bluuebunny/crossref_metadata_2025_split huggingface dataset:
Spatial Distribution of AlO in a High-mass Protostar Candidate Orion Source I
Authors: Tachibana Shogo , Kamizuka Takafumi , Hirota Tomoya , Sakai Nami , Oya Yoko , Takigawa Aki , Yamamoto Satoshi 
Published: April 2019

Abstract
High-temperature molecular gas containing metallic elements is potentially a good probe to trace the kinematics/dynamics of circumstellar disks, and its presence in circumstellar disks around young stellar objects (YSOs) may also give some insights into formation processes of high-temperature meteoritic components formed in the Sun’s protoplanetary disk. The Orion Kleimann–Low (KL) region is the most famous and nearest massive star formation site, and has been extensively studied since the 1970s. The KL region harbors a candidate high-mass YSO, Source I, which has a hot circumstellar rotating gas disk emanating a magnetocentrifugal wind of SiO. In this study, we report spatially resolved distributions of aluminum monoxide (AlO) emission lines at 497 and 650 GHz in the rotating outflow of Orion Source I based on subarcsecond observations obtained by the Atacama Large Millimeter/Submillimeter Array for the first time in star-forming regions. These AlO emissions are detected only at the base of the outflow as the high excitation line of H2O in spite of their low excitation temperatures. The limited distribution of AlO to the launching point of the outflow indicates that AlO is not in the gas phase in the outer part of the outflow lobes away from the disk surface, which could be attributed to recondensation of AlO as dust due to its refractory nature.
Digitalization Goes Subsea
Authors: Kristiansen Karstein Berge 
Published: April 2019

This paper discusses the requirements for a "next-generation" subsea control system and provides a description of the proposed setup/architecture. Requirements for "next-generation" subsea control focuses on requirements for "digitalization" and Industry 4.0 capabilities. Existing subsea control systems today are intended for and used to control hydraulic valves in subsea production setups. The proposed "next-generation" subsea control system is specified, designed and built for an all-electric process control setup, with requirements for extensive usage of digitalization toolboxes.
Primary requirements for the "next-generation" subsea control system would be deterministic behavior and latency in the millisecond range for the control of operations part/signals/objects, while at the same time generating large amounts of high quality and highly accurate time-stamped condition monitoring data to be used in the digitalization setup. The proposed concept integrates subsea control and historian systems directly into the existing topsides control and historian systems. Implementation of an anti-surge control system will be used as an example to illustrate the concept for control of operations, and the use of artificial intelligence (AI) and historical stored data would be used as examples for topside digitalization techniques used on subsea installed equipment.
Removing boundaries between topsides and subsea automation as suggested in this paper provides options to use already available toolboxes for digitalization of topsides assets on similar subsea components. The proposed open architecture control system would also easily interface directly to any cloud-based solution with standard interfaces or well-defined application program interfaces (APIs).
Economic benefits of implementing an open-architecture control system would include CAPEX and OPEX reductions, while at the same time creating a "future-proof" system that allows for the addition of digitalization options. Subsea data would be delivered and stored with higher quality, providing operators with the option to look retrospectively and evaluate historian data based on knowledge to be obtained in the future.
Moreover, having one integrated control system provides better protection against cyberthreats, as it eliminates the requirement for several systems, which need to be updated and maintained during the lifetime of the installation.
Various predictions and thoughts about the future of subsea controls beyond the proposed "next-generation" subsea control system will also be included in this paper.
Libra Subsea Achievements and Future Challenges
Authors: de Melo Ricardo Toneto , dos Santos Tadeu Milão , Valença Cláudio J. G. M. , Buk Jr Leonidio , Pereira Rafael Merenda , Passarelli Fabio Menezes , Hoelz Fabio Rocha 
Published: April 2019

Abstract
The paper uses a case study approach to present the challenges to develop a large and thick oil carbonate reservoir, full of opportunities but also of uncertainties. Additionally, Libra block development is under a Production Sharing Contract that was awarded to a Consortium where Petrobras is the operator in partnership with Shell, Total, CNOOC Limited and CNPC. This paper will present the main subsea technological achievements made during the execution of the Libra Extended Well Test (EWT) Project so far and also future technologies that will contribute to overcome the full field development challenges.
Validation and Extension of Soil Response Framework for Fatigue Analysis of Offshore Wells and Piles
Authors: Zakeri Arash , Sturm Hendrik , Jeanjean Philippe 
Published: April 2019

