bluuebunny/crossref_metadata_2025_split huggingface dataset:
Digitalisation – The Next Frontier for the Offshore Industry
Authors: Dekker Martijn , Thakkar Anosh 
Published: April 2018

Abstract
The offshore industry has always been at the vanguard of technical innovation and this is not about to change. The next wave of technology will not come, however, from new ways to bend the physical world to our will with steel and human power but from bits and bytes through digitalisation.
Digitalisation is not new to our industry. Now the technology is cheaper and faster and the amount of data and level of connectivity are increasing exponentially, the application of digital technologies can deliver at an affordable cost. The energy industry is emerging from a lower-price environment in better shape and with more resilience and an increased focus on capital efficiency, cost performance and safety. The industry is also ready for a digital transformation that offers a big, if not the biggest yet, opportunity to improve efficiency in our existing operations even further.
This transformative potential has been recognized for some years. What has been missing is a comprehensive approach for applying digital technologies successfully at scale in the oil and gas industry. This reflects one of the significant differences with previous waves of innovation: most of the benefit for existing businesses will come from replication and rapid improvement cycles of across many assets and projects. In addition, digitalisation also opens up the opportunity for new business models that could change the entire industry structure.
This paper explores an approach to digitalisation that draws on successful use cases that have already realized significant value in Shell's operations. It identifies the underlying principles of the digitalisation strategy, including data strategy, approach to insourcing versus outsourcing and methodology of scaling up. The required success factors that underpin digitalisation are also explored: capability building for both people and IT/data systems; how to organize the digital deployment; and the required leadership, culture and way of working attributes. Practical examples and insights from Shell's digitalisation journey will be provided.
E-Line Intervention Enables Operator to Design, Manufacture A New Customized Bit to Mill Out Isolation Valve in Record Time and Enable Early Production from Well
Authors: Tyagi Chirag , Singh Virendra , Nayak Jyoti Prakash 
Published: April 2018

AbstractA well in the Panna-Mukta-Tapti Joint Venture (PMT JV) was completed using an isolation valve as the method of isolating the reservoir whilst running the completion into the well. Mechanical failure to open the valve was not anticipated as the isolation valve had a successful history in the JV with no failures in the last 10 years. However, in this well, the isolation valve failed to open. After spending multiple days attempting to open the valve and diagnosing the cause of the failure, it was concluded that the isolation valve was mechanically stuck.Further evaluatios of solutions incorporating Coil tubing (CT) and e-line interventions concluded that standard milling operations would pose additional challenges for the well due to the design of the completion below the isolation valve. Subsequently, a unique, star shaped milling bit was designed and manufactured to enable milling of the isolation which was smaller than 2.56" SSD and landing nipple present below the isolation valve. This was required to ensure future access for interventions through the SSD and landing nipples is not compromised and milling out the coupon from the flapper isolation valve does not get stuck in the smaller ID completion profile below it.The newly designed bit enabled milling and subsequently expanding that hole to the desired OD of 2.7" which would allow for future interventions. E-line milling was selected due to limitations in control with CT for debris generated. The total time from identification of the problem to designing, manufacturing, testing the new bit, transporting it to India and executing the solution was 45 days. The operation itself was carried out within 45 hours vs 120 hours projected with CT, leading to a significant cost saving, equivalent of 3 times daily spread rate for the rig. This unique methodology also enabled early onset of production, avoiding a delay of approxmately three month.This was the first time this new mill bit was applied and the first time that this isolation valve had been milled out using E-line. Existing, standard bit designs were not sufficient to accomplish this solution nor were conventional approaches satisfactory in today's economic climate. This paper will present the significant benefits accomplished from the utilization of the robotic, electric-line (e-line) intervention to mill out a malfunctioning isolation valve versus the use of coiled tubing (CT).In addition, it will use the flexibility and control features of e-line based, intervention technology towards addressing short lead time and design modification required to meet dynamic well challenges.
Malikai TLP Transport and Installation
Authors: Huffelen Rolf van , Bruin Ruben de , Wassenaar Walter 
Published: April 2018

