bluuebunny/crossref_metadata_2025_split huggingface dataset:
A combined integrated multi-method approach for the assessment of the thermal maturity of sedimentary basins
Authors: Di Paolo L. , Corrado S. , Romano C. , Aldega L. , Di Genova D. , Grigo D. 
Published: December 2014

Abstract
The reliable assessment of thermal maturity of sedimentary successions is crucial for the evaluation of hydrocarbon generation/expulsion. Uncertainties in thermal maturity assessment up to 0.2-0.3% of vitrinite reflectance values can occur according to commonly adopted parameters (eg., vitrinite reflectance, Tmax, etc.) especially when exploring Lower Paleozoic shale gas targets that are devoid of vitrinite macerals. This level of uncertainties is not acceptable in thermal modelling and can negatively influence decisions on the development of prospects.
This contribution provides a new methodological workflow to assess thermal maturity of organic matter dispersed in sediments and hosting sedimentary succession to largely reduce such uncertainties.
The multi-method approach consists in combining optical analysis and Raman and FTIR spectroscopy of organic matter dispersed in sediments with X-ray diffraction of the inorganic fine-grained fraction of sedimentary successions.
The four techniques have been systematically compared in diagenesis for the first time. Results are from an about 3000 m deep Cretaceous-Silurian section that shows a regular and highly resolved trend of increasing thermal maturity with depth on the base of spectroscopic and XRD data, and a general agreement among vitrinite reflectance, FTIR quantitative and qualitative indexes, pyrolysis and Raman indexes. Levels of thermal maturity of dispersed organic matter range from immature-early mature stages of hydrocarbon generation in the Cretaceous-Jurassic section to mid-late mature in the Triassic and Silurian units. Moreover, fine grained sedimentary rocks record an increasing trend of thermal maturity from early diagenesis in the Cretaceous-Jurassic section to late diagenesis for the Triassic and Silurian sections.
Flawless Startups in Iraq - Majnoon Oil Field Achieves First Commercial Production
Authors: van Huysduynen Tom Hooft , Ames Simon , Tierney William , Verspoor Remco 
Published: December 2014

Abstract
The Majnoon Field was discovered in 1976 and brought online in 2002 by the Iraq South Oil Company (SOC). In December 2009, during the Ministry of Oil's 2nd Petroleum Licensing Round, Shell won the right to develop the field under a Development and Production Services Contract. Shell Iraq Petroleum Development BV (SIPD) became operator for the Majnoon Field (45%), with partners Petronas Carigali (30%) and Missan Oil Company (25%).
In September 2013, first oil from the combination of newly built and the refurbished existing facilities & wells, was established. In accordance with the terms of the contract, a minimum average flow rate of 175k bpd over a period of 90 days was achieved in order to meet the First Commercial Production (FCP) target and thus allow Shell to begin cost recovery.
This paper will be based on Shell's experience executing the Majnoon field development in South Iraq. The project scope was completed in challenging circumstances, with very little subsurface information available to confirm design assumptions. As a result, a number of execution risks were transferred to the commissioning & initial start-up operations. The team ultimately relied on experience, planned contingencies and intelligent workarounds to achieve the FCP production target.
The key startup challenges will be discussed in this paper that are relevant to the audience, particularly those involved in field start-up & operations. Conclusions will relate to how the team overcame flow instabilities (slugging) from daisy chained pipelines (linking the multiple wellpads), crude foaming in the process facilities, welding debris in the flare system, dealing with export curtailment (process stops and re-starts) and establishing custody transfer measurement with SOC.
In addition, this paper will present a selected number of Majnoon lessons learned during the commissioning & startup period and how Shell improves Project Delivery in subsequent projects to achieve Flawless Startups to meet the original project premises of safe, reliable production under specified costs and schedule constraints.
Transporting Sour Gas in a Non-Corrosive Form through use of Remote Dehydration Units
Authors: Jain Kirti , Sreenivasan Venkatesh , Djordjevic Ljubisa 
Published: December 2014

