bluuebunny/crossref_metadata_2025_split huggingface dataset:
Proactive Well Integrity Management Through the Estimation of Residual Well Life
Authors: D'Alesio P. , Caramanico L. 
Published: December 2015

Abstract
Among the strategic issues of the Oil & Gas Industry, management of well integrity currently plays a key role, since it allows to simultaneously achieve two major objectives: minimize risk of uncontrolled release of hydrocarbons and extend the life of wells, thus getting the most from reservoirs.
Well integrity is about maintaining at least two independent well barriers at all times. This prevents reservoir fluids from being unintentionally and uncontrollably released at surface, and from migrating to other underground layers. However, degradation over time may weaken the elements comprising well barrier envelopes, and therefore impair well integrity if not taken into due consideration.
This paper describes an innovative approach to well integrity, which effectively puts the concept of "proactive management" into practice: the aim is not only to ensure that wells operate safely today, but also to be reasonably confident that they will properly work in the future in order to achieve an extended production life and optimize operational expenditures.
The subject approach complies with the ISO TS 16530-2 "Well Integrity for the Operational Phase", and uses both a failure mode analysis and a risk assessment technique to estimate the residual well life, on the basis of the expected degradation rate of well barrier elements.
The described approach enables to: Evaluate the current well integrity status through a risk-based perspectiveAnticipate future well integrity issuesElaborate a suitable risk reduction action planIdentify proper monitoring and maintenance requirements.
A dedicated software has been developed to effectively support the analysis of the current well integrity status and the identification of the well barrier elements that are expected to become critical in the future. The main characteristics of the software are also described.
RasGas Well Integrity Solution - Evolved, Engineered and Looking Beyond…
Authors: Kandaswamy Saravanan , Bugti Mehboob A. 
Published: December 2015

Abstract
This paper describes the development and deployment of a customised, on-line well integrity management system that has resulted in a major improvement in the effective and timely identification, diagnosis and remediation of well integrity issues in RasGas operations.
The system, which was built in-house on a web portal, is a business-driven, interactive and collaborative solution that integrates well integrity surveillance data (annuli surveys, integrity tests, corrosion log results, etc.) with maintenance schedules, and provides timely reporting of potential or observed integrity problems and harvesting of historical well data. This enables RasGas engineers and operations personnel to make informed and timely decisions on well integrity to ensure continued safe operation and a high level of well reliability and availability.
Key features of the system include effective visualisation of safety-critical elements and operating parameters from the field, effective tracking of integrity testing and preventive maintenance activities, use of "surveillance-by-exception" principle under which the system sends out a notification to all key personnel if any integrity-critical parameter on any well falls outside pre-established limits. The paper will illustrate the effectiveness of the system with actual field examples. Planned enhancements such as incorporating well failure models and individual well risk rating system will also be described.
While there are a number of packaged well integrity management tools available in the market, the uniqueness of RasGas system lies in its in-house development which has resulted in seamless integration with the existing data telemetry and processing workflows, flexibility in incorporating customised solutions and ease of scalability to accommodate increasing well count. The paper describes the key factors that contributed to the successful development and deployment of the system, including buy-in from all stakeholders, continuous feedback from field personnel and timely familiarisation and training of the end users.
The value of the Common Operating Picture for Emergency Response
Authors: Siermann J. , Hulshof B. , Slack D. 
Published: December 2015

Abstract
Managing the effect of a serious incident requires access and understanding of many types of information. For an effective and coordinated response to an incident a shared, common picture of the situation is essential. A common picture of reality is required by various organizations that look with different lenses to the incident so they all can collectively respond to it, in order to safe lives, environment and reputation.
A Common Operating Picture (COP) is a computing platform based on Geographical Information System (GIS) technology that provides this single source of data and information for situational awareness, coordination and communication to support emergency management and response personnel and other stakeholders involved in or affected by an incident.
The situational awareness provided by a COP is fundamental in the understanding of the relevant social, economic, environmental and logistic aspects of the (potential) incident. This paper explains how Shell is currently implementing a COP for all its major operations.
Developing Safety Leadership Skills at all Levels in an Organisation Drives Goal Zero Performance
Authors: Bralee Abigail , Peacock Mark , Norton Steve , Johnson Stephen 
Published: December 2015