Heerema Marine Contractors (HMC) in combination with IEV Malaysia was contracted by SSPC to transport and install the Malikai TLP offshore Sabah. Malikai is Shell's second deep-water project in Malaysia. It features the country's first tension leg platform, a floating oil production facility moored to the seabed in 500 meters water depth.
This paper discusses the installation contractor's experience and lessons learned in executing the tow and installation campaign.
Operational and Safety Improvements of Applying Real-Time Analytics in a Drilling Contractor RTOC
Authors: Madaleno A. L. F. , Neto S. L. S. , dos Santos L. A. , de Oliveira C. A. L. 
Published: April 2018

This paper will present how QGOG Constellation, an ultradeepwater drilling contractor, is taking advantage of its Real-Time Operation Center (RTOC) to leverage process safety and performance in six critical areas. The company applies real-time analytics to automatically identify and alert RTOC engineers of abnormal situations.
Data analysis is supported by a data collection mechanism, communicating with a real-time analytics IoT platform. It allows the integration of data generated from drilling packages and BOP, as well as basic environmental information present on units’ drilling data servers.
Operation modes are automatically detected in real time and used as primary information. Algorithms developed by the RTOC team search and raise an alert for any abnormal situation. These tools are organized in six main dimensions: well control, well barrier assessment, equipment safety operational window, drilling problems prediction, process sensor integrity, and BOP monitoring,
A flexible dashboard platform enables RTOC engineers to develop algorithms and graphics that are customized to improve monitoring accuracy and fulfill operational needs. The dashboards that come out of this development target critical operations and allow much more data to be taken into consideration, resulting in a more structured decision-making process. Examples of successfully implemented real-time logics include a comparison of BOP-selected EDS and auto-shear status with the operation mode, comparison of combined loads on a drillstring with the tubular safety envelope, an automated trip sheet which compares the theoretical displacement of a tubular with the trip tank variation, fingerprinting of pumps-off scenarios, and automatic assessment of pressure and volume. These logics turn data into useful information and detect abnormal situations faster, taking into account much more data than a drilling crew could.
Alarms are associated with the scenarios and alert RTOC engineers of any abnormality. After verification, the RTOC communicates the rig and further actions depend on type and severity of the recognized situation.
The RTOC role within a drilling contractor is a new factor. This paper also introduces a methodology where a platform can integrate and synchronize data coming from different data sources, including third party companies and the well operator.
An Electro-Mechanical Actuator with Hydrostatic Drive for Subsea Trees to Reduce CAPEX and OPEX with Higher Reliability and Safety Levels
Authors: Orth Alexandre , Hendrix Gottfried 
Published: April 2018

Abstract
Although subsea production is already a mature technology, a high engineering effort is currently needed to "industrialize" the applied systems for cost optimization. The drive system applied for the actuation of subsea valves in trees and manifolds reflects exactly this challenge: how to reduce manufacturing costs by increasing safety and availability?
The first approach was based on hydraulic cylinders, which were operated by electric-piloted hydraulic subsea valves with topside Hydraulic Power Units. This system is very robust, but leads to very cost-intensive umbilicals to provide the needed fluid power and prevent environmental damages due to leakage of hydraulic fluid into the sea.
To reduce environmental pollution, complexity and costs; all-electric solutions were developed. However, hydraulic actuators continue to be used because of important benefits such as high power-density, lower friction and integration of a mechanical override.
Is it possible to create a hybrid solution which can combine the benefits of both technologies? In other industries, this dilemma was solved by integrating the hydraulic cylinder into a self-contained electro-hydraulic servo axis, which applies pumps driven by variable-speed motors for accurate positioning.
This paper presents the results of the development of an electro-mechanical actuator with hydrostatic drive to operate gate valves of subsea trees and manifolds.
The main achievements, demonstrated by simulation and testing using a 2″ valve actuator at 3,000 m water depth, are: Cost-effective modular design using industrial componentsEnvironmentally friendly set upLower power consumptionHigh availability and condition monitoringFunctional safety able to achieve SIL 3Integration of mechanical overrideAdvanced Electric Controls with Industry 4.0 connectivity
This system is an important step to close the technology gap to accomplish the all-subsea factory. Especially, it can be applied in cases where the hydraulic actuators are still preferred instead of all-electric actuators.
2014-2017 Anomalous Loop Current Activity
Authors: Sharma Neha , Storie Jill , Ivanov Leonid , Magnell Bruce , Leber Michael , Gustafson Drew , Zimmerle Heather 
Published: April 2018

