bluuebunny/crossref_metadata_2025_split huggingface dataset:
Installation of the World's First Subsea Thermoplastic Composite Flowline for Hydrocarbon Service
Authors: Spruijt Wouter 
Published: March 2018

Abstract
The Thermoplastic Composite Pipe (TCP) has been established for a number of years as a viable alternative to steel and flexible pipe in subsea applications, with various intervention type of applications building track record in the field. After the successful installation of a Thermoplastic Composite Pipe for permanent methanol injection on Chevron's high-pressure Alder field in the North Sea in September 2016, Airborne Oil & Gas moved forward with the installation of a flowline for a full well stream application.
The selection of a TCP Flowline ensures a CAPEX reduction as it is manufactured in long continuous length up to 6000 meter and reeled on lightweight transport /installation reels. This allows for reel-lay or surface tow installation with a low-cost installation spread, contrary to steel pipeline requiring slow lay-barges. Furthermore, the TCP flowline can be terminated on the platform and pulled through the I or J tube without the end-fitting, allowing for small and light I or J tubes. The TCP Flowline can be installed in a single pass, optionally with a weight coating to achieve on-bottom-stability and immediate burial with for example a jet trencher if required. This single vessel installation results in the lowest material and installation cost for TCP Flowline compared to the alternatives.
Besides the CAPEX reduction, the selection of TCP flowlines ensures a significant OPEX reduction. Integrity management and corrosion prevention in particular have significant impact on operational cost. This is the case for new developments that more often see increasingly challenging environments with H2S, CO2, MIC etc, but also for existing operations that face unplanned shut-downs and repair cost caused by corrosion.
The fully bonded TCP Flowline has significant advantages. The TCP does not corrode, has a smooth bore featuring low pressure drop, is collapse resistant to large water depth and combines pressure and tensile strengths with spoolability. The unique and specific properties of TCP make it a cost effective choice for a variety of different applications, from shallow water flowlines, to flexible high pressure jumper spools and deepwater risers.
A Pragmatic Approach to Corrosion Inhibition of Offshore Pipelines Transporting Produced Hydrocarbons
Authors: Nuttall Robert Horan 
Published: March 2018

Abstract
The application of corrosion inhibitors to mitigate carbon dioxide corrosion in offshore oil and gas pipelines has been practiced for several tens of years. In many instances, the performance of the corrosion inhibitor has achieved the mitigation required and as such, the use of such products has become commonplace. However, the depletion of relatively easily accessible reserves has focused attention on deeper, hotter and frequently more corrosive fields.
The concept that the injection of a corrosion inhibitor demonstrated to achieve a corrosion rate of less than 0.1 mm/y on a representative piece of carbon steel in a static or rotating autoclave is a panacea for aqueous carbon dioxide corrosion is becoming less evident in upstream operations. Considerations regarding the impact of the active inhibitor molecules preferentially partitioning into either the water phase or the liquid hydrocarbon phase and the availability of the inhibitor molecules at top of line locations appear less frequent and the requirement to conduct corrosion inhibitor testing in representative conditions using representative fluids and representative materials is seen as a nuisance rather than a fundamental. Typical test requirements for the assessment of a carbon dioxide corrosion inhibitor, for application in a subsea pipeline, and user expectations are identified and discussed together with some general considerations relating to the production of more aggressive fluids.
The Use of Computational Fluid Dynamics Techniques in 3D Gas Detector Coverage Studies
Authors: Cunningham Shona , Wu Kejia , Green Johnathan , Sivandran Subajan 
Published: March 2018

Abstract
Fire and Gas detectors are used on Oil and Gas facilities to trigger an alarm and potentially initiate automatic safety measures in response to hazardous leaks. The effectiveness of the Fire and Gas system strongly depends on the layout and coverage of the detectors implemented. Prescriptive approaches using industry guidelines (e.g. SHELL DEP 32.30.20.11-Gen or BP GP 30-85) outline a target gas cloud size for detection for enclosed, semi-enclosed, and open areas. The objective of this study was to assess the conservatism inherent in prescriptive approaches in comparison to a Computational Fluid Dynamics (CFD) approach. The employment of a CFD approach to model the dispersion of flammable gas from the potential loss of containment was used to determine whether the prescriptive approaches are overly or under conservative for flammable gas detection. The analysis found for the same assessment parameters such as zone volume and a 90% single detector coverage criterion, geographic coverage (prescriptive approach) requires a significant increase in gas detectors to meet the criterion, an extra 13 detectors. Further to this analysis, the method of using the volume of a sphere to calculate the equivalent diameter was assessed. It was found by modelling the characteristics of a flammable gas release and using the volume of a cone to calculate the equivalent diameter, a more accurate and realistic method was obtained. The study also introduces a 3D frequency plot which is a novel tool for positioning the detectors in the most effective areas irrespective of equivalent diameter. Incorporating the proposed CFD method with the prescriptive approaches raises a number of questions in the area of Fire and Gas Mapping. Whilst the future for this industry may be the use of scenario based coverage, more research is required in order to develop the most effective method.
Yetagun Field Development ERD- Drilling Performance Improvement Case Study
Authors: Atemin Azizul , Jainuddin M. Nor Rafie , Ong Chongyew 
Published: March 2018

