bluuebunny/crossref_metadata_2025 huggingface dataset:
Personalized Health Care System with Virtual Reality Rehabilitation and Appropriate Information for Seniors
Authors: Gachet Páez Diego , Aparicio Fernando , De Buenaga Manuel , Padrón Víctor
Published: April 2012

The concept of the information society is now a common one, as opposed to the industrial society that dominated the economy during the last years. It is assumed that all sectors should have access to information and reap its benefits. Elderly people are, in this respect, a major challenge, due to their lack of interest in technological progress and their lack of knowledge regarding the potential benefits that information society technologies might have on their lives. The Naviga Project (An Open and Adaptable Platform for the Elderly and Persons with Disability to Access the Information Society) is a European effort, whose main goal is to design and develop a technological platform allowing elder people and persons with disability to access the internet and the information society. Naviga also allows the creation of services targeted to social networks, mind training and personalized health care. In this paper we focus on the health care and information services designed on the project, the technological platform developed and details of two representative elements, the virtual reality hand rehabilitation and the health information intelligent system.
Tracking Engineering Education Research and Development
Authors: Williams Bill , Neto Pedro
Published: April 2012

<span style="font-size: 10.0pt; font-family: "Times New Roman","serif"; mso-fareast-font-family: "Times New Roman"; mso-ansi-language: EN-US; mso-fareast-language: EN-US; mso-bidi-language: AR-SA; layout-grid-mode: line;">In recent years, bibliometric analysis of publications has been receiving growing attention in engineering education research as an approach that can bring a number of benefits. In this paper two such forms, taxonomical analysis and citation analysis, are applied to papers from the first 2011 number of IEEE Transactions on Education (21 papers) and from the two 2011 numbers of the ASEE-published Advances in Engineering Education (22 papers). In the former approach, seven taxonomical dimensions are used to characterize the papers and in the second the references cited in the 43 papers were studied so as to analyze how the researchers were informed by previous studies. The results suggest that the silo effect identified by Wankat for disciplinary engineering education journals in 2009 was still apparent in the IEEE Transactions on Education in 2011. The Advances in Engineering Education papers show a wide range of cited references, including reference disciplines outside of engineering education, and this suggests that research published there is likely to be informed by a broad range of previous studies which may be interpreted as a sign of a growing maturity of engineering education as a research discipline.
Les usages linguistiques des adolescents québécois sur les médias sociaux
Authors: Lebrun Monique , Lacelle Nathalie
Published: April 2012

L'article s'intéresse aux pratiques linguistiques sur les médias traditionnels et les médias sociaux déclarées par de jeunes Québécois de 14 à 17 ans, fréquentant l'école française. Le questionnaire d'enquête utilisé cible de façon particulière les usages du français et de l'anglais chez cinq sous-populations : les francophones de souche, les anglophones de souche, les allophones de souche, les francophones d'adoption et les anglophones d'adoption. Les résultats démontrent un usage très diversifié du français dans la vie quotidienne selon l'origine ethnique : les francophones de souche et d'adoption l'utilisent presque toujours à l'école, avec leur famille et leurs amis, et, à un degré important dans leur consommation des médias traditionnels, alors que les trois autres groupes le choisissent de façon sporadique, lui préférant l'anglais. Concernant les médias sociaux, les comportements s'alignent également sur les origines ethniques, cependant la prédominance du français chez les deux groupes les plus francophones s'estompe quelque peu, semblant concrétiser la prédominance de l'anglais sur la Grande Toile chez les jeunes Québécois. La conscience linguistique des jeunes Québécois, d'un point de vue général, même celle des deux groupes de francophones, n'est pas encore très éveillée, non plus que leur opinion face à la francophonie.
Étude longitudinale de la prise de notes d'un cours universitaire français : le cas d'étudiants étrangers d'un cursus européen
Authors: Faraco Martine
Published: April 2012

Cette analyse de la prise de notes dans le cadre d'un cours universitaire français s'inscrit dans une perspective longitudinale et est centrée uniquement sur des publics espagnol, allemand et anglais, dénommés ici scripteurs non natifs (SNN). Nous nous intéressons aux abréviations, aux problèmes de structuration et de présentation, au recours éventuel au code switching, et nous nous attachons à voir s'il existe des récurrences en fonction du groupe linguistique dont sont issus les étudiants étrangers concernés.
Behavior of Mechanical Properties of High Wall Thickness and Grade in Hot Induction Bending
Authors: Kathayat Tribhuwan , Hill Rick , Goyal Rajesh , Dhar Sanjay
Published: April 2012

The use of induction heated bends for offshore pipelines and topside pipinghas been an industry practice for many years. However, with the use of higherstrength steels, such as API5LX70M and X80M, there is a need to understand theinduction heating and cooling parameters which may have effect on the resultantmechanical, toughness and dimensional properties.