Abstract
The years 2014-2017 marked a period of anomalous and extreme Loop Current (LC) activity that resulted in significant impact on offshore operations for the first 18 months, followed by a 4- to 6-month period of more typical behavior and then 15 months of uncharacteristic inactivity. The objectives of this study are to (i) provide a detailed description of the kinematic structure of the Loop Current Eddies (LCEs) observed during this time frame; (ii) determine the vertical extent of each eddy and the effect of eddy activity on near-bottom currents, and (iii) establish a relationship (if any) between eddy activity and intensity of inertial oscillations within the water column. We present data collected from ADCPs at several locations in the northern Gulf of Mexico along with an extensive network of drifting buoys in correlation with daily frontal analyses and a comparison with historical events. To estimate the intensity of inertial oscillation and its variability in time, we computed rotary current spectra for periods characterized by high and low eddy activity. While circulation patterns during early 2014 were fairly typical, an apparent sudden increase in energy marked the beginning of hyperactivity in late June. Eddies Lazarus, Michael, Nautilus, and Olympus spun off the LC, each eddy experiencing multiple reconnections with the LC before its final separation in addition to amplified intensities (over 3 knots, max 4.5+ knots). December 2015 marked the beginning of the second phase. Another eddy (Poseidon) separated from the LC in April 2016; however, the winding down process of the LC circulation was already in effect. Poseidon did not exhibit a significant northward migration and the LC itself remained far south. In the central Gulf, the passage of Poseidon was followed by the passage of a subsurface cyclonic eddy, without a significant surface expression, propagating westward. For the next 18 months, the LC remained extremely inactive. While currents in the near-bottom layer were not directly correlated with the flows in the upper part of the water column during the period of the high eddy activity, the later period was characterized by more energetic near-bottom flows, suggesting LCE’s may stimulate generation of topographic Rossby waves that cause strong near-bottom intensities. No significant correlation between the presence of LCE’s and intensity of inertial oscillations was found. Results of recent near-surface and water column current observations are presented in the paper.
Sustainable Offshore Wind Energy: Faster and Larger at Lower Cost and Less Environmental Impact
Authors: Dirks W. G , Kappen J. M. J. , Scheltens R. D. , Winkes J. , Wochner M. S. 
Published: April 2018

