bluuebunny/crossref_metadata_2025_split huggingface dataset:
Addressing the Challenges of Obsolescence and Extended Life Operations
Authors: Belshaw Martin 
Published: September 2015

Abstract
This paper examines the increasingly significant issue of obsolescence and its prevalence in the light of extended life operations in the offshore oil and gas industry. Obsolescence can be likened to an insidious creeping plaque; it hides in the wake of new and changing technologies to take everyone by surprise around 10 years into the system life cycle.
To mitigate this problem a robust system of obsolescence management is necessary. This view is endorsed by the Health and Safety Executive (HSE), which recommended last year that the energy industry develops a corporate culture that embeds an ageing life extension (ALE) philosophy into asset integrity management for the long-term future (Health and Safety Executive, 2014). An important part of this process is the establishment of comprehensive procedures, systems and recording that allow for continuous monitoring of assets plus anticipation of issues, so that these can be managed proactively.
A progressive approach to obsolescence assessment involves offshore site surveys, reporting and detailed design studies. The resultant inventory is then subject to further assessment, using established methodologies and weighting factors to determine vulnerability, impact and risk. Sophisticated database systems now available for the recording, storage and analysis of such “intelligent” inventories. These allow operators to gain a clear and realistic picture of their assets, their associated systems and their place in the lifecycle. Such databases also provide a platform to explore tactics and strategies for removing or mitigating any obsolescence risk.
Nervousness within the industry about the impact on everyday activities is largely unjustified: both obsolescence assessments and system migrations can be carried out with minimal intrusion on normal day to day operations. Today's innovative migration upgrades cause near zero disruption to field wiring. Furthermore, when the value of such exercises is considered in terms of accident prevention and safeguarding against future costly disruptions, there can be no question as to the validity of such investments.
With many assets remaining in production for over 25 years, their associated control and automation systems continue to be used well beyond their life expectancy. Technology marches on, process functionality changes, the availability of spare parts declines, and eventually manufacturers and third parties are unable to provide technical support. Collectively, these issues pose major risks to production, safety and the environment.
Skagerrak HPHT Well Test Analysis and Field Productivity Prediction
Authors: van der Post N. , Sikiru D. , Nishi K. 
Published: September 2015

Abstract
Technical Category: “Smarter and More Efficient Field Development”
The Culzean field is a high pressure, high temperature (HPHT) gas-condensate field located in block 22/25a in the UK sector of the central North Sea. In order to determine the appropriate well count and facility capacity, it is important to accurately assess the individual well mid and long-term productivity.
This paper presents analytical and numerical Pressure Transient Analysis for the Culzean field and several other Skagerrak formation HPHT fields and proposes a method to predict mid-term reser-voir performance from log data. Skagerrak reservoir productivity is shown to be typically tenfold lower than what is estimated from core permeability. It is also shown that the core permeability is not a good predictor of mid-term well performance: whereas the permeability distribution for vari-ous Skagerrak fields is very similar, their field performance is not. The Pressure Transient Analysis of the various Skagerrak fields also shows similar trends, and hence this cannot serve as a good predictor either.
What is driving mid-term well performance in Skagerrak is the sand-sand connection far away from the wells, which can be estimated from the well test build-up data using a reservoir simulation box model and automatic history matching. It is then shown that the net to gross estimated from the Neutron/density log forms a reasonable predictor of the sand-sand connectivity and hence mid-term well performance.
Pore Volume Analysis of Gas Shale Samples Using 3-D X-ray Micro Tomography
Authors: Mehrabi Mozhdeh , Pasha Mehrdad , Jia Xiaodong , Hassanpour Ali 
Published: September 2015

Abstract
Understanding the porosity of gas shale is of great importance in many applications such as for enhanced recovery in gas reservoir. The first step for understanding the above properties is the precise quantification of the structure of the porous media. The structure may be characterised using traditional surface area measurement or mercury porosimetry for pore size analysis. However, these methods would provide data rather on pore sizes rather than their structures and configuration within low permeable samples.
Modern 3D and non-destructive imaging techniques such as x-ray microtomography (XMT) provides a more convenient and intuitive alternative technique to scanning electron microscopy. The importance of quantitative pore structure characterization in understanding shale reservoir behaviors and lack of measurement techniques are the two main motivation factors behind this research.
In this research three-dimensional x-ray micro tomography (XMT) imaging techniques were used to carry out a three-dimensional pore volume analysis of shale samples based on pores size, structure, geometry and orientation.
Two samples with different properties (mainly in mercury intrusion porosity, MIP) were tested. It was found that the overall micro porosity obtained from XMT is about 0.7% and 0.3% for sample 1 and 2 respectively and significantly less than those of MIP. Both samples have very close structure orientation and geometry of the pores.
Training Techniques for the Internet Generation
Authors: Ross Martin 
Published: September 2015