Abstract
A soil response framework for use in fatigue assessment of offshore wells and piles is presented. The framework covers clay and sand soil types. It was developed through comprehensive series of physical testing and numerical simulations. It hinges on determination of the unload-reload secant stiffness response of soils degraded under cyclic fatigue loading and reaching a steady-state condition. The framework comprises two calibrated approaches: spring-only and spring-dashpot. The latter is more appropriate when dynamic response of a structure needs to be more accurately determined through for time-domain analysis. Efficacy and validation of the framework are demonstrated through three (3) field monitoring programs involving offshore wells installed in ground conditions ranging from soft clays typically encountered in deepwater to layered sands and clays in shallow waters. Further validation is provided by presenting results from an extensive laboratory testing program involving nine (9) soil samples taken from various geographical locations against the key relationships of the framework. The laboratory tests were conducted in a novel apparatus developed specifically for obtaining soil resistance–displacement relationship for input to fatigue analysis.
Degradable Materials for Multi-Stage Stimulation
Authors: Tu Huilin , Aviles Isaac , Dardis Michael 
Published: April 2019

Abstract
Degradable plug-and-perf systems made of degradable alloys and polymers are being used extensively for multi-stage stimulation (MSS). This paper reviews the degradable materials available in the market, including degradable magnesium and aluminum alloys and degradable plastics and elastomers, compares their degradation mechanisms, and discusses the factors affecting their degradation behavior.
A series of degradable aluminum alloys with good mechanical properties, and a tunable range of degradation rates were developed in Schlumberger for MSS applications. Key parameters, such as material formulation, temperature, and hydrostatic pressure are used to control the degradation behavior of these degradable alloys. Predictive models are established to predict the degradation time window under a broad range of downhole conditions for improved completions job planning. Comprehensive testing has been done to verify the performance of the materials in the simulated downhole conditions. In addition, field operation results are available to validate the performance of the degradable fracturing plugs made of these degradable alloys.
Degradable materials enable degradable fracturing plug applications and eliminate the need for mechanical intervention. They receive more and more attention in the MSS market. We will see more rapid growth of their applications in the coming years.
Subsea Digitalization: From the Virtual World into the Real World—Using Augmented Reality in Offshore Operations
Authors: Parente Manuel , Stevens Mark , Ferreira Joao , Simao Rafael , Dionisio Mariana 
Published: April 2019

Abstract
Recent advances have made it possible to include augmented reality (AR) technology in the subsea intervention process to overcome problems commonly encountered during remotely operated vehicle (ROV) operations in deep water. Newly developed AR technology uses a state-of-the-art 3D engine to accurately model subsea assets and a geographic information system (GIS) to precisely determine the relative location of assets in the field, creating a virtual 3D visualization of the subsea facilities.
ROV operations are enhanced by superimposing the virtual environment onto the live feed of the ROV's pilot camera. Merging real-time camera images with AR and other data streams augments visibility, improves safety, increases efficiency, and reduces overall costs.
The use of AR technology for subsea operations is enabled by advanced software to digitalize subsea assets, cloud computing to run applications and store data, satellite communications to link offshore operations to onshore decision-makers, command centers that support remote operations, and simulation techniques for pre-job planning and ROV pilot training.
Since testing began in 2015, the AR-enhanced process has been applied in deepwater fields in the Gulf of Mexico and North Sea.
Looking ahead, it is expected that the experience using AR and structured data sets for improved subsea activity will lead to fully autonomous operations controlled by artificial intelligence to achieve project objectives with lower risk and greater efficiency.
Libra@35 - Bringing the Project Break Even to US$ 35/bbl
Authors: Coelho Junior Osmond , Costa Ana Luiza Silva , Bisinoto Luísa Gontijo , Guimarães Mariane Duarte 
Published: April 2019

Abstract
Having a resilient break-even price is essential for deep-water development projects due to all the technical uncertainties inherent to the O&G business and, because of the oil price volatility, especially in recent times. To cope with this permanent threat, the Libra Consortium envisaged, structured and implemented a consortium corporate program called Libra@35. The programs’ main objective is to reduce the projects break-even prices to US$ 35/bbl, by improving the recovery factor and /or reducing costs. This paper describes the Libra@35 methodology and procedures, explaining how the program has helped Libra optimize its projects on a continuous basis through a structured and rigorous methodology. Additionally, it presents the beneficial results and impacts achieved to date. To finalize, the paper discloses the Consortium's future objectives for this successful Program and how it is structured to assist in shaping Libra's projects of tomorrow.
The Evolution of Asset Management: Harnessing Digitalization and Data Analytics
Authors: Nixon John , Pena Emil 
Published: April 2019

