thickening Dilatancy Dispersion Based on Nano-Silica Beads for Oilfield Applications
Authors: Al-Olayan Abeer M. , Alexander-Katz Alfredo 
Published: November 2017

Abstract
A new innovative shear thickening (STF) has been developed based on silica nano particles. The new material has the ability to form highly viscous gel in high shear / high temperature conditions. This innovation has been inspired by the medical industry that simulates the dynamics of biological polymers in a chain of blood clotting. The concept is based on the introduction of short and long polymers grafted randomly on silica particles. Rheological properties of the new STF were tested by Anton Parr Rheometer at different particle concentrations, polymer molecular weight ratios and temperature. The data shows that shear thickening has a good behavior in high temperature and provides a significant increase in fluid viscosity. This is a highly potential material for different oilfield applications.
RFID Enabled Safe Load Indicator Data Logging System Enhances Higher HSE Standards in Offshore Crane Operations
Authors: Chandran Dileep , Alila Morched , Al Owaid Hatim , Hantoosh Abdulla , Alawi Sami , Sajjad Yasir , Singh Kuljinder 
Published: November 2017

Abstract

Objective
To record the operational data through the crane Safe Load Indicators to Identify the risk in the Behavior of crane operators, to improve Safety standards and the need for (individual) basic training in offshore crane operation.

Process
The Data Logger system link with the Radio frequency identification (RFID) tags, which enable the Datalogger to record operation parameters in relation with the crane operator. The data is downloaded to an internal SD card or can be transferred to a Laptop computer for analysis using special software. The data is presented in the form of graphical charts based on the operator's ID.
The collected data shows the actual lifting performance and highlight the violation for each alarm under Operator ID. It will help in identifying the weak crane operator’s weaknesses and the points required training to improve his behavior. The system will assist supervisor’s in controlling risk takers behaivior.
Natural Gas Plant Debottlenecking Thanks to Hybrid Solvent
Authors: Cloarec Eric , Cadours Renaud , Weiss Claire 
Published: November 2017

Abstract
For the last decades, continuous global trend towards more stringent safety, commercial and environmental specifications kept processing sour natural gas containing acid gas such as H2S and/or CO2 a growing challenge. If mercaptans are present in the sour natural gas, the limited mercaptans absorption capacity of the well known alkanolamine solvents can be a major problem. The operating companies have to upgrade their production units to comply with these specification and environmental constraints evolutions. Additional treatment steps are often required to achieve the total sulfur specification in the sales gas, adding process complexity and further increasing cost.
An efficient solution to solve the problem would be to replace the usual alkanolamine aqueous solvent by a hybrid formulation allowing simultaneous removal on mercaptans and acid gases. This approach has been rarely considered because of the side effects of traditional hybrid solvents: hydrocarbon co-absorption, negative impact on the downstream sulfur recovery units. It may be necessary also to replace the internals of the absorber column in the Acid gas Removal Units.
To address this issue, TOTAL is now using a new dedicated hybrid formulation since 2007. This new solvent has been developed by TOTAL by taking advantage of its intensive know-how and experience in gas processing. The hybrid solvent is obtained by addition of a physical component into a generic alkanolamine-water solvent. The final solvent composition is determined to optimize mercaptans removal and minimize hydrocarbon coabsorption, without affecting acid gas removal capabilities.
Without any plant modification, this hybrid solvent can be implemented in existing unit to remove mercaptans with the acid gases, with no detrimental impact on downstream SRU. It allows operating cost reduction of the existing downstream units. Last but not least, the energy consumption of the acid gas removal units can be lowered by 10- 15%.
This paper presents several applications cases where the benefit of using the hybrid solvent is demonstrated.
Challenges with the Development of the Yamal Peninsula
Authors: Akimova Irina 
Published: November 2017

Abstract
The Yamal mega project – new evolving area, that combines production and infrastructure facilities and will have to replace the Nadym-Pur-Taz area – major gas production area in Russia since 1970s, that’s became legend by suppling almost all soviet and than Russian export contracts and securing domestic consumption at the same time. But currently Nadym-Pur-Taz is in its decreasing production phase and thus the need to provide substitution for this area is shaping the impotrtance of Yamal mega project for the Russian and international gas market development and security. The Yamal Peninsula and adjacent offshore areas have an enormous potential: the explored gas reserves with estimated and prospective resources total are 26.5 trillion cubic meters, 1,6 billion tonnes of gas condernsate and 300 million tons of oil and represented by 32 fields in total. [State commission on natural reserves. 2012]. Such significant resource base wil make it possible to produce here up to 360 billion cubic meters of gas per year by 2030. [Ministry of natural resources of the Russian Federation. 2012]
Research and Application of Ultra-Short Radius Flexible Sealed Coring Technology in Re-Development of Matured Fields
Authors: Liu He , Zhang Shaolin , Sun Qiang , Li Tao , Ming Eryang , Huang Shouzhi , Han Weiye , Chen Qiang , Li Yiliang , Pei Xiaohan 
Published: November 2017

Abstract
After long-term water-flooding, many of the matured fields in China have experienced changes in the physical properties of reservoirs. Moreover, the inefficient cycle of water flooding in the reservoirs is serious, and the heterogeneity of reservoirs causes difficulty to determine the distribution of remaining oil. It is impossible to reflect the real situation of the stratum only by simulation analysis with the numerical simulation software. To core in a specific location through coring technology and analyze the core can not only re-conduct a more accurate evaluation of the stratum, but also can modify relevant data of existing models to improve the simulation accuracy. But the current technology can’t conduct coring operations near wellbore and in deep parts.
Therefore, based on the ultra-short radius sidetracking technology, this paper aims to develop ultra-short radius flexible sealed coring technology to achieve coring outside the casing. Compared with the ultra-short radius sidetracking technology, the ultra-short radius flexible sealed coring technology has, in addition to the windowing, deflecting, and horizontal drilling tools, the core tools of this technology, that is, the flexible sealed coring tool. The tool is mainly composed of a flexible outer cylinder and a highly elastic titanium alloy inner cylinder. The flexible outer cylinder is connected by a multi-section of flexible units that can be bent up to 5°. And a special coring bit is connected to the front of the tool. The maximum length of the core taken in a single coring process is 1.1 meters; the core diameter is up to 40mm. By using this technology, the minimum horizontal distance of the core position and the borehole wall is 0.8 meter, and the maximum horizontal distance can be up to 100 meters.
At present, the technology has been successfully applied to more than 10 wells, and the average core recovery rate has reached 90%, which provides valuable data for the geological departments and is of great significance for re-developing matured fields.
This technology can obtain the core from outside of the casing and near wellbore, and offers a more accurate evaluation on changes of physical properties of the reservoirs, providing the basis for adjusting the subsequent water flooding development plans.