To produce high quality bends it is important to consider the requiredchemical composition of the mother plate as well as the welding consumablesused to manufacture the longitudinal welds. Special attention must be paid tothe heating temperature and travel speed as well as the cooling watertemperature and flow rate to ensure that the bend meets the specificationrequirements. The mother pipe plate is produced by using a Thermo-MechanicalControlled Process (TMCP) to obtain the pipe mechanical and toughnessproperties whereas the properties of the bend are dependent on a highlylocalized heating and quenching operations. The same can be said for thelongitudinal weld metal which is formulated to meet as welded properties ratherthan local alterations produced through the induction bending process.

The goal is to deliver induction heated bends in the "as bent condition", however there are occasions when subsequent heat treatment is required usingeither a post bend tempering or a full quench and temper procedure. Both ofthese operations are time consuming and depending on the size of the bends maybe extremely difficult to accomplish without further altering the dimensionalproperties.

The data presented in this paper, represents a recent project wherein 56" ODAPI5LX70M PSL2 line pipe was induction bent and subjected to extensive testingand inspection to confirm the resultant mechanical, toughness and dimensionalproperties. The paper will highlight the need to pre-engineer the materials tobe used in supplying bends for subsea structures, pipeline jumpers, risertie-in sections and topside piping.

The process improvements were also suggested based on the trial results. Thepipe size & grade is 56" (OD)×28.10 mm (WT), API5LX70M PSL2.

Introduction

There is requirement of hot induction bends having radius from 1.2D to 10Dand bending angles up to 90?. Longitudinal sub-merged arc-welded pipesmanufactured from TMCP rolled plates are commonly used for band manufacturing. The pipe wall undergoes different modes of heating and cooling during theproduction of hot induction bends. In order to maintain mechanical propertiesof bends, the chemical composition of base metal and pipe weld seam should besuitable for the hot induction bending process.
HIPPS-Based No-Burst Design of Flowlines and Risers
Authors: Politis Nikolaos , Banon Hugh H. , Curran Christopher J.
Published: April 2012

An approach is presented for design of production flowlines and risers infields that rely on subsea High Integrity Pressure Protection System (HIPPS)because of high shut-in tubing pressure (SITP). The approach enables aninherently safer design using a design pressure lower than the SITP byselecting a wall thickness that provides high reliability against pipe failurein the unlikey event of HIPPS failure and hence exposure to SITP. The paper isintended to generate industry discussion on the feasibility and merits of thepresented approach particularly in the absence of API design codes forHIPPS-based subsea risers and flowlines. The presented design methodology issupported by a combination of analytical and experimental results. Ahypothetical deepwater field is used to demonstrate the methodology.

Introduction

Background

As the oil & gas industry moves to high pressure reservoirs in deepwaterwith SITP in excess of 15ksi, the design of fully rated flowlines and risersbecomes extremely challenged due to increased wall thickness, difficulty ofwelding and inspection, and weight of the line pipe. For such fields, the useof HIPPS becomes an enabler, i.e. by allowing a reduced design pressure for thecomponents downstream of HIPPS and hence reducing the wall thickness offlowlines and risers.

By definition, HIPPS is a high integrity system with a low probability offailure on demand. A possible design approach is to focus on the unlikely eventof the HIPPS valves failing to close upon demand and set the following designobjectives:In case of HIPPS failure and exposure of the system to SITP, flowlines andrisers should have an adequate margin of safety against failure. This objectiveis set by introducing reliability-based acceptance criteria for flowlines andrisers.Risers should be stronger than flowlines hence keeping any potential failureaway from the facility and avoiding harm to people.In case of HIPPS failure, there should be little or no damage to theflowlines and risers in order to minimize any follow-up replacement andrepair.

In addition, in case of HIPPS valves successfully closing upon demand, asection of the flowline immediately downstream of the HIPPS may be subjected topressures exceeding the design pressure hence requiring it to be fortified (asrequired by HIPPS design guidelines [4]). It is proposed that this fortifiedsection be designed with the same reliability objective as that adopted forrisers.

In order to meet the aforementioned objectives, the flowlines and risersdownstream of HIPPS must be checked against burst assuming that the system issubjected to the SITP. This design state is designated as the " accidental limitstate" or ALS if the frequency of this event is less than 1E-2 per year asdefined in [5]. The design requirement for the ALS is a low probability ofburst failure and a second requirement is little or no damage to the pipe andequipment downstream of HIPPS.
Slug Flow Induced Vibration in a Pipeline Span, a Jumper and a Riser Section
Authors: Jia David
Published: April 2012

Flow induced vibrations (FIV) have been observed in subsea jumpers. This studywas undertaken to assist the prediction and prevention of FIV in subseaequipment. This paper presents a multi-disciplinary methodology and solutionfor simulating and solving multiphase slug flow induced vibration in a pipelinespan, a jumper and a riser section. The methodology is implemented in userdefined subroutines and functions in CFD and FEA software usingthree-dimensional Computational Fluid Dynamics of multiphase flow and transientnonlinear Computational Structural Dynamics. This technique is equally validfor analyzing flexible and rigid pipelines.

This paper has many applications, such as, pipeline, risers, jumpers, manifold/tree piping, and other piping in general. The methodology andtechniques from this paper are applicable to both rigid and flexible pipes withinternal multiphase flows.