Abstract
This paper presented the extended reach well construction results to date of 3 infill wells: YA-01, YA- 05ST1, and YA-12ST1 during the Phase VI development drilling campaign in Yetagun gas field, offshore Myanmar which had delivered top-quartile drilling performance throughout every phase of well delivery.
The significant changes in drilling practices had led to the overall time and cost savings. Systematic approach to benchmarking drilling performance had been incorporated into the efficiency of the operation based on the Key Performance Indicators. Every phase of drilling, evaluating, and completing high angle wells was analyzed. The main technical hurdles contributed to the success of these wells were drilling practices, mud selection and directional control technique. Section-by-section was being described in the paper taking into account the factors that contributed to a top-quartile drilling performance including wellpath design, hydraulic, bottom-hole assembly design, drillstring design and torque and drag reduction methods. A few offset wells were selected and analyzed in order to act as a benchmark of expected performance, but up-front effort was established by proposing the significant key performance indicators (KPIs) which required specialized resources.
Value was generated through performance improvement. Engineering team of the drilling campaign dramatically achieved all the KPIs in the top quartile with zero LTI and successfully secured the reservoir target with the maximum drainage contacts as well as meet the gas volume target. Every aspects of the well design and construction was discussed, challenged and where possible, optimized for further study. The dramatic outcome of the drilling performance always came from the combination of some small incremental improvements and step-change innovations. Statistically analyzing of the KPIs covering the central tendencies and convergence link to the consideration of benchmarks. YA- 05ST1 successfully achieved Best in Class for WCPF and DCPF whereas the DDPTF of all the 3 wells were categorized in Quartile 1 performance. Among the significant changes in drilling practices that contributed to the time saving were the waiving of pilot hole, utilization of casing drive system, installation of tubing isolation Valve-Flapper for completion and implementation of drill to limit approach. Moreover, both the techniques and lesson learnt throughout the campaign were continuously revised, improved and distributed with the aim that the information can be built upon and lead to further improvements in the next extended reach well delivery.
In conclusion, the key differences in drilling practices throughout the campaign were proven to be practicable and in fact play an important role in time saving. Since the ERD has become an ever-more important enabling technique to exploit hydrocarbons nowadays, the replication of the best practices and lesson learnt should be shared for future extensive ERD wells planning and executions.
Axial Rock Berm-Pipeline-Seabed Interactions
Authors: Rodriguez Antonio Borges , Klinkvort Rasmus Tofte , Worren Aleksander 
Published: March 2018

Abstract
Rock berms installed over discrete sections of high temperature, high pressure (HTHP) subsea pipelines may be used to provide axial restraint with a view to minimising the end expansions or to improve the later-life buckle performance. For such applications, the paramount consideration for an efficient rock berm design is the interaction of the rock berms with the pipeline and simultaneously, of the pipeline with the seabed during operation.
This paper re-introduces the mechanism of stress re-distribution in the berm or ‘arching’ occurring during pipeline operation-driven cyclic embedment. The development of cyclic pipeline embedment due to shearing and re-consolidation of the soils around the pipeline is quantified at different times during the pipeline operational life. This is assessed analytically by consideration of the generated pore pressures during episodic shearing and intervening consolidation in a framework described herein.
Further, the results from Finite Element (FE) analyses that correlate the pipeline embedment and the effective rock berm-pipeline contact stress, are combined with predictions of the cyclic pipeline embedment from the analytical framework presented here. This allows to form-find the rock berm cross-profile and screen the rock volume requirements in a reliable manner.
A New Insight on the Geometry of Hydrocarbon Reservoir Bodies Based on Multi-Source Sediment Supply Model from the Deep Water Fields Northwest Sabah Basin
Authors: Khair Abul , Zakaria H. , Ali A. , R. Y. Som , Ali A. , Hady H. , Baharuddin S. , Goodman A. 
Published: March 2018

