bluuebunny/crossref_metadata_2025_split huggingface dataset:
Introducing Single Deck Topside Concept for Large New-Build FPSOs in West Africa
Authors: Kim S. E. , Kim S. H. , Chung B. Y. , Lee I. H. , Jung J. J. 
Published: April 2017

Abstract
The era of the low oil price makes all key players to establish the distinct business and technical strategies from the past successful models of offshore plant for better construction and operation. This paper describes design features of a single deck topside and wide beam hull concept for large new-build FPSOs in West Africa. The single deck topside is a common concept in the platform of small production capacity, while it is not applied to large new-build FPSOs. Generally, multiple deck topside has been introduced to large FPSOs to carry a lot more equipment within allowed footprint area. But, it has caused heavy structural reinforcement and complicated layout in topside. To overcome this shortcoming in Large FPSOs, our approach increases the hull deck area, mainly by the breadth more than conventional vessel. Equipment is grouped by the functional similarities and arranged on larger main deck. Other fitting and less heavy equipment may be located on the self-supporting structure. The major piping route, valve location and topside structure are also verified. Combination with mega-block modules could enhance the benefits of this concept, especially in saving the execution time and obtaining the design flexibility. Further, it creates more value of the maintainability by open overhead access to the main equipment, not compromising the safety. Initial hull sizing is carried out in terms of optimizing weight and motion characteristics. Several barriers are reviewed for realizing the single deck topside and wide beam hull, based on the previous experience. Finally, the benefit of this concept is validated by the 3D modeling. In this paper, the main findings and further discussion points from the study are addressed.
Long-Term Abrasion Test for Seabed Mining Hose Liners
Authors: Neale Peter , Nagy Tibor , Grepaly Istvan , Tóth Péter , Kristóf Gergely , Csobán Attila 
Published: April 2017

Abstract
The results of a long term abrasion test on 10" hoses were compared to flow simulation based abrasion calculations. An impact angle dependent small scale abrasion test was carried out on the rubber liner material to establish input data for abrasion simulation. The simulation proved to be very sensitive to the dependence of the impact angle on the abrasion rate, particularly at low impact angles. Three different lining materials were applied in the full scale test: rubber, a proprietary plastic liner and rubber with built in hard steel rings using a purpose built machine. The abrasion rate increased in the following order: armored liner, rubber and plastic, although the plastic had better Schopper abrasion than rubber.
Residual Strength Pushover Analysis: Enhanced Assessment of Seismic Platform Performance
Authors: Litton Richard , Ku Albert , Chen Jiun-Yih , Fraser Ramsay , Beck Richard 
Published: April 2017

Abstract
For abnormal (ALE) and reliability (RLE) level earthquake events (return periods of 2,500-10,000 years) used in the design or assessment process, there is a need to establish the acceptance of the structure's ability to survive the event. The present industry practice of subjecting a platform to nonlinear dynamic simulation of several severe events relies on significant and somewhat subjective judgments by the engineer in the determination of platform survival. This paper presents a method for quantifying the resulting damaged state, leading to a more explicit and reliable determination of platform robustness.
Residual Strength Pushover Analysis compares the ultimate strength of the undamaged or pre-earthquake condition of the structure to the residual strength of the structure after the severe earthquake using both pseudo-static pushover analyses and nonlinear dynamic time history analyses. The method requires nonlinear structural analysis software capable of capturing the damage state of the structure from the time domain earthquake simulation in a pseudo-static pushover analysis after the earthquake.
The research work presented in this paper shows a clear distinction between inefficient seismic framing systems such as K- and Diamond-braced systems in contrast to the robust, ductile systems utilizing X-bracing schemes.
Two separate case studies are presented in this paper to demonstrate the methodology and provide a recommendation for the acceptance criteria. One study uses a representative structure fitted with four different framing systems (K, Diamond, X without perimeter horizontals and X with perimeter horizontals) and the other uses an existing structure modified to improve seismic performance.
Combining the Most Efficient Active Heating Technology with Subsea Electrical Distribution to Develop Remote Resources
Authors: Verdeil Julien , Giraudbit Sonia , Silcock Donald , Cherkaoui Saad 
Published: April 2017