Abstract
Despite a strong safety performance during construction, commissioning and early operations, in 2012 the Pearl GTL community embarked on a safety leadership development journey. Following a culture sensing survey the Site Leaders acknowledged that the safety culture at the plant was not what they perceived it to be. A period of discovery was undertaken to fully examine and understand the current safety culture; this was done through listening and enquiry deep into the organization with a deliberate intention to not react to the insights with actions until a full picture emerged. Only after this period of discovery and reflection did the leadership team start to envisage and articulate the desired safety culture for their community. It was recognized that doing more of what we knew, such as enhancing the management system and implementing short term campaigns would not sustainably lead us to Goal Zero.
The leaders took a bold decision to empower a group of high capacity individuals from across the organization to work with them to develop a long term improvement plan. This team - consisting of Engineers, Production Specialists, HSSE professionals, HR and Business Improvement personnel - worked for 18months in partnership with Site Leaders. The focus of the effort was on developing safety leadership at all levels by designing unique engagements, developing innovative tools, building capability and implementing new skills and today the improvement plan is making significant progress.
It is recognised that no single group in an organization, be it the senior leaders, supervisors nor the front line can impact the culture on its own and it takes a cross business, multi-level approach with consistent steer and commitment for the long term to be able to affect and develop the desired safety culture. In this paper, case studies and the positive Business impact at various levels in the organization will be discussed. The case studies will focus on the design of a unique programme for front line safety leadership development and how this evolved to include supervisors, how developing a cadre of Safety Leadership Coaches is affecting senior leaders and the importance of incorporating all the site programmes and initiatives within the culture of safety leadership.
It is over 2 ½ years since the last Lost Time Injury at Pearl GTL and visitors to the site tell us that there is a sense of community and workforce engagement that they rarely experience elsewhere, particularly for a plant with a short operational history. The same visitors are energized by what they see and reflect how they can envisage elements of the safety culture improvement plan at Pearl GTL being implemented in their own organisations.
SHE&S Improvement of a Major Subcontractor on the Barzan Onshore Project
Authors: DeHart Robert E. , Brand Johnny , Khan Khurshid 
Published: December 2015

Abstract
This paper illustrates how significant improvements were implemented for SHE&S (Safety, Health, Environment and Security) performance by Descon; a site Subcontractor organisation on the RasGas executed Barzan Onshore Project. Under contract to JGC, the project's primary EPC (Engineering, Procurement and Construction) contractor, Descon's work scope was to construct the Common Process South and Offsite facilities which have been completed.
At the outset of the project, Descon aligned their SHE&S (Safety, Health, Environment and Security) Management System with JGC's SHE&S management system, which is based on the EPC SHE&S contractual requirements provided by RasGas. However, in the early days of the project, Descon was incurring incidents at a frequency greater than the other seven subcontractors and also experienced the project's first Lost Time Incident (LTI) in July 2012. The paper evaluates the management system tools and practical actions that drove and sustained improvement of Descon's SHE&S management.
In response to incidents which had occurred, in the second half of 2012, Descon management made significant changes to their programme - including improvements to: SHE&S and craft training programmes; the site organisation; site SHE&S campaigns; enforcement of site SHE&S policies and procedures; and worker recognition. The improvements were also driven by various IIF (Incident and Injury Free) activities for ongoing engagement with the workers at the worksite and in the camps including: IIF site walks; social camp visits and management lunches with the workers; various camp sports; and educational and cultural activities. The improvement actions were captured within action plans, and key indicators were selected to monitor and measure the success of the programme. Since the July 2012 LTI and SHE&S programme overhaul, Descon established and sustained a positive safety culture with the workers and supervisors; worked 31 million man-hours without any additional LTIs; and clearly demonstrated leadership and innovation for SHE&S improvement on the project. This paper addresses how these improvements were accomplished and the actions that made these SHE&S programme improvements sustainable.
In summary, positive initiatives and actions taken by Descon ensured that the fundamentals of a SHE&S Management System were executed consistently and sustainably, with strong management commitment and buy-in by the workers and supervisors.
A High-Density Wide Azimuth 3D Survey in Oman
Authors: Tellier Nicolas , Denis Michel , Jacques Frank 
Published: December 2015