The results illustrate the process of slug formation and decay inside the pipe, and the dynamic response of the pipe, including dynamic stresses andfrequencies. The mixed flow of gas and liquid in a pipeline span, a jumper anda riser section is shown to form slug flow, induce vibration and potentiallymay lead to resonance of the piping, ultimately resulting in fatigue damage. Acomplete solution of three-dimensional fluid domain and structural domain witha multi-disciplinary approach accounting for interaction and deformationbetween two domains is provided.

The proposed procedure provides insight into understanding slug formation anddecay in a pipe while the pipe is also vibrating in response to this slug flow, accounting for the interaction between the two domains. This is a veryrealistic approach for simulating this process and solving this challengingproblem. A platform for analyzing and quantifying the fatigue damage andresonant response due to slug flow induced vibrations, and for betterengineering designs is presented. The methodology and techniques are notlimited to any particular type of equipment. It is robust enough to apply tomany pipe structures, such as, pipeline, risers, jumpers, manifold/tree piping, etc, and for both rigid and flexible pipes.
Flow Assurance of Vertical Solid-Liquid Two Phase Riser Flow During Deepsea Mining
Authors: Wijk Jort Merijn , Talmon Arno , Van Rhee Cees
Published: April 2012

Growing economies and world population make the step to deep sea mining forfulfilling our needs for food and raw material inevitable.

Deep sea mining typically consists of excavation of material at the sea bottom, vertical transport of material to the sea surface and further processing. Oneof the most promising concepts for vertical transport from large water depths(over 1000 m) is hydraulic transport: transport of solid material in an upward water flowthrough a riser. This paper describes part of a PhD study to flow assurance invertical hydraulic transport (VHT).

Excavated material has varying sizes, shapes and densities: relative velocitiesof particles during hydraulic transport therefore vary as well. Typicalmaterials are manganese nodules, phosphorous nodules and chips of SeafloorMassive Sulfide deposits. Particles heavily interact, e.g. collisions, overtaking andclustering. Worst case is riser blockage due to large clusters packingtogether, which immediately stops the mining operation. Nodules have a roundedshape, while chips of SMS are unspherical. Literature on VHT up to date isconcerned with spherical particles (spheres, nodules), while SMS cuttings arebecoming more important. Therefore, this paper extents research to thetransport of unspherical particles and consequences thereof for riser blocking.

To assess flow assurance of VHT, a numerical model has been set up, presentedin this paper along with simulation results. The model is experimentallyvalidated, methods and results are discussed in this paper. Experiments focuson transport velocities, transport regimes and formation of concentration peaks over longdistances. The information can be used in the hydraulic design of riser systemsfor solid-liquid flow.

Simulations show that, depending on inflow conditions, development of highlyconcentrated clusters is a large risk. Experiments indicate large solids arelikely to be transported in the plug flow regime. The combination of clusterdevelopment and highly un-spherical particles being transported in the plug flow regimeincreases the risk of riser blockage. Inflow conditions therefor should beengineered carefully to ensure a safe and reliable operation. Guidelines forinflow conditions are given.
Methodology To Determine Floating LNG Tank Capacity by Combination of Side-by-Side Down-Time Simulation and Cost/Benefit Analysis
Authors: Orimo Yohei , de Wilde Jaap , Ichimaru Yoshikazu , Terashima Takeshi , Berg Joris van den
Published: April 2012

Storage tank capacity of Liquefied Natural Gas (LNG) is one of the key designaspects for a Floating LNG production unit (FLNG). Because of the limitedfootprint of an offshore floating facility, a FLNG cannot have the same amountof redundancy in tank capacity as an on-shore LNG plant. In addition, theside-by-side LNG offloading operation in open sea is more onerous thanconventional offloading methods. Therefore the risk of the filling levelreaching the top of the tanks is higher for a FLNG than for an on-shore LNGplant, resulting in higher risk of shut down of the LNG production andassociated economical loss.

To overcome the aforementioned problems, this paper proposes a new methodologyto determine the design LNG storage capacity for side-by-side offloading. Itconsists of the following four steps:–Two (2) body motion analysis: for ten (10) year time series environmentaldata to determine motions based on model test;–Offloading criteria analysis: incorporating offloading operational scheduleand berthing criteria determined by navigation simulation;–Tank inventory calculation: incorporating production rate, LNG carrier size, FLNG capacity, LNG carrier arrival schedule, LNG offloading rate and initialFLNG storage inventory; and–Cost benefit analysis to determine the design FLNG storage size

Since FLNG is new for the industry, there is no generally establishedmethodology for analyzing the (weather) related downtime and the associatedrisk of tank top. This paper will exemplify the analyzing methodology for theAbadi FLNG project currently planned by INPEX Masela Ltd. in the Indonesiansea.

INTRODUCTION

Generally, the storage tank capacity of a FPSO is sized based on productionrun-down rate, offtake frequency and other design parameters such as offtaketanker size, number of tank compartment and so on. For a FLNG, the samestrategy basically can be applied. However, some FLNG specific issues need tobe considered.