Abstract
A major challenge faced by many natural gas developments in the MENA and CIS regions is transporting raw, wet, sour gas from wells to the Central Processing Facility (CPF). The presence of H2S or CO2 and H2O in raw wellhead fluids creates a highly corrosive environment, which dictates the use of expensive corrosion resistant materials such as nickel alloys or stainless steel.
Petrofac designed, built and commissioned a sour gas processing plant in the CIS region, which includes remote, unmanned Gas Treatment Units (GTUs). The GTUs are located up to 16 km away from the CPF, and receive sour raw gas from the wells for treatment using conventional TEG dehydration. The main function of gas dehydration is to dry the gas, thereby eliminating one of the components that causes corrosivity of the gas. This avoided the requirement for cladding the large bore, sour gas transfer pipelines with corrosion resistant alloys (CRA), which would have resulted in high costs, mitigating schedule and construction challenges involved in the installation of CRA pipelines.
Dealing with raw, wet, sour gas is a global challenge faced in many plants worldwide, and has been a major cost and schedule challenge due to the use of corrosion resistant materials. The development solution illustrated in this document depicts an innovative method for transporting sour gas for treatment without the use of large bore CRA pipelines, and can reduce costs of construction and procurement substantially. Similar applications can be made in large scale natural gas processing plants where sour gas and H2O combinations exist, provided that thorough cost analysis is performed to determine the technical and financial viability of the option.
GTU operating data in the form of online water content measured by dew point analysers are documented in this report. Laboratory analysis of the dry sour gas and lean TEG are also included, with the results demonstrating the successful performance of the GTU design.
Fire Dynamics Simulation in Oil and Gas Tanks: A Key Parameters Study
Authors: Al Mezaini I. A. , Ali M. I. , Shatilla Y. 
Published: December 2014

Abstract
In the current economical market, sustaining a great level of process and company protection is a serious apprehension. Makers can reduce expenses by diminishing destruction to apparatus and exterminating incidents that affect individuals and the atmosphere. Oil and gas industries in recent times have need to meet the challenges with alternative resources being explored by the human mankind. That mandates for producing oil and gas with zero losses. One of the major contributing factors that accounts for increase in cost of production are fires. Fires in oil and gas industries can be mitigated if the potential threats and foreseen consequences are known to the operators. Fire Dynamics Simulator (FDS) software is an appropriate tool that should be implemented at project planning stage by the designers and it should be a part of mandatory requirement implied at approval stage of an oil and gas project.
This paper analyzes risks of fire whirl when it is occurred at oil and gas platforms. The study hopes to show how fire patterns are influenced by circulation of air. The fire whirl process over liquid fuel is simulated using FDS, Which produces the development of fire and the change of the radiation intensity and flame height in the case of fire whirl. Also, consequences of fire and wind interaction are considered in this paper. The study results provide reference data and theoretical guidance for fire protection design and firefighting tactics in case of fire whirl. In addition, findings of this study will deliver an optimal safe design for oil and gas facilities.
From Surface To Subsurface: Cenozoic And Mesozoic Carbonate Reservoir Sequences From North Of Erbil, Kurdistan Region Of Iraq
Authors: Conradi Florian , Sauer Roman 
Published: December 2014