Abstract
Underwriting the costly insurance of complex oil and gas projects — with every one unique — requires careful risk assessment of numerous factors via long-standing criteria. But two risk-mitigation factors not currently considered are (a) the increased operational visibility; and (b) predictive maintenance made possible by today’s advanced asset management technologies. Those technologies include the digital twin, data analytics, and secure Internet of Things (IoT) connectivity. With these technologies, E&P operators can now better quantify the probabilities of untoward events and mitigate their risks, improving their HSE posture, and potentially reducing the cost of their insurance premiums. In fact, one E&P OEM using digitalization to better quantify risks related to project errors and omissions led to a $750,000 premium reduction from its insurer, one of the world’s largest insurance companies.
Automatic Slip Status and Stand Detection in Real-Time Drilling
Authors: Zhao Jie , Chambon Sylvain , Shen Yuelin , Venkatakrishnan Sai , Hamzah Mohammad Khairi 
Published: April 2019

Abstract
The drilling process can be broken down into various activities from top-level activities (e.g., drilling and tripping) to lower-level activities (e.g., in-slip, out-of-slip, making connection, and circulation). The detection of the fundamental drilling unit, a stand, is necessary and essential for recognizing and inferring drilling activities. A new method is proposed to detect slip status, pipe change, and drilling/tripping stands based on real-time streaming data.
The slip status is a critical element because it indicates a connection is made before drilling or tripping a stand. The proposed method is designed to infer the slip status with hookload, standpipe pressure (SPPA), and surface torque (STOR) sensor data. Specifically, the logic using hookload includes two criteria, a hookload standard deviation criterion and a dynamic hookload threshold criterion. This allows addressing the limitations of prior methods at shallow depth and using a manual threshold, which prevents the full automation of slip detection. In addition, the slip status can be confirmed or corrected with a logic using a combination of SPPA and STOR data. Then, a check is performed on whether a stand is added or removed during in-slip period. If needed, the stand detection can also be run to detect where a stand begins and ends.
The method has been extensively tested and validated on many land and deepwater wells with drilling/tripping operations. Without human intervention, the dynamic hookload threshold can be determined automatically and adaptively after one or two drilling or tripping stands. Moreover, the hookload standard deviation criterion works well to detect the change of slip status at shallow depth. It is shown that high accuracy of detection can be achieved when the streaming data have a proper range of sampling rate.
The new method addresses two limitations of the existing methods: (1) it automatically determines the dynamic hookload thresholds and eliminates the need of setting up the hookload threshold manually, and (2) it improves the accuracy of slip status and stand detection at shallow depth. This innovative work enables the automation of the slip status and stand detection process in batch runs or in real time without operator input.
Aasta Hansteen Hull-Topsides Dry Transport and Dual Barge Mating Operations
Authors: Vernes Niels , Donia Stephan , van Ginkel Anthony , de Jonge Jan , Selstad Henning , Krokeide Bjørn 
Published: April 2019

Abstract
The Aasta Hansteen Field development in 1300m water depth is the deepest field on the Norwegian Continental Shelf (NCS) and is developed using a Truss Spar FPSO. The platform was made ready with platform mooring chains after which Topsides were installed by float-over method in a fjord before the complete platform was being towed to the field vertically in summer of 2018.
The Topsides of 25,300 t and the hull of 46,000 t were both constructed by Hyundai Heavy Industries in Korea and transported to Norway on Boskalis heavy transport vessels. Due to its size and weight, the Truss Spar FPSO had to be transported by the largest heavy transport vessel in the world, BOKA Vanguard.
Topsides mating onto the Spar hull was carried out by Boskalis in a Norwegian fjord by a dual barge float-over operation. The Topsides was first transferred from HTV White Marlin to two S-class vessels, then from the two S-Class vessels to the Spar hull. Load transfer was obtained by simultaneous ballasting of the dual barge hulls and de-ballasting of the Spar hull.
The paper will focus on the engineering and design process of the dual barge float-over operation and the subsequent translation to a real time simulation model followed by the actual dual barge float-over and mating operation. The information and discussion provided in the paper can be used for planning and design of other large floater applications.
There were several firsts in the execution of this scope ranging from transporting the world's largest Spar platform on the world's largest heavy transport vessel to executing a dual barge float-over and mating operation using two heavy transport vessels. The use of real time simulation as validation and training tool has been a highlight of this scope.
How Digital Engineering and Cross-Industry Knowledge Transfer is Reducing Project Execution Risks in Oil and Gas
Authors: Evans Simon Jonathan 
Published: April 2019

Abstract
Technology has transformed the energy industry over the last 60 years. It has made processes more efficient, employees more productive and crucially, it has improved the safety of both workers and facilities.
In a mature industry, such as oil and gas, operators and owners are faced with the challenge of safely and efficiently managing their ageing plant and assets. This challenge is compounded by poor historic records and information, and the potential loss of knowledge as the current workforce retires. Coupled with the increasing requirement for high levels of design assurance and confidence in solutions, and the constant pressure to deliver value, faster and cheaper; companies are constantly looking at the latest technological advances, and to other industry sectors, for possible solutions.
This paper explores, through case studies, how the latest digital modelling and visualisation techniques are being innovatively deployed to enhance design, delivery and operations in the oil and gas sector. SNC-Lavalin have been uniquely deploying these technologies into the nuclear sector, where access time is highly-limited due to nuclear radiation. This learning has been brought to the oil and gas sector, and is an exemplar of cross-industry working and knowledge transfer.
Innovative Field Development Scheme Based on Saipem's ETH PiP and Relevant Subsea Power Feeding System
Authors: Arcangeletti Giorgio , Bacati Fabrice , Radicioni Alessandro , Breuskin Bruno , Jacquet Sylvie , D'Amico Amerigo , La Sorda Enrico 
Published: April 2019