Due to the cryogenic nature of LNG, the LNG transfer with floating hose cannotyet be carried out. Therefore, cryogenic LNG loading arms will be used for LNGoffloading between a FLNG and a LNG carrier in a side-by-side configuration(side-by-side offloading) which is a similar configuration for LNG offloadingbetween LNG carriers and a jetty. The availability of side-by-side offloadingin offshore is affected more by metocean conditions than in nearshore orharbor. Generally metocean conditions in offshore are more severe than fornearshore or for a harbor, causing larger motions and interactions between theFLNG and the LNG carrier. The large motions and relative motions may exceed theworkable limits for side-by-side offloading systems such as loading arms, fenders and mooring lines. The factors mentioned above shall be taken intoconsideration for the evaluation of side-by-side offloading availability.
A Holistic Approach to Steady-State Heat Transfer From Partially and Fully Buried Pipelines
Authors: Zakarian Erich , Holbeach James , Morgan Julie Elizabeth P.
Published: April 2012

The mechanism of steady-state heat transfer from deeply buried pipes has beenrigorously modeled for a long time. Detailed analytical formulae have beenproposed recently for the calculation of the overall heat transfer coefficientacross the entire range of burial depths. This paper presents an evaluation ofthese formulae and suggests some improvements on the basis of numericalsimulations performed with high-fidelity Computational Fluid Dynamics (CFD)models.

Explicit formulae can quickly be implemented and used for generating profilesof overall heat transfer coefficient along pipelines. The effect ofuncertainties in input data on steady-state heat transfer can easily beassessed for any amount of burial. Four explicit, continuous formulae arepresented and compared to three independent sources of CFD analyses. A relativedifference of 10% or less with respect to CFD can be achieved with analyticalformulae for a comprehensive range of offshore pipeline systems, ambientconditions, soil thermal conductivities, and burial depths. The applicabilityof these formulae to onshore systems is also evaluated.

Introduction

Pipeline embedment into the seabed is a key consideration for offshore oil& gas developments with high temperature fluids. Inaccurate calculation ofthe overall heat transfer coefficient at the design stage of a project maysignificantly affect the integrity of pipelines and ancillary systems afterstart-up. For example, the overall heat transfer coefficient will beoverpredicted if the effect of pipeline embedment into the seabed is ignored. In the case of high temperature fluids this will result in hotter temperatureprofiles for longer. Such errors may cause issues such as uncontrolled pipelinebuckling; under design of cooling spools; accelerated degradation of externalcoatings; excessive corrosion rates; and unanticipated/excessive top of linecorrosion in wet gas pipelines

Two explicit, continuous formulae have been proposed recently to improve thedetermination of the overall heat transfer coefficient for partially and fullyburied pipes (Morud, 2007) (Ovuworie, 2010). This paper presents a detailedanalysis of these formulae with the support of high-fidelity CFD simulation. Two other analytical formulae are introduced and evaluated.

Theory

This section defines the overall heat transfer coefficient (OHTC) and presentsformulae for its calculation.
Maximizing the Benefit of Technology by Evaluation Qualification from Early R&D and Concept Stages of Development
Authors: Sillett Mike , De Naurois Herve J.
Published: April 2012

Introduction

Technology Evaluation Qualification is a systematic process for reducinguncertainty associated with new technology. Although frequently applied todrive the technology readiness level of the subject technology from the resultof a prototype onwards, there is a proven benefit to applying the discipline ofTechnology Evaluation Qualification from the earlier stages of R&D, Conceptand Proof of Concept. This paper discusses the tailored application of themethodology to these earlier stages of technology development. It explores anumber of examples and analyses the benefits which were derived.

Application

This tailored application of Technology Evaluation Qualification is applicableto all aspects of technology, but is especially valuable in the offshore areawhere today risks, costs and development time are very high. Severalmethodologies have now been applied in varying degrees by oil and gas majors, operating companies, and indeed the entire technology supply chain. Theimportance of improving the reduction of risk and uncertainties in an effectivefashion has been highly emphasized in the last year, and is requiring a widertransversal and collaborative effort by an increased number of parties, ascomplexity and difficulty of interfaces intensify, and thus this paper shouldbe of interest to a broad audience at OTC 2012.

Results, Observations and Conclusions

The results from a number of examples of its application are detailed. Theconclusion reached is that the offshore sector can benefit from an improvedprocess ensuring that from an earlier stage, before selection, lower risk andbetter performance will be delivered through a robust structured process ofTechnology Evaluation Qualification. This is true for both enhancing andenabling new technologies.

Significance of Subject Matter

The primary benefit from this process driving towards an early application ofTechnology Evaluation Qualification is the improvement in reduction in risksand uncertainties in the first application of a new technology. By identifyingthe risks earlier in the development cycle, more timely and cost effectivemitigation actions can be invoked. Application of this process within TotalOperator Company has fully demonstrated that improved identification of rootcauses of issues, lack of maturity, risks and uncertainties can be reached. Hence optimized actions can be undertaken to establish safe applicability, inthe sense that they more properly answer the real uncertainties, and then allowsafer new technology deployment, and result in earlier reliableapplicability.