Abstract
We aim to demonstrate the use of high-resolution sedimentological data during the early phase of the exploration cycle. The data reviewed included more than 1300 m of log sections taken North of Erbil. This was combined with field mapping, a microfacies study and the acquisition of routine core analysis data from plugs to provide a more complete analysis. Subsurface data included lithological information from two wells and 2D seismic lines with a total length of 487 Km.
The study focussed on carbonate sequences including potential and known hydrocarbon reservoirs, notably the Qamchuqa-, the Shiranish-, the Khurmala- and the Pila Spi Formations. As a result a refined stratigraphic and depositional framework for the Lower Tertiary and Upper Mesozoic sequences has been established. The Cretaceous sequences analysed herein display a series of distinct lithofacies types ranging from shallow marine to deeper marine environments, which can be attributed to different main depositional complexes. The Paleogene sequences show a high diversity of lithotypes that relate to fluvial, fluvio-marine, mixed siliciclastic - carbonate shelf and inner platform depositional environments.
Outcrop samples from both Tertiary and Cretaceous dolomites inherit the highest porosities thus presumably best reservoir quality in the subsurface. However, the effect of fracturing cannot be assessed in detail from surface data alone.
A 3D facies model has proven useful in displaying the spatial relationship of the well and outcrop data. The display of facies probabilities improves the recognition of cyclicity within homogeneous dolomite sections. Possible extent and connectivity of geobodies could be assessed with the model.
The results have been compared with, and put into a regional context with data from literature and proprietary selected subsurface data. The outcrop data have been incorporated into a workflow that supported other G&G subsurface disciplines during the exploration phase.
Impact of Competency Management Program on Job Satisfaction
Authors: Mahmood Sadaqat , Mushtaq Saman , Hussain Jamila , Khan Mehwish N. 
Published: December 2014

Abstract
Massive developments have transformed the field of Human Resource Management into a vast new field of study. All HR practices are now based on strategic application with real effect on business. Human Resource of any company is considered to be the greatest asset and having a competent workforce always lead tangible results to the organization. Significance of Competency mapping and management is inevitable and has been studied invariably as part of applied sciences. A competent employee is considered to be well performing one as well as highly satisfied. Job satisfaction itself is said to be the most discussed topic in the field of organizational psychology while competency has been progressively successful in terms of its pragmatic implementation within the organizational arena; but the relation between these two is not much explored. This paper has laid foundations of determining this relationship. We selected the company that specializes in oil field service industry and has successfully established a competency management system. Using questionnaire as tool, we have found that there has been very positive effect of having a Competency Management System on Employee Job satisfaction. Considering the exploratory nature of the study, we see that it focuses only on two parameters i.e. Competency management system and job Satisfaction and has left room for future researches. Question statements were driven from the literature defined as well as tools established by previous researchers. This can be carried forward by measuring the overall effect on job satisfaction by all organizational factors including pay and benefits. This will help us calculate the importance of having a Competency management System within an organization.
Deployment of High-Resolution Reservoir Simulator: Methodology & Cases
Authors: Cominelli A. , Panfili P. , Casciano C. , Rotondi M. , Delbosco P. , Trajtenberg H. D. , Thompson A. M. 
Published: December 2014

Abstract
The oil industry is developing more and more complex reservoirs, often lying in difficult environments like deep or ultra-deep water. At the same time, brown fields are systematically studied to implement IOR and EOR processes to increase the ultimate recovery factor. In this context one of the challenges is to simulate highly detailed models and provide robust answers for corporate decision making processes. Because conventional reservoir simulators are not very well suited for these purposes, new generation reservoir simulators are tempting solutions. During recent years eni is implementing a step-change in the way reservoirs are modeled and simulated, deploying a new generation, high resolution simulator for the most critical and complex assets. The purpose is twofold: computational efficiency on one side and enabling the development of more accurate models on the other one. The process is run in a selective manner, aimed at identifying opportunities when conventional simulators do not meet expectations.
In this paper we present the methodology used by the Company in the selection of field cases, together with the results achieved for some of the most interesting and complex assets. In particular, comparative results, with respect to conventional simulators, are presented for: deep-water reservoirs, a tight oil development, CO2 injection schemes, and a large scale heavy oil project. The analysis is performed using key computational and engineering performance indicators. The deployment is run in cooperation with the technology provider: cases, logic, issues and solutions are discussed together in a critical manner.
The process is run on the basis of long term corporate objectives, targeting the simulation of EOR processes and complex assets in a computationally efficient and accurate manner.
Enhancing the Value of Sulphur: Using Sour-To-ACid as Field Development Concept
Authors: Gierman M. , Lebel M. , Micone P. , Carrillo E. 
Published: December 2014