Abstract
Active heating technologies are for the moment based on topsides power distribution, limiting by default, the length of the flowline that can be heated. It is proposed to extend the range of active heating technologies by utilizing a field architecture that enables production for very long tie-backs by combining subsea electrical power distribution with the most efficient active heating technology the "Electrically Heat Traced Flowline" (EHTF) technology.
The paper will present typical field architectures that require such combinations of subsea electrical power distribution and efficient active heating technology, typically brown fields with remote tie-backs that could not be developed with available technologies.
EHTF Technology is based on a field proven high performance thermally insulated pipe-in-pipe, limiting the heat loss. Multiple high voltage wires, connected as three phase circuits, laid under the insulation along the entire length of the fluid carrier pipe, are used to provide heating. The heating wires extend typically 20km each side of a small in-line structure allowing safe penetrations into the pipe-in- pipe annulus. This small structure is powered on by a power cable, laid alongside the flowline, via a subsea electrical power distribution unit, which can be combined with a subsea transformer, to distribute the power to the multiple heating circuits within the annulus.
Exceptional thermal efficiency of the insulation system generates lower heating power requirements, meaning that subsea distribution systems can be designed with reliable and off the shelf components, easily retrievable and maintained with low operational expenditures.
Multiple circuits in the cross-section offer a greater operational flexibility and improved reliability of the system. Different power outputs can be provided from simple switching control depending on the heating requirement.
Combining an efficient, reliable and flexible active heating technology with a simple and robust subsea power distribution allows development of remote fields that can be tied-back to existing facilities, virtually without limitation in length.
On-Bottom Stability Analysis of Submarine Pipelines, Umbilicals and Cables Using 3D Dynamic Modelling
Authors: Youssef Bassem , O'Brien Dermot 
Published: April 2017

Abstract
Submarine pipelines and umbilicals are essential elements of many offshore hydrocarbon developments. In general, the most economical approach is to lay the pipelines and umbilicals directly on the seafloor with adequate self-weight to avoid any requirement to perform secondary stabilisation work such as trenching. A fundamental design requirement for this scenario is to ensure adequate pipeline stability under extreme environmental loading conditions, as excessive lateral displacements may result in pipeline or umbilical damage.
The commonly used and widely accepted recommended practice DNV-RP-F109 (Ref. 3) provides three design approaches with increasing levels of complexity to perform on-bottom stability design. These three design approaches are: Absolute Lateral Static Stability, Generalised Lateral Stability and Dynamic Lateral Stability Analysis. The first method is based on two dimensional (2D) force balance equilibrium equations while the second method is based on extensive dynamic modelling results of 2D pipeline models. These first two methods are intended to provide conservative on-bottom stability designs for rigid pipelines. The third method involves detailed finite element modelling of the pipeline under a time domain hydrodynamic loading.
This paper highlights the DNV-RP-F109 recommended practice limitations with respect to the on-bottom stability design of flexible pipelines, umbilicals and cables. The paper presents a dynamic simulation methodology, in accordance with the recommended practice DNV-RP-F109, for on-bottom stability design of rigid pipelines, flexible pipelines, umbilicals and cables, together with specific sensitivity analyses and comparisons with the Absolute Stability method.
The dynamic modelling results and comparisons presented in this paper highlight some limitations of the Absolute and Generalised methods for flexible pipelines, umbilicals and cables and illustrate the benefits of using the three dimensional (3D) dynamic stability analyses. The results of the sensitivity analyses clearly identify important parameters for the dynamic simulation, such as the hydrodynamic load correction due to the pipeline movements, the pipeline axial stiffness and the seabed passive soil resistance, that significantly affect the on-bottom stability behaviour. Refining the identified parameters input values will lead to more accurate and cost effective on-bottom stability design.
Design of an Energy Storage System ACAES Applied to Marine Renewable Energy: Study Case Based on Energy Integration Approach
Authors: Chassé C. , Lemois F. , Chilloux D. , Langeard O. 
Published: April 2017

Abstract
Marine energies (including wind turbine, tidal current and wave energy) are now recognized not only as high potential energy sources, but also as a significant and maturing energy market. Nevertheless, renewable marine energies are highly intermittent and so adequate energy storage systems are a main challenge for renewable marine energy development, to make it reliable and compatible with domestic and industrial power demand.
This paper focuses on the ACAES (Adiabatic Compressed Air Energy Storage) technology. It presents a study case of a large wind turbine farm (320MW capacity). After a state-of-art review on energy storage systems, the ACAES technology is selected as the most adequate solution for this case to store renewable energy, which means to store the entire produced power during low demand periods and to return all the stored energy during high demand periods. The operating principle of an ACAES system is that, using produced renewable energy, air is first compressed to be stored during low energy demand period. Storage is made through some natural cavity. Then the air is expanded during high energy demand period to return stored energy. A parallel heat transfer medium is used to make the system adiabatic.
An efficiency assessment is performed and key parameters are identified thanks to a heat and mass modeling and sensitivity studies. A suitable solution is selected and the storage system is sized, including process equipment (air compressors and turbines, motors and generators, pumps, water facilities as hot water storage and cold water storage, heat exchangers) and electrical systems. The required footprint is assessed by drawing a layout and a three-dimensional representation. The CAPEX of the selected ACAES system is estimated. Possible installation of this kind of storage system is assessed through a research on geological cavern and a review of available and possible air storages.
This work offers a comprehensive overview of a typical Adiabatic Compressed Air Storage installation, applying O&G plant design expertise to an emerging alternative energy, to make it reliable.
Feedback on the Design and Operation of the Skarv FPSO Mooring System
Authors: Naciri Mamoun , Heimsnes Tom Erik , Newport Andrew , Mée Romain le 
Published: April 2017

