bluuebunny/crossref_metadata_2025_split huggingface dataset:
Flexible Hose Technology Benefits for Ship-to-Shore High Pressure Natural Gas Transfer
Authors: Szekely Gergely , Peixoto Eduardo 
Published: April 2018

Abstract
A few years ago the industry started to look for alternatives to the LNG loading arms and moved towards the cryogenic hoses. Recently the volatile gas prices and the consequent quick paced projects resulted the same pattern on the high pressure side of the FSRU: more and more players are looking into utilizing high pressure flexible hoses for the ship-to-shore regasified transfer lines due to the technology's inherent advantages including its very short lead time.
This paper is to demonstrate the benefits of the flexible hose transfer lines over rigid marine loading arms when used on the high pressure side of an FSRU or even an FLNG vessel. A side-by-side comparison of the two technologies is presented accounting for technical capabilities, installation considerations, associated levels of risks as well as investment costs including upfront expenditure, operational and logistics costs. The operational envelope of the hose transfer line is studied and defined by finite element analysis (FEA).
Brief overview is given on the existing operational history of high pressure flexible hoses on FSRU vessels. Technical properties of the hose technology are discussed in details in contrast to marine loading arms, such as the magnitude of weight and footprint reduction, fewer number of leak paths along the transfer line and much lower requirement of hydraulic power to operate. The loading arm's moving components are substituted by the flexible hose's intrinsic flexibility significantly reducing maintenance needs and downtime. It is highlighted how the lack of complexity of the system drives down the costs: starting with a significantly lower CAPEX through reductions in OPEX as well as savings on installation and logistics. It was found that the complete lead time of less than 6 months of the whole system can address such quick paced terminal projects which was not possible with marine loading arms. Finally the result of the system integration study will be presented supported by the operational envelope limits derived from a FEA model.
An Underwater Robotics Platform for Hybrid AUV/ROV Systems
Authors: Siesjoe Jan 
Published: April 2018

Modern ROV and AUVs are becoming more and more capable. Traditional ROVs are enhanced by sophisticated piloting aides to improve quality and to reduce operator load, minimizing errors and increase safety. Increasingly more complex AUV operations are becoming possible which involve decision making and intervention. In many ways the line between advanced ROV and AUV is disappearing.
These systems are also becoming more and more complex and therefore more expensive to develop and qualify. At the same time the demands and tasks are changing requiring vehicles of different shapes, power levels, tools and functions to cope with these.
The way that has chosen to address this, to be able to quickly field new vehicles that meet customer demands in a cost effective manner, is a technology platform. Reusing hardware and software components in between ROV and AUV systems allows us to build new systems that from the start have proven performance, reliability and a large user base to build on. This, combined with open interfaces that allow customers and third party suppliers to provide their own "intelligent" functions into the system, allows rapid deployment of new systems such as resident AUV and ROV systems.
This paper will present the Robotics Platform and interface philosophy along with a view of the roadmap forward. It will cover existing components and how they are used. It will discuss open interfaces and how they are used in recent projects and some views on coming developments.
Risk Based Internal Corrosion Assessment of Pipe in Pipe Flowline
Authors: Hogelin P. T. , Webb J. T. , Ruocco Y. , Vadel D. , Hill R. 
Published: April 2018

Abstract
Safety and protection of the environment are paramount to successful, effective operations. A prominent challenge in the offshore oil and gas industry is striking a balance between maximizing production from a field and managing risks to meet or exceed regulatory compliance and safety goals. Noble Energy currently manages integrity of its Gulf of Mexico deepwater assets through implementation of a riskbased integrity management (IM) program. The objective of this paper is to demonstrate the value of a risk-based assessment process to mitigate internal corrosion of a pipe-in-pipe (PIP) flowline by progressively advancing detailed engineering assessments from routine monitoring activities. The results improved understanding of internal corrosion degradation mechanism and allowed for an update to the IM plan for remaining service life.
As part of Noble Energy's subsea IM program, annual asset risk assessments are conducted to identify, assess and control operational risks. Key performance indicators (KPIs) have been implemented to manage degradation mechanisms during design review and flag potentially unfavorable operational conditions. The exceedance of a KPI limit and the reliability of monitoring data directly affect the predictability of the associated degradation mechanisms. Elevated corrosion rates from a conservative corrosion model, combined with discrepancies in topsides corrosion coupon sampling, resulted in lower confidence for threat predictability. This prompted a more detailed assessment to confirm integrity of the flowline. The assessment included a review of design and historical monitoring data. A complete produced water analysis was executed to update the corrosion model. A flow regime analysis was conducted to assess the pipeline water-wet condition and water hold-up potential for current operational conditions.
This paper presents challenges and assumptions in identifying representative load cases from a 10-year operational history. The result of the assessment was the identification of areas along the flowline with medium to high water-wetting probability, and understanding of the hazards associated with internal corrosion at the identified locations. This study provided significant improvement in visibility of the internal corrosion degradation mechanism of the flowline and develop continued risk management strategy.
This paper presents a holistic approach to managing internal corrosion threats for subsea flowlines. It demonstrates the value of linking data to degradation mechanisms to improve understanding of risks on the assets, and the value of a structured program to ensure informed and confident decisions can be made by an operator.
Application of Wear-Resistant Elastomer to Significantly Improve Service Life of Telescopic Joint Packers
Authors: Denison C. R. , Fiore C. J. , Krakowski F. J. 
Published: April 2018