Abstract
In order to meet future growing gas demands, resource owners will develop more complex gas fields which contain relative large quantities of sulfur containing components. A critical aspect of sour gas field developments is the disposal method selection for the sulfur. Traditionally the sulfur containing components are converted into solid sulphur. Production of large quantities of solid sulphur makes sour gas field development costly and challenging.
In this paper, the application of Sour-To-Acid as alternative field development concept for sour gas fields is presented. In comparison with conventional field development concepts where solid sulfur is produced, the Sour-To-Acid concept converts sulfur containing molecules from the wellhead directly into sulfuric acid.
Sulfuric acid is globally the most produced and traded chemical. Driven by the increase in population and living standards, the sulfuric acid demand will rise steadily over the coming years. The Sour-To-Acid concept links sour gas developments with the sulfuric acid demand increase.
It is demonstrated that the Sour-To-Acid concept – enabled by Cansolv SO2 scrubbing technology - can form a competitive and alternative concept for sour gas field development. Considering the overall value chain, both savings in investment and operational costs can be achieved by application of the Sour-To-Acid development concept. Additionally, the sustainable footprint of sour gas field developments can be improved. All together, the Sour-To-Acid concept enhances the value of the sulfur present in the reservoir.
Lesson Learnt from Implementing Hse Equipment and Systems in Accordance with Adnoc Cop V6-01
Authors: Basha R. 
Published: December 2014

Abstract
ADGAS has gone through the implementation cycle of the HSE critical equipment and systems (HSECES) in line with ADNOC directive issued in code of practice COP V6-01. The COP stipulates all Abu Dhabi National Oil Company (ADNOC) group companies must identify equipment and systems that will contribute, cause or protect against a major accident hazard, covering the whole life cycle of the plant, from conceptual design right through to decommissioning. HSECES Assurance processes and procedures are developed and implemented to ensure the mitigation of the risk in the case of equipment failure contributing to Major hazard and assurance of the functionality of equipment and systems protecting against a major hazard. In ADGAS HSECES compliance is monitored through the issuance of equipment and systems compliance exceptions report, highlighting noncompliance of HSECES and recommending remedial actions, a series of audits are planned annual audits are conducted by each Independent competent person to ensure the effectiveness and compliance of HSECES's against the performance standards.
The paper will share ADGAS's experience and lessons learned from the implementation process of COP V6-01, identification of HSECES systems and equipment, development of performance standards. Establishing exceptions reporting system for equipment and systems as well as spares inventory monitoring and closing the loop through internal and external compliance assurance.
Global Buckling and Pipeline Walking Interaction - A Unique Challenge
Authors: Hakim M. Abdel , Azouz A. M. , Yehia M. 
Published: December 2014

Abstract
Pipeline walking is a phenomenon known to affect ‘short’ high temperature subsea pipelines subject to cyclic loading such as startup / shutdown cycles. Pipeline walking is a form of ratcheting response in the pipeline axial displacement under certain conditions such as seabed slopes and thermal gradients. Unfortunately, the industry's understanding of pipeline walking is still developing due to the complexity of the walking mechanism as well as limited availability of operational verification for the design predictions.
Pipeline walking is in many cases overlooked for ‘long’ HPHT pipelines which are typically susceptible to global buckling. Hence, for such lines the global buckling design is carried out without due consideration of pipeline walking. However, global buckles effectively divide a ‘long’ pipeline into a number of ‘short’ pipeline segments which may be susceptible to walking. The interaction between pipeline walking and global buckling may affect the long term development of the global buckles as well as the pipeline end expansions.
Therefore, ADMA-OPCO has initiated a detailed assessment of global buckling and pipeline walking interaction on a recent subsea pipelines project. The assessment showed that the interaction between the two phenomena can have a significant effect on the pipeline response in terms of the expansion behavior and buckle growth. The key findings of the assessment are presented along with an overview of the design process and the typical mitigation techniques to be considered for similar subsea pipeline projects.
Recruitment and Retention of Emirati Gen Y in the Petroleum Industry: A Gender Comparative Study
Authors: Lim Hwee Ling 
Published: December 2014