Abstract
A large high-density, wide azimuth, broadband 3D seismic project was recently acquired in an oil producing area of the Sultanate of Oman. The project aimed to outmatch legacy project results to accurately image a challenging geology, with strong time and budget constraints. This case study presents the key design, operations, and organizational points that enabled achieving the project successfully and record high-quality data.
To provide a clear understanding of the project stakes and fulfillments, the following features will be reviewed:
Local geology and geophysical objectives
Design of a high-density wide azimuth 3D survey
Project acquisition and productivity optimization
Crew organization, intensive logistics, HSE commitment, integrated QC chain
The proper imaging of the complex geology – including geological faults, traps, and thin beds - led to the choice of a high-fold full-azimuth geometry with a density of almost 10 million traces per square kilometer. Such a trace density, far above the average for desert projects worldwide, confirms an ever-growing trend and industry requirement, especially in the Middle East. The large block was acquired using the Distance Separated Simultaneous Sweeping (DSSS) technique combined with slip-sweep. With VPs being acquired single source, single point, and the use of super-heavy vibrators (90,000 lbf), the project produced very high quality data, even for the deep targets. Crew organization was paramount to achieve the acquisition on time and within budget. Almost 10,000 shot points were recorded on average daily with extensive HSE commitment.
An excellent dataset with a wide range of offsets and azimuths was acquired, outmatching the previous projects. Currently being processed, this dataset confirms the single-sweep single-source shooting strategy, and promises a new and thorough level of interpretation and understanding of the area that should lead to new productive prospects.
Optimal Learning of Field Operation and Well Placement in the Presence of Uncertainty
Authors: Klie Hector , Agreda Aquiles , Likanapaisal Pipat 
Published: December 2015

Abstract
We propose a novel learning optimization approach to find nearly optimal field solutions with a high probability and at a relatively low computational expense. Key attributes of the approach include capabilities to handle non-linear constraints in a dynamic fashion, automatic control of search directions; use of machine learning-based proxies; real time control of the optimization execution flow and, risk management decisions. The resulting algorithm retains the attractive property that the number of simulations is independent of the number of decision parameters as it progressively improves its rate of convergence as more information becomes available. We illustrate the new approach to determine multiple well locations and operation strategies to optimize field production on deep water and unconventional resource applications.
Research on Evaluation of Formation Water Salinity and Origin of Its Big Variation in Ultra-Low Permeability Clastic Reservoir
Authors: Feng Cheng , Mao Zhiqiang , Fu Jinhua , Shi Yujiang , Cheng Yumei , Li Gaoren 
Published: December 2015

Abstract
For big variation of formation water salinity in Chang 8 stratum, Triassic, northwestern Ordos Basin, China, low resistivity contrast exists between oil layers and water layers. In order to increase the accuracy of log interpretation, accurate formation water salinity is a vital part. Based on the petrophysical theory, this paper summarizes and improves two methods to estimate formation water salinity. Firstly, reservoir resistivity-porosity cross plot method is introduced for oil-water layers and water layers. To be specific, resistivity and porosity log values of target reservoir are added to the cross plot. Data points, which are closest to the origin of coordinates, are selected as water layer ones. Then, formation water salinity is calculated by Archie formula. Secondly, shale water salinity is approximately regarded as formation water salinity. Because shale water salinity estimation is a nonlinear problem with small sample sets and there is no theoretical equation, Least Squares Support Vector Machine (LSSVM) is used for shale water salinity prediction. 9 parameters are extracted from lithology, resistivity and porosity log curves, among which, 5 are optimized as sensitive parameters by Principal Component Analysis (PCA). The effectiveness and reliability of resistivity-porosity cross plot and improved SVM method are tested by 23 formation water chemical analysis data. The average relative error of the former method is 19.79%, while that of the latter 27.57%. In addition, formation water salinity of another 50 wells are calculated by the two methods. Based on them, a salinity plane distribution map is drawn by Geomap software. In high salinity area, producing wells gather. Thus, one possible origin of formation water salinity variation is proposed. High salinity water moves into reservoirs with oil from source rock, which leads to high water salinity. In ultra-low permeability clastic reservoir with near source accumulation, formation water salinity probably varies significantly because of oil migration and accumulation. Furthermore, layers with oil often have higher formation water salinity, which is the main cause of low resistivity oil layers. Thus, the accurate formation water salinity calculated by the improved methods, will play an important role in the evaluation of low resistivity contrast oil layers and water layers.
Subsurface Standards for Process Safety
Authors: Dean Michael C. , Goeyenbier Hans 
Published: December 2015

Extended Abstract
Several major safety incidents in the Petroleum Industry combined with the global nature of media interest have resulted in the focus on our industry rising to an all-time high. HSSE incidents impact the license to operate of not only individual companies, but also the entire industry. As such, the objective of this paper is to share one approach to formalizing standards around key Petroleum Engineering (Geology & Geophysics, Petrophysics, Reservoir Engineering, and Petroleum Technology) activities that have an impact on process safety, with the primary focus on well activities. Engineering standards with an impact on Process Safety are common within the Petroleum Industry however subsurface prediction standards have not generally been formalized in a similar manner, in part because subsurface prediction carries with it significant uncertainty which is higher than the uncertainty related to engineering design and calcualations. This project has helped to formalize technical standards for subsurface prediction within the Shell Health, Safety, Security, Environmental and Social Performance (HSSE & SP) Control Framework in the same manner that engineering standards are formalized.
Adapting the Caspian Factor for the Installation of PETRONAS’ First Gravity Based Structure
Authors: Rashdi Khairil Raezwan , Md Yusoff Md Nabil , Achong Omar 
Published: December 2015