Abstract
Advancements in elastomer technology have enabled an increased reliability and longevity of elastomeric packers used in telescopic joints. This paper provides an overview of a new nitrile and its benefits, including improved uptime for telescopic joints, achieved by prolonging seal life while maintaining actuation pressures similar to standard nitriles.
Elastomer specimens of several nitrile and polyurethane variants were subjected to rotary platform abrasion testing per ASTM D3389. This test measures the mass lost by a specimen as it wears against a rotating abrasive wheel. These same materials were subjected to ASTM D471 standard test method for liquid effects on rubber, using water as the test fluid to evaluate their propensity to swell. Telescopic joint packers manufactured from two of these compounds were subjected to full-scale laboratory comparative testing using a modified API 16F wear test. The packers were finally installed on offshore rigs to confirm the laboratory results in an operational setting.
Until recently, the industry has primarily employed standard nitriles or urethanes as dynamic seals in abrasive drilling applications. Standard nitriles often wear quickly in high-friction applications, leading to inefficient downtime to replace seals when a leak develops. Urethanes provide improved wear-resistance compared to standard nitriles, yet they are typically stiffer than nitriles and therefore require much higher actuation pressures. Wear-resistant nitriles circumvent this compromise by offering long service life without requiring changes to operating procedures. Recent advances have resulted in the growth and acceptance of wear-resistant nitriles as a solution to the market need for improved seal durability. The wear-resistant elastomer specimens demonstrated improved performance in standard laboratory abrasion tests, losing significantly less mass than standard nitriles. This durability improvement has been confirmed through full-scale product testing in the laboratory, as well as through field testing of seals manufactured from the wear-resistant elastomer compound. Results will be provided for two seals that were tested for six months on floating drilling rigs in Brazil and the North Sea.
OPEX Savings in Pipeline Blockage Remediation - Lessons Learnt from West Africa Experience
Authors: Bukkaraju Sampath K. , Osorio Nelson F. , Monge Juan I. , Estevez Gabriel J. 
Published: April 2018

Abstract
The primary objectives of this paper are as follows:
To share the lessons learnt from a recent blockage remediation experience offshore West Africa. To highlight the importance of sound engineering assessment in locating and identifying the nature of blockage and in the selection of appropriate blockage remediation technology. To present the methodology applied which minimized the need for costly rental equipment which in turn resulted in significant OPEX savings and minimal impact to production.
The approach taken to remediate blockages is usually driven by the cost and time required, customer preference and remediation goals (i.e., establishing communication and flow Vs. full clean out), impact to production, operating conditions, production chemistry of the produced fluids and injected chemicals, geographical location of the field, field layout, available facilities, operating history and availability and access to specialized equipment and skilled personnel. If not properly assessed and planned, blockage remediation costs can easily go out of control with no guarantee for success and a long term solution. To minimize the required resources and maximize the chances for successful blockage remediation, a structured path needs to be developed.
This paper presents and highlights the importance of accurate produced fluid sample data, information on injected chemicals and production history to determine efficiently the nature and location of the blockage. Review of the pressure and temperature sensors data at key locations along the flowpath and a good understanding of the early blockage remediation attempts and their outcomes help are key inputs to the engineering assessment of the blockage. This paper shows how the right interpretations of the sensor data prior to and during remediation of the blockage are essential part of a sound engineering assessment. The assessment followed by the selection of suitable remediation options led to the successful remediation of the blockage. The options selected were those that could be readily implemented requiring no specialized or additional equipment, avoiding alternatives that involved considerable cost and time for deployment.
Autonomy Applied to Seep Hunting for De-Risking Exploration
Authors: Lindsø Steffan 
Published: April 2018