In the emerging era of more rigorous regulation, an audit trail of riskevaluation throughout a technology's life, capturing both performance and HSErisks and associated mitigations will be of significant benefit.
Mobile Gas Lift Compressor and Well Unloading System for Enhancing Oil Production and Reserves, While Reducing Greenhouse Gas Emissions in Offshore Environments
Authors: Rexilius Jarrad Paul , Wamanon Tipparat , Sahni Akshay
Published: April 2012

The mobile offshore gas lift system discussed in this paper is a novel conceptcombining two production enhancement methods for oil wells which enables theunlocking of vast oil resources from offshore reservoirs. The system has beensuccessfully trialed in Benchamas Field, Gulf of Thailand (GoT), addingsignificant incremental production and reserves, while reducing greenhouse gasemissions from legacy ‘Well Unloading Units’ used in the field.

The innovative system, named WUUC, optimizes oil production by allowing wellsto be subject to very low backpressure at surface while also being gas liftedsimultaneously, using otherwise vented hydrocarbon gas.

The system incorporates a 3 phase separator and surge tank to separate fluidsfrom the production stream, with an inlet pressure as low as 30 psi. Liquidsare pumped back into the production pipeline at system pressure while the gasis captured in a 3 stage reciprocating compressor, compressed to approximately1100psi, and directed to a gas lift manifold which distributes the gas tomultiple wells for gas lifting.

A unique aspect of this system is its mobility. The entire system is modularand can be rigged up or down in a single 12 hour shift offshore, using standardplatform cranes. This enables the unit to service multiple wellhead platformsoffshore for maximum usage, supporting a low cost, pay-as-you-go rental modelfor the equipment. Its small footprint offshore allows flexibility to performwireline activities simultaneously while operating the unit, an importantbenefit in high activity operations such as Thailand.

The system began field testing in July 2009 on the ‘REX’ platform in BenchamasField, GoT. 2 MMscf/d of associated gas is captured from the production stream, compressed to high pressure and used to gas lift four oil wells (previouslyshut-in and depleted) on the remote platform, adding 2,000 bopd incrementaloil. The production results and system reliability have been outstanding. After2 ½ years of operation the unit has had 97% reliability and added over 900 Mstbof incremental oil. These are reserves which would otherwise have been leftunrecovered due to economic constraints of installing a conventional gas liftcompressor and/or electrical submersible pump (ESP) on the remote wellheadplatform.

In addition to these production gains, the system has prevented the release ofover 1.5 Bscf of greenhouse gas, which would otherwise have been vented toatmosphere, and utilized it instead for gas lifting application.

Due to its mobility, low risk pay-as-you go business model, and smallfootprint, the WUUC system has potential to be applied in multiple offshorelocations globally, adding significant oil production and reserves, whilereducing greenhouse gas emissions.
The Pazflor Adventure
Authors: Bon Louis
Published: April 2012

An adventure is something that is exciting and associated with the taking ofrisks. Pazflor project has certainly been an adventure and a huge capital andtechnological investment for Total.

The stakes were high with 65% of the production being a heavy viscous oil fromMiocene reservoirs using worlf first technologies, combined with thesimultaneous production of a lighter oil from a deeper Oligocene reservoir andover a very extensive development area.

Pazflor is a truly global project with a worldwide control organization and avery demanding schedule. The First Oil achieved on 24th of August 2011, onemonth before the initial planned date, showcased Total's ability to managehighly technological huge international projects.
Start-up of a Giant
Authors: Constant Arnaud , Ramat Lionel
Published: April 2012

The start-up of the Pazflor field required a response to three simultaneouschallenges:Start-up of a large complex facility, which involved the use of innovative 3Dvirtual reality training tools used to increase operator confidence and theavailability of Total Group previous experience.Flow assurance for two different reservoirs and oil qualities. First, theOligocene Field had light oil with high temperature, wax/corrosion issues, verylong subsea production loops. Second, the Miocene Fields had unconsolidatedsand, heavy viscous oil, emulsion and gas carry-over and Subsea SeparationUnits.Operating innovative Miocene subsea facilities, with gas/liquid separation onthe sea bed.

Introduction

The Pazflor development includes four reservoirs in Block 17 deep offshoreAngola, which produce to a Floating Production Storage Offloading unit throughone Oligocene subsea loop and three Miocene lines connected to subseaseparation units (SSU) and subsea pumps, with associated gas and waterinjection facilities (Fig. 1).

Classical challenges were faced by Field Operations teams for this type ofproject: performing various engineering studies and delivering spare parts, training production and maintenance personnel, and taking over an installationin safe condition with an adequate operational organization integrated into thepermanent organization.

Particular flow assurance challenges regarding high viscosity and " heavy" fluidissues together with unconsolidated reservoir formation had to be addressed, such as foaming, emulsion, deposit and sand management.