Abstract
This paper presents the steps taken by PETRONAS Carigali (Turkmenistan) Sdn. Bhd., in undertaking the complex installation of a Gravity Based platform in the Caspian Sea. Its Gravity Based Structure (GBS) posed numerous installation challenges on top of the difficult and delicate constraints of the Caspian Sea – a combination that demanded creative solutions, design changes and tough decisions to realise this mega project.
Due to the scarcity of readily available resources in the Caspian Sea, the platform was designed to be self-installed without requiring a derrick barge. This was also one of the driving factors for the design of the substructure and superstructure. Hence, an ingenious design concept was opted for the platform - a self-installing 7,500 MT steel GBS with a conventional floatover topside. The GBS installation operation can be divided into several phases, namely Loadout, Dry Tow, Floatoff, Wet Tow, Lowering and Ballasting, Touchdown, Self-Penetration and Suction Penetration.
There are only a handful of steel GBS that have been successfully installed globally and this project, being the first GBS for PETRONAS, was by default a technical and operational challenge. The complexity increased as the GBS design especially its installation concept is unique and a first. With no prior experience of GBS installation in PETRONAS, this was indeed an unchartered territory for PETRONAS and more so for the project team. Through hard work, dedication, strategic decisions and sacrifices, PETRONAS is able to successfully deliver and install this one-of-a-kind state-of-the-art offshore facilities despite encountering numerous problems that challenge the very philosophy of the GBS installation concept.
The concept of self-installing GBS requires an innovative method for its offshore installation operation. Designed to be self-installed, the GBS’ installation philosophy undergone significant changes during the detail engineering, installation engineering and operation stages – changes deemed necessary to improve its installability and to suit onsite conditions. These changes include the enhancement through automation and barge mating, and Caspian winter sea state adaptability. Details of the changes and its reasoning will be highlighted in this paper.
Shop Testing of Major Turbomachinery in Oil & Gas EPC Projects - Cost Savings & Schedule Impact
Authors: Bustos Emmanuel , Mossolly Mounir 
Published: December 2015

Abstract
Turbomachinery for oil and gas EPC projects are shop tested to minimize the plant start-up risks and assure a trouble-free operation. However the extent of testing of turbomachinery vary with each project, though the minimum requirements dictated by the international codes and standards shall be met. In fact testing activities for turbomachinery are expensive, and specifying additional tests on top of the minimum requirements; which are narrated in this paper for major turbomachinery, need to be technically and commercially justified. Defining the extent of testing depends on several key factors which are listed and illustrated in this article. The Owner; in collaboration with the Contractor, is responsible to approve the required tests for a certain equipment based on critical analysis and a trade-off between risk, cost and schedule. However manufacturers' testing capacities do not always meet the testing requirements, this needs to be considered when specifying tests, else a test bed upgrade is necessary if the Owner is ready to contribute to the cost. This article surfs through the topic of shop testing for turbomachinery presenting best practices and lessons learnt from recent oil & gas EPC projects.
Use of Remote Sensing Techniques to Survey Detect and Interpret Hydrocarbon Seeps and Spills
Authors: Miegebielle Véronique , Dubucq Dominique 
Published: December 2015

Abstract
The objective of this paper is to present Remote Sensing technologies and methodologies developed within Total to detect Oil Slicks and to ensure spill response in the offshore domain. –In the case of incidents occurring on surface/subsurface facilities operated by Total or nearby facilities operated by others.–For regular monitoring of offshore production facilities.–Research concerning new emerging technologies in the remote sensing area is also dicussed.
Several actual field cases are presented (seeps, spills, boat sewages).
In the offshore domain, the majority of satellite data used for hydrocarbon detection consists of radar (SAR – Synthetic aperture radar) images. Because of constraints essentially due to meteorological conditions (important cloud cover….), the programming of radar data, from medium to low resolution, is favored to optical data, especially as the existence of radar constellations offers the opportunity to acquire an images everyday anywhere in the world. The ‘critical' point still remains the programming delay, which is the elapsed time before the collection of the first image acquired on the zone of interest. This delay is fixed by the technical specificities of each SAR satellite, the orbits trajectories, the localization of the area of interest (there are more daily acquisition opportunities at the poles than at the equator), the radar systems depointing capabilities (angles of shots…)