Abstract
By finding and evaluating seabed seepage of oil and gas, geologists can make better decisions about drilling expensive exploratory wells. However, current seep hunting methods are costly and time consuming, and provide inconsistent results. This paper presents a concept for a new seep hunting method that uses systems comprised of existing autonomous technologies, advanced sensors, and remote piloting technologies. By using technologies developed in the oil and gas industry and other sectors, the concept has the potential to completely change the way that seepages are found and analyzed.
The current, prevailing method for seep hunting requires multiple steps, first using autonomous underwater vehicles (AUVs) to survey the seabed, followed by deployment of large manned service vessels and remotely operated vehicles (ROVs). In contrast, the new approach can discover and analyze seepages in one mobilization, without any need for personnel offshore. The system uses autonomy to deploy surface and underwater vehicles to the site and find seepages, and utilizes remote piloting technology for close-up analysis of the seepage—effectively bringing shore-based geologists to the location of the seepage.
During the past decades, the oil and gas industry has applied a range of new technologies to solve subsea engineering problems, largely for installation and maintenance of offshore infrastructure. These technologies include multi-beam sonar, ROVs, autonomous pipeline inspection vehicle sensors, and satellite communication networks. In addition, research for sensing and analyzing chemicals has pushed subsea sensor technology far beyond what was possible a few years ago.
Many of these new technologies can be combined into completely new ways of exploring for seepages to provide additional data to geologists and reduce the risk of drilling an unsuccessful exploratory well. The new method will be smarter, less expensive, and capable of covering much larger areas of the seabed than current seep hunting techniques. Most importantly, they will offer the geologist the ability to stand onshore behind the ROV pilot and explore the seabed in real time.
Managing Marine Risks to Offshore Oil Structures: How Close is Too Close?
Authors: Tieman Jason 
Published: April 2018

Abstract
Vessels are a critical part of offshore drilling and production operations, but they also pose a major risk to an organization's operations and to other nearby infrastructure. In some regions, vessels can also represent significant security risks. It is necessary to identify and prioritize the greatest operational risks that vessels can pose, along with their associated safety, security, and financial impacts. One of the first steps to take when trying to understand the risks associated with vessel movements is to use the same Automatic Identification System (AIS) data that has been used during the past decade to monitor vessel activities for logistical and safety purposes. Combining AIS data with radar and other input gives operators the information they need to detect, assess, and mitigate threats to offshore infrastructure before an incident can occur.
This new way to manage and mitigate risks overcomes the problems with earlier approaches (such as simply setting a radar "guard ring") and creates the opportunity for innovative new capabilities, such as establishing remote watch teams that have a consolidated view of all assets anywhere in the world. By performing watch activities, and collaboratively using a web-based platform, a centralized team can monitor and respond to risks identified across multiple global assets, ensure standardized compliance, and facilitate key performance indicator (KPI) measurements for marine risk management. Operators can also gain new insight into logistical challenges and contractor performance.
Construction Challenges in Future Offshore Wind Developments
Authors: MacLeay A. , den Hollander R. 
Published: April 2018

Abstract
Offshore wind is now a well-established technology in Europe with 12,631MW installed capacity from 3,589 grid connected wind turbines in 10 countries. The technology is now expanding in to new markets in North America and the Far East.
This growth is being fuelled by the reducing cost of offshore wind generation with the first subsidy free projects now in development in Europe. In these markets offshore wind will be a lower cost and more environmentally friendly means of generating electricity than gas.
This cost reduction has been driven by a number of factors but three important ones are discussed here together with a number of lessons learned from recent projects.
The wind turbines are steadily getting bigger. Larger turbines mean that fewer need to be installed for a given project size. The average size of a grid connected turbine in 2016 was 4.8MW but the future subsidy free projects will require turbines closer to 15MW. This means larger foundations and heavier turbine components need to be installed.
There is a significant degree of standardisation and repetition in the installation of offshore wind. High levels of repetition mean that a greater investment can be made on installation techniques, installation aids and procedures than would normally be seen on a one off project. This in turn places a higher demand on production and installation engineering than experienced on oil and gas projects.
The cost of project finance has come down significantly. These projects are very large and most Utilities will no longer finance them off balance sheet. Therefore the bankability of projects is critical to the developer in reaching financial close.
Based on recent successful project delivery there is a broad range of investors willing to provide finance. However, the financiers and their technical advisors set the risk levels, contracting strategy and very often the construction methodology.
Trends in offshore wind projects and lessons learned from recent projects are discussed.
A Universal Field Development Approach for Advancing Stalled GOM Deepwater Projects
Authors: D'Souza Richard , Basu Shiladitya , Khurana Sandeep 
Published: April 2018