Finally, one of the major stakes was to be ready to face the new technicalchallenge of the Subsea Separation Unit, with a completely new operatingstrategy.

This paper reviews these various challenges, presenting Field Operationspreparation and organization used to meet them. It details main flow assuranceconcerns and innovative subsea facilities operations, and presents the mainachievements of the Pazflor field start-up.
Qualification of Composite Armor Materials for Unbonded Flexible Pipe
Authors: Kalman Mark Douglas , Yu Liang , Seymour Mike , Erni Juan
Published: April 2012

This paper presents the plan and execution of a comprehensive test program toqualify composite tensile and pressure armor materials for application inunbonded flexible pipe for deep and ultradeep water, high temperature andpressure production and high pressure injection service. Due to lighter weightand resistance to corrosion and fatigue, composite materials are beingimplemented for the pressure and tensile armor in unbonded flexible pipe. Amaterial qualification program is necessary to define material properties thatare used in design and to assure that the materials will meet performancerequirements over the service life. The material qualification testing programpresented in this paper can also be used as a model for other compositematerial qualification programs for offshore applications.

The qualification test program was developed based on the design of thepressure and tensile armor layers, and a comprehensive evaluation of thepotential failure modes and associated failure mechanisms associated with theapplication of composite armor materials for the layers. The materialqualification program was developed based on the guidelines presented inDNV-OS-C501 Offshore Standard for Composite Components. Since compositematerials are anisotropic, material properties in the principal directionsneeded for analysis, and how these properties vary with time as a result of theloads and environments experienced over the service life are evaluated. Thematerial qualification requirements have been agreed by members of the flexiblepipe technical community and are being published in Draft InternationalStandard API 17J/ISO 13628-11 as Annex H. This paper summarizes therequirements and presents one manufacturer's initial work to qualify bothfiberglass and carbon fiber based composite armor materials for the pressureand tensile armor layers in unbonded flexible pipe.

Introduction

The advantages of replacing the metallic pressure and tensile armor of unbondedflexible pipe, with fiber reinforced polymer (FRP) materials, or compositearmor, have been known for many years. References [1], [2], [3] and [4]summarize efforts over more than 20 years to use FRP materials for tensilearmor in unbonded flexible pipe. In summary, with proper material selection, design and manufacture, the advantages of composite armor include:Higher strength to weight ratio, resulting in a lighter weight pipestructure for equivalent structural capacityImproved fatigue resistanceResistance to corrosion and degradation by most oilfield chemicals andseawater

In particular, the higher strength to weight ratio enables lower top tensionriser configurations without adding substantial buoyancy, enabling installationand operation from smaller vessels, resulting in lower installed cost risersystems. The advantages increase substantially for ultradeep water risersystems [5].
Field Implementation of New Electrostatic Treating Technology
Authors: Walsh John Michael , Sams Gary Wayne , Lee Joseph M.
Published: April 2012

Mars is an offshore drilling and production platform operating in the deepwaterregion of the Mississippi Canyon area in the Gulf of Mexico. It startedproduction in 1996 with a design basis of 140,000 BOPD. In 2003 at the start ofthe work reported here, Mars was producing an average of 200,000 barrels of oilper day. While the platform had undergone a number of expansions, many processunits, including the Bulk Oil Treater were operating above the design capacity. Due to the high throughput and therefore short residence times, the platformwas experiencing oil dehydration problems, and a high rate of demulsifier wasrequired to meet the oil discharge dehydration target of 1.0 % BS&W.

The original Mars electrostatic treater was a conventional design involving aserpentine perforated pipe distributor, steel electrostatic rods, conventionalAC electrostatic treating technology and a perforated pipe collection header. During the hurricane Katrina shutdown (late 2005/early 2006), the Mars Bulk OilTreater was upgraded to composite grids, Dual Frequency® AC/DC electrostatictreating technology and a Hi-FloTM pipe / deflector spreader. After theupgrade, a significant savings in demulsifier cost was realized. This paperdiscusses how the new electrostatic treating technology was used to reducetreating chemical cost and improve throughput. Additionally, comparison ofdifferent crude dehydration technologies is discussed.

Introduction

When a field reaches its maximum production rates, mechanical separationcapacity is often exceeded. For deepwater platforms, separation residence timeis typically short due to the high cost of space and weight. Topsidesseparation problems can be costly, particularly when production must bedeferred to meet oil or water quality specifications (BS&W and oil in waterconcentration).

The work reported here was carried out in 2003 through early 2006. It wascarried out in two phases. In 2003 and early 2004, the platform was operatingat historically high production rates. Oil production averaged 200,000 BPD. Dehydration problems were addressed by adding more heat, improving the chemicalapplication, and improving the operating procedures. In addition, the option toupgrade the Bulk Oil Treater vessel internals was evaluated during this timeperiod. This was the first phase of the work during which the platform wasoperating at high production rates.
High-Pressure/High-Temperature Sensor Development and Qualification
Authors: Hall James E.
Published: April 2012

This paper describes work required to achieve the goal of identifying anddeveloping the sensors that will be required for accurate flow measurement forextreme (high-pressure, high temperature, or HP/HT) subsea productionapplications. Ideally, these sensors should be available for use by metermanufacturers from normal commercial channels. However, due to small numbers ofthese specialized sensors required for the offshore subsea market, the neededtechnology has not been pursued for development through commercial-onlychannels.