Abstract
The Skarv field, located 210 km offshore Norway, has been developed by BP using a turret moored FPSO, with first oil production achieved in December 2012. This paper presents the station keeping philosophy adopted for the FPSO, and gives an overview of the turret system design, and the challenges involved. In addition, based on four years of offshore operation, feedback on the behaviour of the mooring system is reported and compared with the design assumptions. The turret mooring system is located at 1/3 of ship length aft of the forward perpendicular, which reduces its passive weathervaning characteristics, leading to the provision of a heading control system to optimize topside ventilation, minimize turret loads and improve vessel motions. The harsh environment of the Skarv field, together with survivability considerations for a black ship conditions when power for the heading control is lost, result in mooring loads in excess of 5000 tons. These loads are significantly higher than loads imposed on previous FPSO turret mooring systems.
Operational experience from nearly four years will be compared to global performance as predicted during design stage through both analysis and model testing. Conclusions will be drawn about monitored global performance. Lessons learnt will be provided. Feedback from this frontier project will help the Industry tackle mooring system design in more and more challenging metocean conditions in the future.
The Qualification Methodology Behind an Integrated Multizone Frac Pack and Intelligent Completion for the Lower Tertiary
Authors: Jannise Ricki , Joubran Jonathon , Gavin Bruce , Coffin Maxime , Techentien Bruce , Geoffroy Gary , Craik Steve , Perez Eddie 
Published: April 2017

Abstract
Currently, ultradeepwater single-trip multizone completions are commonly run (Techentien et al 2016). Looking forward, improvement and progress can be achieved by using run history, lessons learned, and best practices. In the Lower Tertiary of the Gulf of Mexico, multizone completions in which differential pressure ratings of 15,000 psi are necessary, all operational stages should be considered, including stimulation treatments and production depletion. To date, little information is published about specific downhole component design methods or standard qualification processes required by operators and/or service companies. The objective of this paper is to help educate the industry by presenting the approach of one service company to address the 15,000 psi Lower Tertiary challenge.
This paper discusses the innovative qualification processes of all subsystems, including the intelligent upper completion, interfacing intermediate completion, and the sandface lower completion. The proven success of the industry-standard 10,000-psi generation IV (Clarkson et al. 2008) multizone frac-pack system (Grigsby et al. 2016) provides an installation and operating standard that is used as a basis for a 15,000-psi pressure-rated multizone system. Operators were interviewed, internal discussions with all stakeholders were conducted, and thorough reviews of current and future regulatory standards were completed to develop this methodology. This paper presents the results of these discussions and reviews the downhole components using a detailed qualification process. It also discusses the test procedures for full system validation to satisfy operator and regulatory requirements. The result is a reliable 15,000-psi differential, single-trip multizone system that incorporates an intelligent completion string for interventionless zonal isolation, control, and monitoring over the life of the well.
Cost Effective Solutions: Less is More
Authors: Agussol L. , Lavagna Ph. 
Published: April 2017