Abstract
Big attention was directed towards the deepwater fields offshore Sabah area after the discovery of commercial hydrocarbons Sabah in 2002. Hundreds of wells were drilled in up-faulted structural traps within North East trending thrust ridges which some of it are dry. The interpretation of these reservoirs was established as a series of four turbidite fans from Upper Miocene to Pleistocene. Yet, no correlation was found between the same fan in different locations with regards to geometry, thickness and mineral composition. This research studied over 50,000 sqkm of 3D seismic surveys, over 100 wells with different sets of logs including image logs, cores from two wells and bathymetric images. Normal seismic structural interpretation was conducted and seismic attribute of the turbidite fans were analysed. Seabed morphology was examined using bathymetry surveys and 3D seismic. The deepwater sediments type and depositional environment were investigated using core and log data.
The geometry of the oil prone sand reservoir bodies and heterolithic sand bodies within the deepwater fields was found to be of three types: North East trending narrow sand channels and turbiditic channel levees in the Southwest area of deepwater offshore Sabah,North East trending confined turbidite sand bodies bounded by elevated structural ridges south and south east of type 1,Deepwater fan system composed of channel sand, levee turbidites and local and regional MTD to the North East of type 1
This new understanding of the source and sediment supply of the deepwater fields Northwest (NW) Sabah explains the geometry, distribution and lack of correlation within the Miocene sediments. Thus, this study will direct the future exploration in the deepwater reservoirs.
Explanation of Low Reservoir Quality Wells by Re-Understanding the Environmental Deposition of Lower Safa "A" Unit within Khattatba Formation in JG Field, Abu Gharadig Basin, North Western Desert, Egypt, Case Study
Authors: Shafik Sherif A. , Saudi Ahmed T. 
Published: March 2018

Abstract
The JG field is an oil & gas producing field located in Abu Gharadig Basin. The Lower Safa Member is the main reservoir representing the lower member of Khattatba Formation and it is subdivided into two reservoir units "A and C" separated by non-reservoir unit "B". During the next development phase of Lower Safa "A" by it is necessary to avoid drilling dry holes or wells with low reservoir quality, and so, it was essential to understand the reason behind drilling 6 wells with low reservoir quality and the re-evaluation of the available data used to re-identify geometry was of high importance.
Lower Safa "A" had been cored in three wells with total length of about 46m. The sedimentological description of these cores highlighted several features pointing to a tidal dominated estuarine environment of deposition as abundance of carbonaceous material, channel erosion surfaces and paleosols, rapid changes of lateral and vertical facies, and mix of terrestrial and marine micro fossils.
The previous development strategy of JG field was to drill wells on crestal position along the main bounding fault which extended about 8 km in the East-West direction, assuming extension of estuarine system in the North-South direction.
Based on this study after re-evaluating available data estuarine system subdivisions clearly reflected in Lower Safa "A" unit and delineated from log characters and core features, it was proven that this unit was deposited in tidal dominated estuarine environment but extended in the East-West direction parallel to the fault, and the wells which encountered low reservoir quality were drilled in the low energy central zone and marches of estuary.
According to this study, it is recommended while developing Lower Safa "A" unit to drill within eastern and western areas i.e. the inner and outer parts of the estuarine system, which are characterized by good reservoir quality and to avoid drilling in the central part where the reservoir is low quality.
Stratigraphic Reservoir Characterisation Using Simultaneous Seismic Inversion in Bongkot Field, Gulf of Thailand
Authors: Promrak W. , Fongsuk P. , Uttareun R. , Sa-Nguanphon S. , Tubsrinuan N. , Matangkapong K. , Iamboon J. , Srisuriyon K. , Pabchanda S. , Sognnes H. I. 
Published: March 2018

Abstract
Combination and stratigraphic traps may contribute with significant gas reserves in Bongkot Field, Gulf of Thailand. However, such stratigraphic play cannot be easily defined as conventional seismic interpretation provides mainly structural information. To identify stratigraphic prospects in this area, a seismic pre-stack inversion and reservoir characterization study was carried out. The input dataset consisted of 365 km2 of 3D seismic, six wells, and interpreted time horizons. Following seismic pre-conditioning and rock physics analysis, wavelet extraction and well-ties were performed for each individual well, considering every input angle stack. Constrained by input time horizons, low frequency models were built based on well log and seismic stacking velocity. Inversion parameters were tested; subsequently, final inversion results were subjected to Bayesian classification to obtain a litho-facies volume. In addition, multi-linear regression was used to derive elastic-petrophysical relationships, to generate petrophysical property volumes. The final results included inverted elastic properties, classified litho-facies, computed effective porosity and Vshale volumes. By analyzing these results, several channel and deltaic/sand lobe features could be observed throughout the study area. Connected sand-filled channels with high porosity were mainly observed in the shallow section, as sand distribution appeared sparser and more isolated with increasing depth. Also, the predicted reservoirs in the deeper section were mostly filled with gas, while shallower sand bodies were mostly filled with brine. This observation implied that the high net-to-gross reservoir distribution in the shallow section can be a key factor that hinders effective trapping of hydrocarbons at this level. Since reservoir distribution plays a key role in hydrocarbon trapping mechanism, upside stratigraphic potential was identified from isolated gas-filled channels, mapped from seismic inversion products, to implement a more successful field development strategy in a mature field.
Integrated Real-Time Operation Centre: A Complete Solution towards Effective & Efficient Drilling Operation
Authors: Iskandar Farah Farhana , Abiddin Mohamad Sukor Zainal , Nazzeri Norbaiti , Aziz Amir Abd , Atemin Azizul 
Published: March 2018