Abstract

Objective
"The offshore wind industry is in the process of becoming an advanced and mature industry in North Western Europe, with the costs of the energy produced by offshore wind farms rapidly decreasing. The cost of offshore wind energy, however, is still higher than the cost of energy from fossil sources. The success of offshore wind, as a significant contributor to the global energy supply in the future, will depend on future energy prices, enabling legislation to further develop offshore wind and technologies that reduce CAPEX and OPEX costs. This paper will present an overview of technologies that are being developed by Van Oord and other innovative companies in the offshore wind supply chain, notably AdBm from the USA and Fistuca from the Netherlands.
The presented technology developments aim at lowering the costs of foundations for offshore wind turbines, which is a significant part of the total CAPEX cost. The costs of foundations can be reduced by: 1) optimizing the design; this means less weight, easier to install and with the lowest possible maintenance costs over its lifetime, 2) developing installation vessels and equipment that enable faster installation with limited dependency on sea state. At the same time, wind turbine manufacturers are developing larger offshore wind turbines and legislators are instituting more limitations, for example on the emissions of underwater noise. These developments create additional challenges for upscaling the installation capacity and performance of vessels and pile driving equipment and the development of technology that reduces or abates underwater noise.
This paper presents an overview of new technologies related to foundation design, installation vessels, pile driving technology and noise mitigation systems and the challenges to get those new technologies ready for implementation as fast as possible.
These new technologies will become relevant for upcoming sector developments, e.g. in North America and Asia, with specific local challenges like difficult soil conditions, restricted installation periods due to weather constraints, or noise mitigation to prevent damage of sensitive marine life.
Malikai TLP: Collaboration in Design and Delivery of the Malikai SCCTTR
Authors: Aramanadka Shankar Bhat , Hafernik Steven , Power Thomas , Tay Kay Yang 
Published: April 2018

Floating vessels with dry tree production equipment are large capital expenditure projects with multiple interfaces often spanning several entities, including the Operator, Engineering Procurement and Integration Contractor (EPIC), Rig Builder, Production and Drilling Top-Tensioned Riser (TTR) supplier, Subsea Wellhead supplier, and Surface Wellhead/Tree supplier. Design and Interface Management play a significant role in the success of a project of this magnitude. The Shell Malikai Single Combo Casing Top Tensioned Riser (SCCTTR) was successfully deployed and commissioned on the first TLP in Malaysia. The Malikai SCCTTR is an industry first and an example of innovative design configuration coupled with rigorous project execution to deliver a system that is an enabling technology for current industry market conditions.
The SCCTTR is a single riser used first for drilling and then remains in place for the full field life. This provides significant cost savings, both in hardware and operational time for large field developments, but introduces technical challenges to meet the requirements of both traditional drilling and production/water injection risers. This paper presents key design challenges to meet the requirements for ‘multi-purpose’ configuration and identifies how they were addressed to accomplish the project goal of flawless delivery. Project management was a key factor in achieving this goal. Shell chose a one-stop solution for delivery of the subsea wellhead and SCCTTR which provided advantages in management of interfaces and overall delivery. While this minimized interfaces, it still required a significant effort to coordinate components from multiple continents to deliver a single system. In addition to project management, the system required innovative design, as illustrated by the tensioner system, which introduced new features such as deflection absorbing bearing pads to limit the impact of the SCCTTR on the TLP hull design. Even with the additional features, the new tensioner system was designed, manufactured, and qualified within the project schedule. The Malikai SCCTTR stands as a testament to what can be accomplished when innovative design approach is coupled with robust project management and collaborative efforts between operator and equipment suppliers.
All-Electric Subsea Systems - Intelligence on Demand
Authors: Elgsaas Kristin Moe , Hjertvikrem Terje , Hua Wei , Tryti Svein , Glomsaker Terje 
Published: April 2018

Abstract
Interest in All-Electric subsea solutions has grown significantly over the last few years. The trend coincides with subsea electric actuation gaining a solid track record after 15+ years of operational experience, and ongoing industry wide discussions and validation of the benefits of All-Electric systems. A diverse group of subsea vendors and operators, including BHGE, has shared analyses showing how a move to All-Electric subsea production system reduces CAPEX and OPEX.
This paper starts with an initial introduction to All-Electric subsea systems, including system types, and an overview of the direct benefits of moving from electro-hydraulic to fully electric solutions. However, the main focus of the paper is the additional benefits from subsea electrification that can be derived by leveraging the data available in electric systems to confirm system health at any given time and predict future system conditions. Benefits are considered in the context of electrically actuated systems, life of field production system performance and enterprise level strategies. Finally, the paper looks at how any electrification strategy should be aligned with automation efforts and digital strategies.
Autonomous Inflow Control for Reduced Water Cut and/or Gas Oil Ratio
Authors: Elverhøy Anita B. , Aakre Haavard , Mathiesen Vidar 
Published: April 2018

