bluuebunny/crossref_metadata_2025_split huggingface dataset:
Simulation Experiment and Mechanism Research on the Change of Lateral Friction Against Surface Conductor in Deepwater Drilling
Authors: Meng Wei , Yang Jin , Tong Gang , Hu Nanding , Zhu Yi , He Li , Deng He , Zhao Yihui , Wang Xiao 
Published: April 2016

Abstract
Lateral friction against surface conductor plays an important role in the stability of subsea wellhead. It changes during jetting process and increases with soaking time. But the change rule and mechanism remain unclear. Therefore, the purpose of this paper is to explore the change mechanism of lateral friction during and after conductor jetting process by field experiment and numerical simulation.
Firstly, a field experiment was conducted to simulate actual surface conductor jetting process. The time- dependent change rule of radial pressure, pore water pressure and effective skeleton pressure were obtained. Then, the stress states of soil bodies during this process were analyzed. Based on experiment and analysis results, the primary reason that causes the change of lateral friction was found. After that, to explore the specific change features of bearing capacity of seabed soil for surface conductor, another field experiment was conducted. Finally, finite element method was adopted to simulate the conductor jetting process and to verify the research conclusions.
The field simulation experiment showed that the sensor at the base of surface conductor suffers conspicuous higher value of radial pressure than other sensors above. Meanwhile, the effective pressure of each layer has a tendency of declining as time increasing and then gradually adds after reaching a certain value. These regularities matches the change rule of radial pressure on piles during driving process. Based on the stress analysis, it is certain that the soil compaction effect does exist in conductor jetting process, caused by which, the formation and dissipation of pore water pressure during jetting process would be highly related to the change of lateral resistance against surface conductor. After jetting into position, soil lateral friction would increase with time non-linearly. The change rate would gradually rise at the first 10 hours. After 72 hours, the added values of friction are small and the change rate turns to flat. According to the numerical modeling results, under the action of jetting force, on one hand, soil bodies that are closed to bit are cut into grains and flow out from wellbore with drilling fluid; on the other, soil bodies that are farther from bit would be squeezed down and then pushed around.
Previous studies mainly considered the soaking time and bearing capacity of surface conductor, focused on specific values. This research designed a system to simulate surface conductor jetting process to explore the change mechanism of lateral friction against surface conductor by combining the method of numerical modeling and field experiment.
Integrity Management: Today and the Way Ahead
Authors: Villano Gregory , Scott Richard , Walters Paul , DeWitt Cris 
Published: April 2016

Over recent decades, sophisticated industrial control systems (ICS) have benefited offshore vessels, but the benefits have been at the expense of operational simplicity and transparency. Continuing questions about how system integrity is best managed raises important issues about the nature, measurement, management, and perhaps even basic concepts of system integrity in the maritime industry. Traditional definitions, concepts, and measurement tools do not adequately support the specialized integrity management needs of the maritime industry. The industry needs practical tools that are readily understandable, supported by a meaningful measurement technique, minimally disruptive to the current data and integrity management workflow, and sufficiently useful so as to endure and evolve the industry's knowledge about integrity in complex systems.
This paper explores a structure for a metric supported by a process to systematically evolve the maritime industry's knowledge about integrity in complex systems. The structure introduces a vital concept for system integrity management instantiated as a "corruption vector" that has dimensions useful for gauging the relative impact of integrity-reducing practices and incidents, while supporting the determination and mitigation of the root causes of those incidents. This paper also contemplates the implementation of an analytical method based on, (a) commonly accepted and well-understood software engineering models; (b) commonly collected information for describing the dimensions of a corruption vector; and (c) a transparent and practical decision support tool for quantifying, gauging, trending, and ultimately managing ICS integrity.
New integrity management concepts, tools, and processes are needed to clarify the nature of ICS integrity and provide actionable guidance to system managers. Utilization of a structure that embraces the concept of defining, gauging, and eliminating corruption vectors from complex systems is a leap forward in ICS integrity management.
Calculations Methodology for Dry - Transportation of Large Floating Units
Authors: van Burik R. , de Jonge J. B. 
Published: April 2016

