bluuebunny/crossref_metadata_2025_split huggingface dataset:
Frontier Subsea Technologies
Authors: Poincheval Alain , Gleize Philippe 
Published: April 2012

Abstract
Technip and Subsea 7 Consortium, acting as a contractor to Total, operator ofthe Pazflor project, made a challenging oil field development a reality anddemonstrated their ability to deliver a complex SURF project, maintaining aworld class HSE performance and pushing the frontier of subsea technologieswith focused innovation. Among the several key challenges, the necessity tohandle two different oil characteristics led to two distinct subseaarchitectures. First, the Oligocene with a high constraint on thermalefficiency for such a large field footprint made Pipe-In-Pipe (PIP) flowlineand Integrated Production Bundle (IPB) flexible riser essential. Developed byTechnip from design to installation, the reeled, rigid Pipe-In-Pipe andflexible pipe IPB are ideally adapted for these flow assurance challenges. Second, the Miocene with heavy and viscous oil characteristics led to thedevelopment of a Subsea Separator Unit (SSU) where Subsea 7 demonstrated itsability to install safely heavy modules in 1000m depth with high positioningaccuracy. Finally, with the first implementation of the patented diverlessrisers automatic hook-up system to FPSO, Technip and the Consortium's leadingedge technology was further demonstrated on Pazflor, successfully enablingsafer and faster handover for first oil.

1. INTRODUCTION
Pazflor's demanding flow assurance and associated thermal performance of thesubsea production transport system of light paraffinic oil (Oligocene) requiredthe use of challenging technologies among which Pipe-In-Pipe associated with anIntegrated Production Bundle flexible riser has proven itself to be the optimumsolution and is further detailed in the following sections.
Furthermore, maintaining a world class HSE performance and pushing the frontierof subsea technologies with focused innovation led to the development and theuse of a diverless riser automatic hook-up system to the FPSO, avoiding diverintervention and hence disconnecting weather conditions from riser pull-in (HU)operations.
In addition, with the Miocene field, Total achieved a number of world firstsfor the Subsea Separation system with first vertical separation system, firsthybrid pump technology and first separation system to be implemented on fieldstart-up in 800m water depth. This section aims to give an overview of theinstallation of the Subsea Separator system, from preliminary testing in Norwayto final pre-commissioning at offshore site.
Finally, the integrated Consortium between Technip and Subsea 7 showed its fullefficiency during the management of simultaneous complex installationoperations involving a large number of vessels together with a comprehensivedrilling campaign.
New Developments in Wet Gas Metering To Meet Offshore Challenges
Authors: Gregerson Svein Erik , Risdal Martin 
Published: April 2012

Abstract
This paper presents an overview of wet gas multiphase metering and a new meterdesign to meet future offshore challenges. The design introduces new microwaveelectronics, transmission as well as resonance measurements, a salinitymeasurement system, reduced PVT dependence and a new HP/HT design.
Building on the success of wet gas metering in accuracy and reliability, thenew meter increases operators' ability to detect the onset of formation waterproduction and accurately measure flow rates where an increasing amount ofliquid and water is present in the flow (due to gas wells produced over a widerrange of process conditions).
The new meter design will have an increased importance for subsea tiebacksapplications. While today's wet gas meters are well suited for subsea tiebacks, current subsea developments require longer horizontal production pipelines, where accurate and sensitive measurement of water is crucial to ensure flowassurance and maintain maximum production capacity of the pipeline.
Furthermore, the restrictive and remote nature of subsea fields means that thecosts for subsea interventions and periodic fluid sampling (PVT) are high. Thenew meter is more robust to changes in PVT (fluid composition) and reduces theneed for frequent fluid sampling.
The paper will describe the development and technology choices of the newinstrument and how it will meet future subsea field demands.
It will explain how the new microwave electronics provides more stable andaccurate measurements; how transmission and resonance measurements extend theoperating range to 80–100% GVF and 0–100% WLR; how two complementarytechnologies - a salinity probe for liquid film measurements at low GVF andFormation Water Detection Function software for droplets measurements at highGVF, provide the first complete salinity measurement system in wet gasapplications.
The paper will also show how multivariate analysis and new measurements enablethe meter to compensate automatically for changes in produced fluidcomposition.
The paper will be highly significant to oil and gas operators looking toincrease flow assurance and oil & gas production from wet gas fields andmeet the growing offshore challenges of varying process conditions, intervention costs, and subsea tie-backs.
Designing the World's Deepest Offshore Well to Drill and Core the Earth's Mantle
Authors: Pilisi Nicolas , Whitney Bill , Kawamura Yoshi 
Published: April 2012