Abstract
Ten minutes in the company most school or college-age people almost anywhere in the world today is enough to make it apparent that young people live in an always-on, Internet-connected, multi-tasking world. Mobile devices, cloud computing, gaming, multiple devices, Internet information and multi-channel entertainment have revolutionised the everyday experiences and expectations of the talent pool available to the oil and gas industry. To compete and retain the human capital needed to sustain the industry, new solutions for education and training that respect the changing expectations of the workforce are required. The rapid evolution of consumer electronics and the cloud-based computing platforms of the future are set to revolutionise the learning experience of the next generation.
Focusing on the role of the control room operator and the field technician in the oil and gas industry, this presentation explores methods and tools organisations can use to enhance the learning experience of the student, as a new recruit and throughout their continuous professional development. A framework is described that allows organisations to design learning and training experiences that will be engaging for the students and cost effective for the organisation.
By designing the student workbook using a theoretical framework it is possible for students to develop towards clear, well-defined goals at their own pace, while KPI-based feedback helps identify performance gaps and provides opportunities for active interventions. Examples show how “gamification” techniques such as virtual reality simulation, together with more traditional challenge and response scenarios, provide an enriched experience for both teacher and student. These new techniques motivate and engage students, increasing attainment of learning outcomes and improving retention of knowledge, skills and behaviours.
The economic and social imperative for safe, efficient production combined with the compulsion to grow shareholder value puts immense pressure on human capital. Education and training performance is an efficient lever to help respond to these challenges.
Importance, Development and Management of Critical Judgement for Engineers in the Offshore Industry
Authors: Morgan Neil 
Published: September 2015

Abstract
The ability to develop and use critical judgement defines and differentiates engineering excellence in our industry, yet it is one of the hardest skills to codify and replicate. This paper deconstructs the individual components and builds them into a framework that engineers and organisations can use day-to-day to develop consistently robust, pragmatic and timely decision making skills, whatever the situation. This is a key requirement for organisations to trust and empower people to perform effectively in increasingly unfamiliar contexts. Examples are given where critical judgement has influenced engineering situations and issues with the term ‘judgement’ are examined, including understanding the judgement of others, explaining your own judgement, importance of information to different experts; where the term ‘judgement’ is used to limit further engineering or analyses and the role of international codes and standards. After outlining the work of others, the paper provides a framework for critical judgement for engineers and other facilitators of judgement, such as managers or project managers, in the offshore industry and explains the key factors involved. These factors include scoping the problem, focusing on important aspects, practicalities, selection of methodology, sensitivity to assumptions, precedence/comparison, consequences of failure and pro's & con's and conservatisms & unconservatisms. Each of the factors within the framework can be used at any stage of a typical problem solving processs. It then outlines aspects of technical governance used within Lloyd's Register to consistently develop and manage judgement including technical authorisations and technical networks.
Cap Rock Restoration in Plug and Abandonment Operations; Possible Utilization of Aplite-Based Geopolymers for Permanent Zonal Isolation and Well Plugging
Authors: Khalifeh Mahmoud , Saasen Arild , Vrålstad Torbjørn , Larsen Helge B. , Hodne Helge 
Published: September 2015