Abstract
The United Arab Emirates (UAE) petroleum industry needs to secure talented professionals in a difficult labor market due to the retirement of older workers and the entry of a large younger Generation (Gen) Y cohort. Moreover, young women professionals remain an underutilized source of human capital even as oil-gas companies have made progress in Emiratization. Since there is limited research on Gen Y professionals at work in the UAE, this study investigated gender differences in the work motivators of Emirati Gen Y in the energy sector and compared factors affecting their recruitment and retention. Surveys (face-to-face and online) and interviews (individual phone interviews) were conducted with respondents from a major UAE petroleum company. The sample comprised 45 employees, born 1980 to 1990 (aged 22 - 32 years in 2012), both genders, holding technical and administrative positions in the company. Quantitative and qualitative data were obtained and the findings showed that intrinsic and extrinsic work motivators were most important in the Gen Y professionals' vocational decisions. The results also showed changes in the importance placed on specific intrinsic and extrinsic motivators, by each gender, in recruitment compared to retention. The findings contributed to the field of human capital development and Emiratization in the UAE. The study added to current understanding of the work motivators of Gen Y who are vital to the future of the energy industry. The recommendations for the effective recruitment and retention of Gen Y provided can be used to guide companies, not just limited to those in the petroleum industry, formulate personnel policies that will positively influence Gen Y professionals' decision to join and continue working for the organization.
Viscoelastic Surfactants Based Stimulation Fluids with Added Nanocrystals and Self-Suspending Proppants for HPHT Applications
Authors: Aggarwal Avi , Agarwal Soham , Sharma Shubham 
Published: December 2014

Abstract
With dwindling resources and mushrooming energy demands worldwide, HPHT field development has come under the limelight of the industry. Thus for expanding the existing horizons, new frontiers in HPHT stimulation advancements are being anticipated for economical harnessing of hydrocarbons. From more than a decade, surfactant fluids had been extensively employed in completion and stimulation operations as the surfactants arrange anatomically to form very long worm-like micelles, maintaining considerably low formation damage levels, and simultaneously exhibiting brilliant rheological properties, viscosity and proppant transportability. High fluid leak off and its inability to withstand temperatures greater than 200°F, have limited its HPHT application. Similar is the case for proppants where significant advancements have been made to increase its strength, but with better strength it has become heavier, causing early screenout, making it unable to reach deeper-complex fractures and requiring more viscous fluids.
This paper discusses in detail an extensive review of the application of nanoparticle and hydrogel polymer technology to enhance fluid – proppant performance in conditions with temperatures nearing 275°F and brine density up to 14.4ppg. This can be achieved by developing nano-sized crystals, which colligate with VES rod-like micelles to yield a virtual viscous filter cake that significantly curbs the fluid loss rate, thus demonstrating wall building on the porous media, rather than usual viscosity dependant leak off control. When internal breakers are applied, VES micelle structures degrade rapidly, leaking off VES fluid and the pseudo filter cake will then split into brine and nanoparticles, thus producing formations remains intact. To augment its performance proppants can be encapsulated with a thin hydrogel polymer layer which will hydrate on coming in contact with water. This layer smoothens the proppant, adsorbs the fines, and makes the proppant self-suspending. This wonder layer is resilient to high pressure high temperature conditions and exhibits excellent characteristics which are elucidated in this paper.
When applied, nanotechnology can reduce requirement of VES fluid volume by 60% and permeability range of VES fluid application is extended upto 2000md. While the incorporation of self-suspending proppants (SSP) can significantly bring down the requirement of additives and enable fracturing of challenging formations with maximum retained conductivity.