Traditionally, floating production systems such as FPSOs are either self-propelled or wet-towed from their new-build or conversion yard to the place of destination. Heavy lift vessels were not considered suitable for these kinds of transportation projects due to their size. Since the inception of the Dockwise Vanguard in 2012 and the successful introduction in the market early 2013, an alternative is now offered to the industry making dry-transportation of FPSOs and other floating production facilities a reality. Early 2015 Dockwise transported the Goliat FPSO, a Sevan type, and the Armada Intrepid FPSO on the Dockwise Vanguard. The FPU for Moho Nord is scheduled for August 2016.
This paper addresses the technical challenges that had to be overcome to realize these projects and describes the extensive research program executed, and the feedback retrieved from the first FPSO dry transports.
Due to the sheer size, the stiffness of this type of cargo has an influence on the load distribution on the heavy transport vessel. Finite element analysis (FEA) has been executed to determine cribbing pressures as well as to study the structural strength of the construction. Varying the stiffness of the cribbing wood has shown to be of influence on the static as well as the dynamic load distribution. This initiates the discussion whether the traditionally used wood still poses the best technical and operational solution. Early 2015 Dockwise have conducted testing on alternative materials. Also real-time measurements on actual cribbing compression during a voyage have been performed and compared to the calculated values; this validation provides insight and possibilities to further improve the calculation methodology.
Pipeline Bundle Extended Length for Subsea Development
Authors: Animashawun Kolawole , Goodlad Martin 
Published: April 2016

The Subsea 7 Pipeline Bundle fabrication facility in Wester, Scotland UK has been utilised for the fabrication, pre-commisioning and launch of Pipeline Bundles in the North Sea and Norweigian Sea regions for over 36 years.
Subsea 7 has installed:
Three Pipeline Bundles in Australia for Esso’s Bream & Tuna Fields
Eight Pipeline Bundles for Elf Exploration Angola Girassol Field
Over seventy five Pipeline Bundles installed in the North Sea and Norwegian Sea regions
Research and Development work has been conducted to extend the length of a single Pipeline Bundle beyond the current site capacity of 7.7km, thereby further enhancing the Pipeline Bundle technology for longer subsea tie-backs.
Pipeline Bundle length extension can be achieved with the use of onshore tie-in methods such as golden welds, mechanical connectors or fabrication at a different site with sufficient length capacity. This paper presents an overview of potential methods that can be used for fabricatation, launch, tow and installation of Pipeline Bundle lengths greater than 7.7km. Case studies for Pipeline Bundle lengths between 8km and 15km inclusive have been analysed as part of the work.
The work confirms the feasibility of Pipeline Bundle length extension and the potential for significant reduction in CAPEX for subsea fields requiring long tie-backs. The use of the different connection methods further confirms that the Pipeline Bundle technology can be applied globally once a site with a suitable length is identified.
The work presented in the present paper highlights the critical elements associated with the application of Pipeline Bundle Extended Length. Emphasis is made on the Pipeline Bundle control during tow operation based on the companies tow expertise developed over the past three decades.
Operational Simulations of Safe LNG Offloading to Conventional LNG Carriers in Severe Open Sea Environments
Authors: Cahay M. , Paquet S. , Auburtin E. , Roberts B. A. , Olsen F. , Thorsen T. B. , Korneliussen P. B. , Voogt A. 
Published: April 2016

AbstractFloating Liquefied Natural Gas (FLNG) units, which have been under development for decades, are now a reality with Technip delivering the first two major projects in open seas. Both these projects incorporate side-by-side offloading of LNG from the FLNG to the LNGC (LNG Carrier) using loading arm technology. This technology will not be applicable in severe environments. Several tandem LNG offloading systems are proposed by the industry providing greater separation distance between the vessels and higher environmental thresholds. The drawbacks with such systems are the use of a dedicated LNGC fleet with a specific bow loading system or the deployment of long-length floating LNG flexibles (~300 m) to the midship manifold of conventional LNGCs.Recently, Technip has worked with HiLoad LNG to develop a smart LNG offloading system based on already proven and qualified technologies to be operated with conventional LNGCs (without modification). It allows a vessel separation greater than 100 m, high environmental conditions and a minimum length of LNG transfer lines. The system uses the HiLoad LNG DP (dynamically positioned) vessel for the position keeping of the LNGC parallel to the FLNG and Technip's cryogenic flexible pipes for the transfer of LNG and vapor. The system is suitable for either spread- or turret-moored FLNGs.The full-mission bridge at MARIN's Nautical Centre in The Netherlands has been used to simulate normal and emergency operations of the Parallel Loading System by use of a DP System developed by Kongsberg Maritime for this application. Real-time navigation simulations have been conducted with contributions from LNGC and HiLoad captains who have field experience from earlier HiLoad operations in Brazil and the North Sea. These simulations were performed to assess the DP station keeping capabilities and the marine operational procedures under steady and dynamic/changing environmental conditions. Blackout scenarios have also been investigated as part of the simulation work.The simulations have confirmed the ability of the HiLoad DP system to keep the LNGC inside a tight operating ‘green’ envelope during all investigated challenging metocean conditions and that the operation can be safely performed. The HiLoad LNG Parallel Loading System is a smart solution enabling a safe and robust LNG offloading method with use of conventional LNGCs.
Method for Field Monitoring Asphaltene Treatment Programs
Authors: Jennings David W. , Chao Kung-Po , Cable Robert , Oczkowski Wilson , Cote Dominic 
Published: April 2016