The overall complexity of future subsea transportation systems is expected to increase due to new challenges posed by the novel field development schemes mainly dictated by the combination of tie-back distance and water depth with the target to make the field exploitation profitable, safe and reliable in the current Oil & Gas price scenario.
It is becoming more frequent to face field development projects with long step-out distances associated with considerable water depth and/or low wellhead product temperature. During normal or transient conditions, these factors lead to flow assurance issues that can be avoided by deploying new cost effective technologies such as insulated and heated pipeline systems combined with subsea processing elements like Subsea Boosting.
A dedicated team has performed different studies and internal development activities on this subject based on expected needs of Operators considering their real future subsea fields under investigation.
New development schemes and operating philosophies have been identified together with the relevant technologies that, in some cases are under development, jointly with major suppliers.
The most efficient production schemes have been selected and the conceptual design of its relevant technological building blocks has been performed. These building blocks have been further investigated in terms of market ownership & readiness with technology suppliers and O&G operators. The main enabling technologies involved for the oil fields are Subsea Active Heating/Insulation such as proprietary Electrically Trace-Heated Pipe In Pipe (ETH PIP), Subsea Boosting, Subsea Power Distribution and the All Electric Control System.
ETH PiP, combined with Subsea Power Distribution (Subsea Switchgear, Subsea Transformers, Subsea VSD, etc.) and the All Electric Control System, can significantly support overall investment cost reduction and facilitate the tie-back development to an existing facility by ensuring the flexibility of operations and suitability with a wide range of project design basis.
This paper outlines the selected development schemes for the long tieback oil fields and describes the main technological building blocks. It also outlines the actions initiated to provide a global solution for these types of fields and mainly to industrialize the second generation of the ETH PIP solution for longer tie-backs.
It discusses the main components of the ETH PIP solution and the relevant Subsea Power Feeding System that provide and distribute power also to the other subsea utilities like boosting pumps and All Electric Control.
Well Intervention in Shallow Waters with Dynamically Positioned Vessels: A Study Case for Southeastern Brazil
Authors: Pestana Rafael Guimarães , Rocha Vinicius Sales , Braga Daniel Rocha , Oliveira Eric Ribeiro 
Published: April 2019

Abstract
This paper presents the technical analysis, simulation and work carried out in planning and executing an open sea workover riser operation for decommissioning a well from a dynamically positioned (DP) vessel in shallow waters, on southeastern Brazil. The main challenge in using a DP rig in this situation is the risk of thruster blackout, resuling in a driftoff scenario. In shallow waters, the system safe allowable vessel driftoff is usually strict, resulting in tight Red Alarm Offsets or even making the operation unfeasible. Real time monitoring and analysis may be used to obtain dynamic optimized Red Alarm Offsets during an operation, but simulations must be performed for operational planning. Statistical treatment of a database of measured and simulated metocean conditions led to reduced environmental loadcases than usually considered in standard industry analysis, while retaining an acceptable safety level. Modification of the riser control system also resulted in reduced Emergency Disconnection Sequence (EDS) time, resulting in broader Red Alarm Offset results. The methodology herein presented may be refined even further, in order to make possible the use of DP vessels in even shallower water scenarios.
Design, Testing, and Operation of a Completion Deflector Running and Test Tool for Efficient Multilateral Completions
Authors: Stokes Matthew Bradley , Lajesic Borisa , Ramirez Christian Alexander , Dupler Lester Barett 
Published: April 2019

Abstract
Trip optimization is essential in multilateral well construction, especially for extended-reach drilling (ERD) wells. This paper describes the design, testing, and operation of a completion deflector running and test tool (RTT) that was recently used during completion of one of the industry's deepest extended-reach multilateral wells. The RTT allows for running and pressure testing of a completion deflector and lower completion components in a single trip, thus saving at least one trip, and up to three trips.
The challenge was to develop the capability to run a completion deflector with an existing pressure test tool. This was accomplished by converting the pressure test tool into a running tool. The new pressure actuated mechanism built into the tool releases the completion deflector automatically after a successful pressure test. A secondary release mechanism was also incorporated for contingency options. Extensive engineering qualification tests validated the new features to be highly reliable.