The key element needed is a combination pressure-differential pressure (P-DP)sensor that can be used at pressures and temperatures that are far higher thanmost standard conditions. The primary benefit from this work is the ability toreliably measure flow in these crucially important HP/HT fields, thuspermitting accurate accounting of revenue streams from production and royaltyallocation, improved recovery resulting from more accurate reservoir modeling, and (in the future) better measurement during drilling as well as productionoperations.

Since an HP/HT P-DP subsea sensor was not available at the start of theproject, the team, with the support of and guidance from several majoroperators, concentrated on overcoming numerous technical challenges encounteredin the development of this unique sensor. How these challenges were resolvedwill be discussed, and the performance data for the resulting device, will bepresented.

Introduction

Subsea multiphase flowmeters are increasingly being used as production hasincreased in the Gulf of Mexico as well as other locations around the world. Most of the currently installed subsea multiphase and wet-gas flow meters arelimited to measurement of production fluids at a maximum temperature of 125°Cand operating pressures of 10,000 psig. Improvements are required in the designof the mechanical components of the meters to allow qualification foroperational pressures up to 15,000 psig. For operation at that pressure, theflow meter must be tested at 22,500 psig. The temperature limitation is relatedto the sensors that measure the produced fluids.

Ultra deep and long tie-back systems may require subsea HP/HT multiphasemetering system for well test and allocation measurement instead of using atest flow line. Three types of measurement are needed in this environment:temperature, pressure, and differential pressure. These HPHT sensors, alongwith accurate flow measurement, could provide the basis for accurate revenueand royal allocation, as well as improved reservoir management.

This project was launched as part of the RPSEA Project 07121-1301: Improvementsto Deepwater Subsea Measurement with the realization that this sensor market issmall and the needed HP/HT sensors might not be developed through acommercial-only approach. Thus, this project focused on qualifying and/ordeveloping sensors for the HP/HT environment:Temperature (production fluids) = 250°CPressure (production fluids) > 15K psigWater depth >3K meters (4.3K psig)
SME Special Session: Subsea Slurry Lift Pump Technology - SMS Development
Authors: Leach Stuart , Smith Glen , Berndt Roland
Published: April 2012

Nautilus Minerals', the world's leader in exploration and development of deepocean seafloor resources, has located a number of Seafloor Massive Sulphide(SMS) deposits in the Bismarck Sea, within the Territorial Waters of Papua NewGuinea. Nautilus' business model is based on the notion of ongoing resourceaccumulation and aggregating numerous high grade SMS systems and tosequentially develop them using a floating production system.

Nautilus' project development plans are based on utilizing and / or adaptingexisting technologies from a number of different industries. The offshore oiland gas industry in particular has been a primary source of equipment andtechnology and it is from this industry that Nautilus is procuring a SubseaSlurry Lift Pump (SSLP) to pump slurry from the seafloor to its surfaceproduction vessel.

The SSLP under procurement is a 10 chamber positive displacement lift pump. Thepump technology was originally developed to pump drill fluids and cuttings indual gradient drilling of deepwater offshore oil and gas reservoirs. Byallowing the pump's discharge pressure to adjust to changes in the slurry(Viscosity, Density & Solids Concentration), the positive displacement pumpaccommodates variations in flow conditions to remain within its operatingenvelope. The SSLP has a number of direct technical and operational synergiesthat make it ideally suited for application in the SMS productionindustry.

This paper provides an overview of the SSLP design and its suitability for theseafloor mineral production industry and also explores alternate slurry pump orlift technologies suited to this new and developing industry.
Feasibility of TLP with Tender Assisted Drilling for Northwest Australian Waters - A Case Study
Authors: Xia Jinzhu , Taghipour Reza
Published: April 2012

The objective of the work is to assess the feasibility of a tension legplatform (TLP) dry tree unit (DTU) with tender-assisted drilling (TAD) for theharsh metocean conditions offshore North West Australia, characterized by theoccurrence of tropical cyclones and persistent swells. Making use of thedrilling tender vessel's accommodation, power generation, mud pumping, cleaningand storage facilities etc. can reduce the production platform topsides weightby up to 3,000 tonnes. Such weight and associated cost savings could becomeenablers for some of the deepwater gas field developments offshore WesternAustralia.

A TLP configuration is evaluated as the DTU in a water depth of 500 m. The TLPis sized for a specific payload for gas production. A typical 6-columnsemisubmersible is configured as the drilling tender vessel (DTV), for which apreliminary TAD mooring system is defined. Hydrodynamic models for the combinedDTU/DTV systems are developed and used to perform extreme response andoperability analyses.