Abstract
In 2014 a new dead-crude oil asphaltene stability analysis method was introduced for evaluating asphaltene inhibitor performance (OTC25113). The method is named the Analytical Centrifuge Stability Analysis for Asphaltenes (ACSAA). It uses an analytical centrifuge in combination with a solvent destabilizing procedure tailored to push testing conditions closer to field conditions than previous dead-crude oil stability methods. It was also proposed to extend use of the method to field monitoring in 2014, but at that time, no applications had been trialed.
This paper presents results from the first field monitoring application implemented in a North America field with a CO2 - Water Alternating Gas (WAG) flood operation. The simple, rapid, high-throughput analysis capabilities of the method, coupled with precision to distinguish even small differences in asphaltene stability between samples, make the method well-suited for field monitoring. Examples are shown from more than a year of data, illustrating the method’s ability to detect changes in field treatment dosage rates and to compare treatment chemistries. Ongoing efforts to correlate the results to field expectations are also discussed.
Management of asphaltene deposition is a serious issue for the petroleum industry, so having additional means to improve treatment programs is highly valuable for operators. The introduction of this method for field monitoring now provides operators an additional tool for use in managing and optimizing asphaltene treatment programs.
Joining Forces to Unlock LNG Tandem Offloading Using 20? LNG Floating Hoses: An Example of Industrial Collaboration
Authors: Giacosa Alain , Mauries Benjamin , Lagarrigue Vincent 
Published: April 2016

Abstract
Moving LNG production to an offshore setting presents a demanding set of challenges. Along with the design and construction challenges of developing FLNG facilities, extra thought has been required regarding the transfer of the product; LNG transfer must now battle with the effects of winds, waves, and currents in open seas. In environments where conditions are much more demanding, conventional marine loading arms will not suffice as they could result in a shut-down of the liquefaction plant in bad weather conditions.
This paper outlines why tandem offloading solution that rely on the use of flexible hoses are a viable alternative for the industry - not only limiting downtime, but also improving safety. Hydrodynamics analyses have been performed to demonstrate that the performances of such an offloading system are in compliance with targeted environments and associated operating envelope. Key results of this study will be introduced here.
This paper will also discuss why – in the absence of mature solutions – different actors have been joining forces to develop and qualify an innovative LNG tandem offloading solution using floating hoses that fully satisfies the industry’s requirements. It will be shown how the joint industrial program has been benefiting from diverse inputs coming from an IOC, an EPC contractor, a hose manufacturer and a University laboratory specialized in flow assessment.
Finally, as an illustration of such a successful JIP, significant information will be given about pressure drop analysis within a flexible cryogenic hose based on advanced CFD models and small scale water/LNG flow tests.
Subsea ESP Skid Production System for Jubarte Field
Authors: Tarcha B. A. , Furtado R. Goes , Borges O. C. , Vergara L. , Watson A. I. , Harris G. T. 
Published: April 2016

Abstract
This paper provides a general overview of the subsea Electric Submersible Pump ESP skid boosting system, and describes the technologies introduced to make the ESP system more robust, the resources brought together to move the required assembly tasks to a controlled onshore facility, the equipment validation program, and the initial experiences in installation and operation of the system.
Production of the 17° API heavy oil from Jubarte requires some means of artificially lifting fluids to surface. The high installation and intervention costs associated to subsea ESPs has prompted an operator to search for alternate boosting systems. The mudline ESP skid provides a solution for more cost-effective boosting of fluids to surface in deepwater fields.
The experiences gathered and results obtained with the operation of MOBO (Modulo de Bombeio, which is Portuguese for pumping module) ESP systems in the Jubarte and Golfinho fields have encouraged the operator to develop new ways for producing oil from these offshore fields using techniques to reduce considerably the installation and workover time and cost. In this way, the development of Jubarte Phase III uses a different arrangement for the mudline ESP, with the equipment installed in a horizontal skid instead of a vertical module. The skid comprises two horizontal ESP systems connected hydraulically in series and powered electrically in parallel by a medium-voltage drive located in a floating production, storage, and offloading (FPSO) platform. This setup reduces the size of the subsea assembly and allows use of a vessel of opportunity for deployment instead of a rig.
The subsea ESP skid concept was developed and tested on two previous occasions: an extended well test in Espadarte offshore Brazil and a production module in the Cascade-Chinook development in the Gulf of Mexico. In this new project, the equipment has evolved in relation to the previous installations, with a new and larger ESP system, the inclusion of chemical injection, access to hot stab, and the added capability to install a flow homogenizer.
The skid system design aims at improving economics for production of heavy oil fields while also addressing ESP run life concerns in these low gas volume fraction and high boost pressure deepwater applications.
Selection of Subsea High Boosting Multiphase Pumps for Incremental Oil Recovery of Aging Deep Offshore Fields
Authors: Fernandes Charles , Roux Christine 
Published: April 2016