Abstract
When a well reaches the end of its life-cycle, it is permanently plugged and abandoned. Since the first discovery in 1966 on the Norwegian Continental Shelf (NCS) till October 2014 nearly 5496 wells have been drilled. Of these wells, 3978 are development and 1518 are exploration wells. Of the development wells, 699 have permanently been abandoned and 279 are in temporary abandonment status. It is estimated that 3279 development wells need to be plugged and abandoned in the future. Besides, the number of wells which will be drilled in future should be added for plug and abandonment.
The costs of these P&A operations will be substantial. Hence, there is a need for technology development that will reduce the costs of all these operations. This development involves both techniques, tools and materials. The current work describes different plugging materials and important characteristics of permanent barriers with respect to long-term integrity. In addition, different roots of failure modes of permanent barriers have been discussed. Geopolymers are suggested as possible permanent plugging materials. Geopolymers are aluminosilicate materials, which solidify. A new geopolymeric material is introduced for the permanent zonal isolation and well plugging; an aplite-based geopolymer. Its placeability was studied by investigating the rheological behavior of the geopolymer slurries. The Bingham and Casson models selected to simulate the slurries' viscosities. Both models were fitted to the measured data. Strength development of the produced geopolymers showed sufficient compressive strength. X-ray powder diffraction was used to characterize the microstructure of the produced geopolymers. X-ray patterns showed formation of an amorphous phase. The measured permeability was in the range of nano Darcy. The initial result shows that the aplite-based geopolymer has the potential to be utilized as a permanent plugging material for well plugging and zonal isolation.
The Effect of Bending and Axial Compression on Pipeline Burst Capacity
Authors: Taylor Neil , Clubb Graeme , Matheson Ian 
Published: September 2015

Abstract
High-pressure high-temperature (HP/HT) reservoirs contain hydrocarbons at pressures and temperatures in excess of 10,000 psi (690 bar) and 300 °F (149 °C). The high pressure often requires the installation of a high-integrity pressure protection system (HIPPS) to facilitate a workable pipeline concept and to prevent over-pressurisation. Should the HIPPS fail to respond to an overpressure event, the pipeline may be exposed to pressures in excess of a code-allowable design. It is, therefore, important to fully understand the pipeline behaviour, especially the burst limit state, to ensure compliance with the pressure containment philosophy, i.e. “burst critical” or “no burst”, and the associated probabilities of pipeline failure due to bursting. Generally, a probabilistic analysis will be performed using existing models that predict the burst capacity of straight sections of pipe under the effect of internal overpressure.
In reality, pipelines are subjected to additional loads over and above pure pressure loading; for example, thermal loading will induce compressive axial loads in the pipeline due to pipe-soil frictional resistance. Pipelines are also frequently subjected to bending loads due to a variety of causes; for example, freespans, trenching induced bending, or lateral buckles. To understand the burst behaviour of a pipeline, the effects of bending and themally induced axial compression in conjunction with internal overpressure must be understood.
This work shows that finite element analysis (FEA) can accurately predict the occurrence of pipeline failure due to burst. The FEA is validated by subjecting models of a straight pipe to internal overpressure until burst occurs, and comparing the burst pressure and strains at burst to the predictions made by an analytical model. Subsequently, the FEA incorporates various magnitudes of bending (representative of the range of bending that may be induced by prop-type imperfections up to 0.5 m in height) before internal pressure is applied. Both displacement and load controlled bending are investigated, as well as cases that consider thermally induced axial compression. The burst behaviour of the pipe for the various cases is compared to confirm whether the analytical model is still valid in cases when bending and/or temperature are present.
Thermal loading and displacement controlled bending are found to have negligible effect on burst capacity, because the axial compressive and bending loads are “shed” as the pipe becomes plastic and reduces in stiffness. However, it is observed that there is a significant change in burst capacity for load controlled bending, and hence the analytical model is no longer valid. This is because the applied moment is, by definition, maintained and unable to be shed; instead, the imperfection shape changes significantly to satisfy the loading condition as cross-section plasticity and the associated reduction in stiffness are experienced.
Developing Talent to Meet Demand A Case Study of the Production Technology Discipline in Upstream International Operated
Authors: Godwin Chinyelu Aronu 
Published: September 2015