AbstractBack then, communication between rig-site and town was a huge challenge, even in Malaysia where the first offshore drilling started in the 1960s. During those days, offshore rigs and platform seems isolated and communication was only done via phone call and fax machine which has resulted in very delayed information, and at some point, causes difficult decision making.However, as to date, real-time communication is no longer sounds alien to many people. In fact, it has become common terms that has been widely used in many other industries. With the emergence of sophisticated drilling software and a standard communication protocol, a real-time operation centre is typically occupied with multiple software with different function and capabilities to aid the drilling operation.Having an integrated real-time operation centre equipped with high technology software and coupled with subject matter experts in one room has often leads to efficiency and consistency while drilling especially when encountering complex drilling environment. This set-up has enable high level of collaboration starting from planning phase, drilling execution and post job phase, knowing that all domain experts' works from a single data source, where all decisions & modifications made are agreed upon.Pacing in this digital era, Oil and Gas operators and service providers now aims to embark on digital transformation to elevate their ability and agility to thrive in digital environment as an effort to be ahead of competitors. Having lots of data coming from various sources; leads this industry in this big data world. As technology is advancing at the speed of sound, the industry has now starting to talk about drilling automation, machine learning, artificial intelligence and big data analytics. To be able to do this, the people and the data itself must be ready for it, digitally and technically.This paper will talk about where we are now in regards with digitalization, explaining in detail how an integrated real time centre solution being deployed in operator's office together with the services provided and how we are preparing ourselves for digitalization to catch up with the fast pace of digitalization era.
Managing Big Data of Offshore Project Lifecycle through Investment Information System
Authors: Panggabean Yan Bastian 
Published: March 2018

Abstract
Big Data is popular term in some recent years and become leverage for business trend around the world. Absolutely 100% agree, all the business uses Information Technology for expanding their business and even survive on the market. IT is not supporting business anymore, many start-up company build their business with IT platform as its core competencies. Oil & Gas Business has been transform and progressively using high tech capacity data. It starts with paper works to simple excel and now it is go online.
Since Pertamina seeks to grow, then it does invest in all the chains. Aggressive business growth according to the vision and mission as well as the Company's Long-Term Plan requires comprehensive and precise decision-making. Their errors can lead to miss opportunity that is in sight may be taken by competitors.
Investment Information System is comprehensive end to end application that covers end to end investment process. It starts with how Pertamina propose the project, how to monitor & evaluate execution of the project and evaluate post mortem of the projects. Portfolio module covers all the projects inside the funnel.
Web based application can support management for evaluate all the projects and give the best perspective of company. More over it can support management and shareholder for take good decision making. Back end of this application is also integrated with SAP and support project monitoring for physical and financial for each project and create earned value management for oil & gas project prediction.
Examining the Biosynthesis and Xenoantigenicity of Class II Swine Leukocyte Antigen Proteins
Authors: Ladowski Joseph M. , Martens Gregory R. , Reyes Luz M. , Wang Zheng-Yu , Eckhoff Devin E. , Hauptfeld-Dolejsek Vera , Tector Matt , Tector A. Joseph 
Published: March 2018

Abstract
Genetically engineered pig organs could provide transplants to all patients with end-stage organ failure, but Ab-mediated rejection remains an issue. This study examines the class II swine leukocyte Ag (SLA) as a target of epitope-restricted Ab binding. Transfection of individual α- and β-chains into human embryonic kidney cells resulted in both traditional and hybrid class II SLA molecules. Sera from individuals on the solid organ transplant waiting list were tested for Ab binding and cytotoxicity to this panel of class II SLA single-Ag cells. A series of elution studies from an SLA-DQ cell line were performed. Our results indicate that human sera contain Abs specific for and cytotoxic against class II SLA. Our elution studies revealed that sera bind the SLA-DQ molecule in an epitope-restricted pattern. Site-specific mutation of one of these epitopes resulted in statistically decreased Ab binding. Humans possess preformed, specific, and cytotoxic Abs to class II SLA that bind in an epitope-restricted fashion. Site-specific epitope mutagenesis may decrease the Ab binding of highly sensitized individuals to pig cells.