Abstract
One of the main challenges for increased oil recovery is major breakthrough of unwanted fluids as water and gas, due to uneven influx along the horizontal section. The problem can be avoided or significantly reduced by deploying novel inflow control technologies. Inflow Control Devices (ICD) and Autonomous Inflow Control Devices (AICD) are able to delay breakthrough, but not stop the production of unwanted fluids completely. The newest generation of inflow control technology, the Autonomous Inflow Control Valves (AICV) can optimize the oil production, in both new and old wells, and reduce water cut and/or gas oil ratio significantly. The benefit of the AICV is to provide balanced inflow of oil along a horizontal well, by autonomously choke or close the breakthrough compartments, and still produce from the rest of the reservoir.
The commercial near-well simulation tool, NETool, is used to model a horizontal section with uneven influx along the well. Completion with 16 evenly distributed AICVs in 8 isolated zones is compared to an open hole situation and completion with nozzle ICDs. Simulation of one medium viscosity oil reservoir with water choking, and one light oil reservoir with gas shut-off are performed to demonstrate the increased oil production and recovery by implementing AICV technology. In NETool several models of different types of inflow control are available, including the model of Statoil's Rate Controlled Production (RCP). In this study, the RCP function is tuned to fit the experimentally determined flow performance behavior of the AICV and the function is utilized in the applied simulation.
A good correlation of the experimentally flow performance curves and the flow performance behavior of the tuned RCP function is obtained. The tuned RCP function gives a realistic assumption of the functionality of the AICV, and shows that the potential of increased oil production and recovery is significantly in a range of reservoirs. The simulation result shows that for the medium oil reservoir the water cut (WC) is decreased from 60% with use of open hole completion to 29% for the situation with AICVs installed. The well completed with AICVs increase the oil production with 75%. In the light oil reservoir, the AICV closes the gas breakthrough compartments completely, and increases the oil production from the other zones. The Gas Oil Ratio (GOR) is dramatically reduced from 1281 Sm3/Sm3 for the open hole situation, to 57 Sm3/Sm3 with AICV completion. In both cases a simulation of a nozzle ICD is performed, showing that the performance of the ICD is in between the open hole completion and the situation with AICVs installed.
Mooring Design and Operation Practice for Floating Units Subject to Ice Loading
Authors: Morandi Alberto , Kwan Chi-Tat Thomas , Shelton John , Yao Aifeng 
Published: April 2018

Abstract
An Arctic Mooring JIP was initiated by Kwan Engineering Services and Global Maritime in 2013 to address the issue of Arctic mooring design and operation practice, which was completed in 2016. There were 24 participants including operators, drilling contractors, regulators, designers, and hardware manufacturers with a total funding of $780k. The JIP had five tasks related to mooring in the Arctic:Task 1 – Guidance on mooring strength design practiceTask 2 - Assessment of disconnect devices and requirementsTask 3 - Assessment of mooring components for operations in the ArcticTask 4 – Guidance on methods for ice load predictionTask 5 - Guidance on ice management strategies
A guidance summary on Arctic mooring design and operation practice was developed by the JIP for input to industry standards. This paper presents the key elements in the guidance summary.
ISO 19906 ‘Arctic Offshore Structures’ (ISO 2010) is the most recognized Arctic design code for fixed and floating structures, which does not provide practical guidance for mooring design and operation. API RP 2SK (API 2005) is the most recognized mooring design code, which does not cover moorings subjected to ice loading. The guidance developed by the Arctic Mooring JIP bridges the gap between these two codes and is a significant milestone for the design and operation of Arctic floating systems. The API Mooring Resources Group has incorporated the guidance summary developed by this JIP into a draft document for the 4th edition of API RP 2SK.