bluuebunny/crossref_metadata_2025_split huggingface dataset:
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

ABSTRACT
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

Abstract
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

Abstract

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

Abstract
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

Abstract
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.