The Rosa oil field was discovered in 1998 and brought on stream in 2007 via 20 km subsea production flow lines routed to Girassol Floating Production, Storage and Offloading unit (FPSO) in block 17, Angola. The production of the field has been decreasing mostly due to subsea network pressure drop amid water-cut increase and limited gas compressor capacity.
As result of conceptual studies and Research and Development (R&D) efforts, the installation of high boosting subsea Multi-Phase Pumps (MPP) and related subsea and topside integration modules was retained as the best economical and technical solution to increase production and maximize reserves recovery of Rosa field.
This paper describes the development process leading to the selection of the high boosting MPP concept and how the development of a new technology is managed by TOTAL in parallel to the development studies.
Adapting Tension Leg Technology to Provide an Economical Solution for Floating Wind Power
Authors: Melis C. , Bauduin C. , Wattez A. , Newport A. , Poirette Y. , Perdrizet T. , Averbuch D. C 
Published: April 2016

Abstract
The development of floating offshore wind farms requires the parallel development of suitable floaters to support the wind turbines. These floaters must be economic and must also exhibit good motion characteristics to limit the accelerations and inclinations imposed on the turbines during operation. This paper reviews the required characteristics of these floaters, addressing the requirements of fabrication, turbine integration, tow to site, and offshore installation, as well as the required behavior of the floater once installed. The benefits of an integrated design approach considering all of the above is demonstrated, and consideration is given to the industrialization of the production process for large numbers of floaters for full-scale wind farms.
Based upon this review of requirements, an innovative light weight structural solution incorporating tensioned mooring legs has been developed as an economic solution for the floater. The modularity of the design facilitates construction, and offshore installation can be accomplished using standard anchor handling vessel (AHV) means. The floater design exhibits low turbine inclinations and low accelerations due to a combination of its mooring arrangement and its high degree of transparency to waves, which reduces fatigue loads and maintenance issues on the turbine.
The floater behavior during towing to site and in the installed condition is described, and key performance characteristics are reported based on analytical simulations and model tests results conducted at 1:40 scale.
The paper seeks to clarify the key factors to be considered in developing a floater to support a wind turbine, and to propose a solution that achieves good motion characteristics whilst satisfying the economic constraints of wind farm development.
CompactSep™ - Compact Subsea Gas-Liquid Separator for High-Pressure Wellstream Boosting
Authors: Kristiansen O. , Sørensen Ø. , Nilssen O. R. 
Published: April 2016

Abstract
Subsea separation has successfully been implemented on the Troll and Tordis fields operated by Statoil, Pazflor (Total), Marlim (Petrobras), and Perdido and Parque das Conchas/BC-10 (Shell). One objective of subsea separation is to separate gas and liquid to optimize working conditions for subsea pumps enabling high recovery factors. The objective of this work was to qualify a two-stage, compact, inline gas-liquid separation system with full turndown and slug handling capabilities, consisting of already proven components: one Gas-Liquid Cylindrical Cyclone (GLCC) and one InLine DeLiquidiser.
CompactSep and its separator components and control system were qualified through a comprehensive, large-scale, real fluid and high pressure test programme at K-lab, a Statoil large scale test facility in Norway. This was done in a Joint Industry Project with Statoil as operator and Chevron, Petrobras, Total, and FMC Technologies as participants. The tests were performed with realistic fluids – 59° API condensate and 25° API crude, recombined with natural gas – and at realistic pressure conditions, from 25 to 90 bar, with and without inlet slug flow. The separation requirements for the CompactSep system were a liquid output with gas volume fraction GVF &lt; 0.1 and gas output with gas volume fraction GVF &gt; 0.995 downstream the separator system. The pressure drop limits were 2 bar (soft target) and 5 bar (hard limit). Separate and stricter requirements were set for the system’s individual separator components.
The main results were: a wide operating range where the performance requirements were fulfilled, 99% to 99.9% separation efficiency, gas qualities (GVF) between 0.995 and 0.999, and liquid qualities (GVF) between 0.02 and 0.1. The operational boundaries were challenged to determine the onset of liquid carry over and gas carry under. The actual operating range exceeded the design and performance predictions. The system handled slugging and start-up scenarios. The control system stabilized the process with relatively slow control valves.
The work developed and qualified an inline separator system with full turndown and slug handling capability. Qualification was performed at a wide range of realistic conditions and with high quality reference and performance measurements. Comparison of CompactSep and conventional subsea separation stations shows significant cost and weight reductions for the compact solution. What can be done subsea can be done topside. The CompactSep separator is a viable alternative to conventional vessels for topside applications where size and weight must be limited.