Abstract
Our industry is highly dependent on competent, innovative and motivated professional workforce to deliver the world energy needs now and years to come. Resourcing the business with the right numbers and skill level at all strata of the organization requires that we continue to develop our young professionals and also provide opportunities for the experienced professionals to continue to grow. This paper discusses current best practices deployed and the impact on the business, using the Production Technology (PT) Discipline as a case study.
Development of young professionals is achieved through 3 key ways: In-role development, mentoring and coaching and formal learning. These 3 mode of training follow the 70:20:10 approach to maximize learning where it is expected that 70% of learning occurs through on-the-job experience and learning as you carry out tasks; 20% through interactions with others (coaching, demonstrations, peer-to-peer sharing, etc.); and 10% through formal learning (e-learning, classroom, etc.).
Operator X Graduate Programme (SGP) and the Advanced Graduate Programme (SATP) are some of the recent modes deployed to ramp up the technical capabilities of new graduates. These have aided in cutting down the number of years to “autonomy” while maintaining the quality and efficiency of the technical professionals. For the more experienced staff, operator X has tailored their role specific needs through the technical learning portfolios which include the Project Academy and the Production Academy. The mode of delivery of the trainings is tailored toward the learning objective, for example – awareness training versus on-the-job learning support, etc. In many technical learning portfolios, the blended learning mode is more favored (with emphasis on adequate preparation prior to the classroom event (f2f), more hands-on during f2f and the continuation of learning after the f2f). The formation of Subject Matter Expert (SME) networks to address different subject areas in the Discipline has also helped in deepening the skills of the experienced staff while accelerating learning for the less experienced. The Production Technology career Path Plan provides a vehicle to deploy these tools and processes and consequently transform talented but in-experienced graduates to seasoned and motivated professionals.
Asset Integrity: Managing the Maintenance Burden
Authors: Arthur Neil , Lusher Jody 
Published: September 2015

Abstract
The UK Oil & Gas (O&G) faces significant challenges to ensure future economic potential is maximized. Current issues include escalating maintenance backlogs, facility unreliability; an inability to liquidate production-enhancing or important asset integrity workscopes and uncertainty of the rationale justifying existing maintenance programs. This paper presents the application of a novel maintenance optimization technology that has delivered performance improvement through the deterministic consideration of both commercial and reliability criteria when determining planned maintenance intervals. Real case studies are presented alongside the concomitant benefits. The technology was used to determine an optimized planned maintenance program for deployment in both existing operations and new facilities, and has delivered benefits when compared with traditional approaches to determining maintenance intervals. The technology marries both technical and commercial considerations when determining optimized planned maintenance and, in this way, the modulation of planned maintenance programs in response to changes in production, commodity value or equipment reliability is easily achieved. Based on results of the work carried out using the technology, it is proposed that there are significant benefits available to the UKCS through the adoption of similar techniques, as it is understood that many operators currently struggle to justify existing planned maintenance regimes, and to demonstrate a defensible means by which to alter these regimes in response to a changing economic and reliability criteria. Application of this new technology may provide a means of modulating maintenance in response to changing criteria and offer potential concomitant benefits in helping tackle backlog, bed space and production efficiency challenges.
Assessment of Production Engineering Workflows for Saudi Aramco Production Operations Surveillance Hub (POSH)
Authors: Al-Khelaiwi Faisal T. , Al-Amri Meshal A. , Al-Amri Nami A. , Al-Awajy Majed A. , Jama Ali Ahmed 
Published: September 2015

Abstract
Saudi Aramco's rapidly growing portfolio of fields and wells demands the employment of innovative approaches to manage its assets efficiently in today's challenging economy. One of the main strategies that the company has adopted is the creation of a highly interactive surveillance environment called Production Operations Surveillance Hub (POSH), that supports business collaboration and efficient decision making processes. POSH enables the business to exceed geography and time by consolidating multidisciplinary team knowledge, streamlining communication, providing real-time collaboration and facilitating quick decision making. The POSH also provides an e-workplace for oil and gas production automation and optimization that allows business team members and their partners (within and outside the company) to communicate and coordinate activities from anywhere in real time.
The creation of this environment started with a comprehensive assessment of the production engineering (PE) activities and processes. The assessment was conducted through electronic surveys, face-to-face interviews and interactive workshops to gather the required information from PE experts and develop a full understanding of their work processes. These “as is” processes were then transformed into “to be” workflows where technology applications were associated with each step of the process. A detailed design phase followed, which involved defining the engineering calculations, the communication protocol and the data exchange pathways among the different components of each workflow and between the workflows. A cataloging and organization phase followed in which four main themes were identified for the POSH and aligned with Saudi Aramco's intelligent fields' development strategy. The four focus areas include: well and field activities management; intelligent field equipment performance and real-time data health; electric submersible pumps (ESP) surveillance and pre-diagnostic; and well production and performance monitoring.
This paper describes the assessment planning and implementation process. The paper also illustrates the value of this process through elaboration on the assessment outcome and provision of details of the POSH themes and functions. This step is essential for the success of the deployment of Saudi Aramco's first POSH and similar collaborative environments.