Abstract
Following the oil price collapse in mid-2014, the number of deepwater projects with a floating production host platform sanctioned in the GOM plunged to historic lows. In this period only three projects were sanctioned, Stampede (2014), Appomattox (2015) and Mad Dog 2 (2017). During this time cost compression across the industry reduced the average breakeven project costs from $70 per barrel to $45-$50 per barrel for many, but not all deepwater projects. An additional 10%-15% reduction in breakeven costs is required to get these stalled projects to a final investment decision.
The industry is assessing and implementing many different strategies to achieve these additional cost efficiencies that include standardization, simplification, technology, collaboration and creative financing. Many of these are being addressed at a component level rather than at a field development level. A universal field development approach for deepwater GOM projects requiring a host platform is proposed that entails using the same building blocks for a majority of field developments that will:
Provide a universal field development solution that accommodates a range of reservoir types, sizes and complexities Maximize flexibility for field layout, phased development and contracting options Reduce project delivery uncertainty, as universality facilitates standardization and repeatability Significantly improve discovery to First Oil cycle time while adapting to changing reservoir information during the development phases
This paper presents a universal field development approach together with specific standardization and simplification recommendations of its key component building blocks; floating host platform and subsea system. Taken together these will provide the additional break even cost reduction, project cycle time improvement and increased certainty of project delivery to enable operators’ to confidently sanction a greater number of stranded deepwater Gulf of Mexico projects than is currently possible.
Virtualization: An Innovative Way to Reducing CAPEX and OPEX for Control Systems
Authors: Memuletiwon D. T. , Zimughan J. T. , Etukudoh B. I. , Olami O. , Ntemuse J. S. , Roberts E. N. , Oranye I. C. 
Published: April 2018

Typical Control and Automation Systems for Oil and Gas Production Facilities consists of a large footprint of physical computer systems deployed as Workstations, Servers and HMI's (Human Machine Interfaces). Managing these systems however, can be expensive and time consuming. Given the relatively short lifecycles, frequent upgrades are required with associated plant downtime and significant CAPEX (Capital Expenditure) and OPEX (Operational Expenditure). Therefore, there is a need to maximize availability of the Control and Automation System installed base, throughout the life of the production facility by way of adopting novel technology as a key differentiator.
Virtualization is a Technology that decouples hardware and software. It allows installation of multiple operating systems that can be run as virtual machines using shared resources (Hard disk, Processors, Network Cards etc) from the physical server. Although the concept of virtualization has been in existence in the last two decades, the growing synergy between IT (Information Technology) and Industrial Automation unlocks a new platform to deploy this technology in a way that can radically change the way Process Automation networks are designed and implemented leading to simpler, more cost effective & scalable networks. The underlying concept is to improve design efficiency with minimum Physical Servers/Workstations by way of running multiple servers on a single physical machine, and in more advance deployments, collocating servers from multiple facilities to the back-end office or at a 3rd party datacenter. Currently virtualization is in use in most office domains for business applications (such as ERP) but this novel approach would focus on adopting this technology as a key differentiator in the Process Control Domain (PCD). This paper presents an overview of Virtualization, as a Control Systems solution and how it contributes to OPEX and CAPEX reduction for production facilities operations.
Development of Approval Procedures for the Land Transport of Equipment on Public Roadways
Authors: Saaijenga D. , Ekici D. , Herrington P. , Roberts M. 
Published: April 2018

The offshore energy industry continues to grow worldwide into new frontiers using larger than ever, marine equipment. Much of this equipment is infrastructure fabricated at yards located inland from traditional marine terminals which then requires specialized road transports to be used. Concurrently, Marine Assurance agencies are being called upon to act as the verification agency for these transports with one of their primary goals being to ensure the safe transport of the equipment.
Despite the relatively high number of marine equipment public road transports, the importance of robust securing of cargo is often underestimated in the industry. Additionally, the required operational Quality Assurance/ Quality Control (QAQC) procedures to be applied for a successful and safe operation are often disregarded. One of the main contributors to these issues is the lack of common guidelines recognized across the industry. The correct understanding of the requirements for the road transport will permit reliable and cost-effective operations to be performed in a timely manner.