In a &gt;100 USD/bbl market, the project economics are optimized by different parameters than in a market below 50 USD/bbl. In high oil price context, the focus is on maximizing the revenue (i.e. production), whereas in low oil price context, the focus on costs is more important.
In today low oil price era, a new paradigm to optimize the project economics is &lt;&lt; Less is More&gt;&gt;:
Less equipment/complexity can also be More safety and more Reliability – as less equipment lowers the probability of equipment failure, also reducing both CAPEX and maintenance costs
Less CAPEX/OPEX should enable More projects to become economically viable.
Going to the essence of simple and robust systems enables solutions for the low oil price era. Indeed, while the HSSE commitment is not negotiable, the extra costs related to systems required for maximizing the production uptime are to be challenged to adapt the projects to the new market conditions. Using the example of mooring systems, a functionality review is performed so that the functional specification can be optimized for today's new set of project constraints. This applies along the EPCI chain:
Engineering: where relevant experience (industry standards and field proven solutions) can be used to avoid re-calculating everything to the highest degree.
Procurement where functional specification in place of – often over demanding - client specifications enables more standardization and thereby significant savings on price, schedule and sparing philosophy.
Construction where the clients can focus on ensuring/monitoring the HSSE and QA/QC performance of the project by choosing an ‘hands off’ approach on the execution part which enables the full benefit of using a seasoned contractor.
Installation – especially for Turret & Mooring systems – the installation aspects needs to be integrated from the beginning (Engineering). The most cost efficient way for a safe installation is to have the installation scope integrated in the mooring system contract (i.e. EPCI instead of EPC).
All these simple principles (simplification, standardization, streamlining of the work, lean management) have to be implemented to enable project economic viability in today's market. This Less is More approach has been used on recent tenders and has allowed significant cost savings and schedule reduction leading to further cost reduction.
Effect of Hydrodynamic Parameters on the Wax Mass Density: Scale Up From Laboratory Flow Loop to Crude Production Pipelines
Authors: Agarwal J. , Ravichandran S. , Daraboina N. , Sarica C. 
Published: April 2017

The oil and gas production pipelines typically operate at high Reynolds number and low wall shear stress conditions. However, the current wax deposition prediction models were developed based on the laboratory flow loop experimental data obtained at high shear stress and low Reynolds number. It is required to have reliable experimental data, which closely resembles the field conditions to validate the existing models or fine tune the effect of scale up parameters with available laboratory data. Hydrodynamic parameters such as Reynolds number and shear stress would incorporate the effects of diameter, flow rate and viscosity collectively, thus enabling a comprehensive approach for modeling the phenomenon. However, it is necessary to understand the individual effects of Reynolds number and shear stress as they are coupled.
In the present study, the effect of the hydrodynamic parameters is decoupled with specially designed flow loop experiments. The deposit thickness and wax content were measured, and the wax mass density (wax mass deposited per unit area) was calculated. Since the area of deposition is changing, the main variable analyzed in this study is the deposited wax mass density instead of the deposit thickness and wax content. From the results, it has been observed that the Reynolds number has a more dominant effect on the deposited wax mass density compared to shear stress. This behavior is observed for in house synthesized model oil and different crude oils at various experimental conditions. The results obtained in this study enhance our understanding on the deposition behavior at various hydrodynamic conditions and aids in scale up from the laboratory to field conditions. Moreover, in order to develop more accurate wax prediction models for operations particularly for waxy crude oil production lines, it is necessary to tune right scale up parameters for field applications.
Seismic Design of Subsea Pipeline Systems: Evaluation Study
Authors: Al-Showaiter A. , Kulkarni S. , Shi H. , Sun J. , Abdalla B. 
Published: April 2017

Abstract
When subsea pipelines and tie-in spools are supported directly on the ground, the differential ground movement due to seismic wave propagation may be neglected. This is because pipelines and spools have their centers of mass very close to the ground level. However, when the pipelines/spools are supported on, or connected to different structures (platform, subsea isolation skids, PLETs, etc.), the impact of the differential movements of these supports and structures on the pipeline and spools response should be considered.
The industry approach to the seismic design of a subsea pipeline system is that the system is designed for Extreme Level Earthquake (ELE) and is able to withstand Abnormal Level Earthquake (ALE) with some damage, but not loss of containment. The design of a pipeline system is iterative by nature. The pipeline loads on the subsea structure are input to the subsea structure design, while the subsea structure foundation resistance is an input to the pipeline integrity checks. Hence, an integrated model incorporating the pipeline, tie-in spools and subsea structures is the most comprehensive design method.
Pipeline systems are typically analyzed for seismic loadings by the modal response spectrum method, or time history analysis. The modal response spectrum method is a linear method and is not adequate when non-linearity should be considered (e.g. ALE). It is desirable that the designer should make every effort to ensure that the ALE is a confirmatory check, which should not lead to major adjustments in the design. To achieve this vision, the designer should use ductile material and the design should have sufficient flexibility; meaning that the system should be able to undergo large deformations without loss of containment. In essence, a time history method should be adopted. However, it is not often economical or a trivial task to perform such analysis in the early phases of the project definition (i.e. concept selection or pre-FEED) or even during the FEED phase.
Taking a case study, the application of different seismic analysis approaches to a pipeline system, including pipelines, tie-in spools, and subsea structures, is presented and evaluated. This paper also recommends the appropriate level of seismic analysis for different phases of project definition.