The coupled TLP/DTV TAD system is analyzed in 1, 10 and 100-year return periodenvironments. It is shown that the DTU and DTV vessel can be safely mooredtogether by hawsers without collision in up to 10-year return cyclonic stormevents. This means that the mooring system operability of up to 99.97% isachievable.

In environmental conditions harsher than 10-year return cyclonic storms, theDTV will be disconnected from the DTU and a full 8-point mooring pattern willbe required to moor the DTV to survive up to 100-year return periodcyclones.

Introduction

For deepwater gas field development offshore Western Australia, dry treefloating production combined with land-based liquefaction will be one of theviable field development solutions. Subject to reservoir geometry, dry treecompletion offers several advantages comparing to a wet tree solutionincluding:–Reduced drilling cost relative to a MODU,–Easy and economical well intervention,–Increased recoverable reserves,–Simple flow assurance, and–Simple well control systems.

One of the significant challenges for this field development concept is theincreased payload and functional requirements for facilitating drilling on theproduction platform. For deep water development this challenge is even morepronounced since the increased topside capacity will significantly increaseplatform capital cost. Therefore, many of today's deep water hydrocarbonreservoirs have been developed with subsea solutions. A solution to thechallenge is tender assisted drilling, which reduces the payload and functionalrequirements on the production platform and therefore makes the dry completionmore competitive (Botker et al, 2001).
Flow Assurance for Deep Ocean Mining: Large-Scale Experiment for Flow Correlation Validation and Abrasion Testing
Authors: Parenteau Thomas
Published: April 2012

The flow assurance aspects of all subsea projects have a major contribution tothe pipe design, field layout, choice of lifting equipment (subsea-pump or airlift), power requirement and system operability. The context of deepwatermining pushes the design theories beyond the existing application cases due tothe significantly larger particle size combined with small diameter riser andjumper including wave shape to accommodate vessel motions and excursionrequirements. In order to correctly assess pressure drop and erosion rate closeto real flow conditions, TECHNIP and GIW have built a large scale experimentalbench operated at the same flow condition as forecasted for the deepseaproject. This large scale test is using an innovative method to allow thereproduction of realistic erosion rate in the pipe by preventing the solidparticle to be eroded when looping through the pump.

The current paper summarizes the findings and results from this large scaleexperimental set-up, testing concentration from 10% to 45%, velocities from2.5m/s to 5.5m/s in an 8" flexible pipe with equivalent rocks particles.

INTRODUCTION

As described in (Espinasse, 2010), Technip is supporting an internal R&Dprogram that should allow the understanding of critical parameters essential tothe design and operability of a subsea mining system. Within this R&Dprogram, an extensive study of the abrasion and erosion mechanism inside theflowline is needed to:Understand the inner pipe wear mechanism function of flow conditionsDefine the proper flowline pipe material providing the best compromisebetween wear resistance and pipe cost.Define a procedure to evaluate the lifetime duration of the flowline pipeduring operations to schedule inspection and maintenance.

To capture and understand the abrasion during subsea mining operations, Techniphas setted-up a full scale test with the help of GIW. In addition of tacklingflowline wear issues, this test is used to validate at large scale thehydraulic modeling exposed in (Parenteau, 2010) and (Parenteau, 2011).

STATE OF THE ART

The particularity of subsea mining is to transport large and dense particle inrather small diameter pipe compared to what the industry of slurry transport isused to. Subsea Mining Partcicle size disctribution can range from 1 mm to60mm. Crushing experience conducted in (B. Waquet, 2011) indicated that atleast 50% will exceed 25mm and more than 25% of the solid will exceed 50mm[Figure 1]. The particle densities range from 2500 kg/m3 up to 4000 kg/m3. Pipediameter will range between 8" to 10", and evolving into wavy shapes.
Design Issues and Trends for the New Generation of Offshore Support Vessels
Authors: Sano Mike , Huang Wei , Penfold Mark , Ozaki Yoshi , He Charles , Leszczynski Mariusz
Published: April 2012

The new generation of offshore support vessels (OSVs) has become increasinglysophisticated and technically advanced in response to demands from deepwaterdrilling and production operations. This paper reviews design issues and trendsfor the development of the next generation of OSVs, highlighting recentlyenhanced classification technical requirements. The new requirements addresssafety criteria and environmental protection for the design, construction andoperation of OSVs.

The paper also includes applicable criteria and new notations for eachspecialized service of the OSV including transportation of supplies andequipment, towing and anchoring of offshore structures, well stimulation andtesting, fire fighting, heavy lift, oil spill containment, pipelineinstallation, diving activities and safety stand-by as well as provisions forthe integration of multifunctional services.

Additionally, the paper addresses the use of LNG as a fuel for propulsionprimarily to reduce emissions.

Introduction

Over the years, Offshore Support Vessels (OSVs) have evolved dramatically asshown in Table 1 in terms of diversification, worldwide operation and waterdepth capabilities. This evolution of technology advancement has been driven bythe need to meet the ever-increasing support demands of deepwater drilling, production and subsea operations.