Abstract
Because many fundamental questions concerning the dynamics of the Earth and itsstructure remain unanswered, the Integrated Ocean Drilling Program (IODP) hasrecently completed a feasibility study for drilling and coring a hole 500meters (1,640 feet) through the Mohorovicic seismic discontinuity into theupper mantle of the oceanic crust from three candidate locations in the PacificOcean (Cocos Plate, Baja California, and offshore Hawaii).
The main challenges discussed in this paper are threefold. First, drilling withriser in ultra-deepwater environments with water depths around 4,000 meters(13,120 feet) which will set a new world record. Secondly, drilling and coringin very high temperature igneous rocks with bottom-hole temperatures that areestimated to be as high as 250°C (480°F). Finally, drilling and coring a verydeep hole with a total drilled and/or cored interval around 6,000 meters(19,685 feet) in the oceanic crust below the Pacific Ocean seafloor in order toreach the upper mantle which will constitute a major achievement for theworldwide scientific community.
This paper presents detailed analyses and several discussions concerning marinedrilling riser options by first reviewing the capabilities of the current riserconfiguration that is onboard the IODP scientific drilling drill-ship Chikyuand then evaluating alternative designs such as titanium riser, hybridtitanium-steel riser, slim-riser and lighter buoyancy modules. Furthermore, thedeepwater subsea equipment, drill-pipe design, wellbore design, down-holetools, drilling fluids, circulating temperature, cementing methods and variousadvanced technologies that would be required for this type of operation arealso reviewed. In addition, operational time and cost estimations for differentscientific drilling cases are provided (borehole continuously cored to totaldepth, continuous cores only across the major lithologic and geophysicaltransition intervals, spot coring and when only the mantle section iscored).
Finally, this study helps evaluate critical issues in terms of current andtrending technologies in oilfield and geothermal industries that need to beresolved before embarking upon such a challenging project. The results of thiswork show that drilling to the mantle is certainly feasible, and that there areexisting solutions to many of the technological challenges based on work beingdone in the oilfield, offshore and geothermal industries.
Considerations and Lessons Learned on Development of Gas-Lift Paraffin Inhibitors for Subsea Wells in the Gulf of Mexico
Authors: Wylde Jonathan James , Slayer Jubal 
Published: April 2012

Abstract
This paper details the laboratory evaluation and product development for auniquely applied gas-lift paraffin inhibitor. Several crude oils, specific toone particular Gulf of Mexico subsea network, were characterized with respectto cloud point, pour point and paraffin content. This information was used todetermine suitable wax inhibitors to test for application into the productionfluids offshore. Cold finger wax deposition tests were performed to evaluateeight different inhibitor chemistries.
Details are given on the test methodologies used, with particular focus on thespecific evaluation to determine gas-lift suitability. Volatile flash analysiswas performed by a third party laboratory, coupled with a unique dynamicgas-lift test method, to find a suitable candidate. Of the products tested, twonew and specific formulations were developed for gas-lift applications thatdisplayed low weight loss and very little increase in viscosity.
There is very little documented in open literature on the formulations and testmethodologies employed to evaluate paraffin inhibitors for gas-liftapplication. This paper describes the most important treatment parameters anddetails on how gas-lift application was performed. This includes somesignificant learning lessons on the design and implementation of gas-liftparaffin inhibitors, as well as conclusions regarding the most appropriatedeployment parameters to avoid gunking and clogging of injection systems. Italso details the specific chemistries that can and should be used for this typeof application.

Introduction
Paraffin Deposition from Crude Oil
Crude oils naturally contain paraffinic, waxy components, defined as aliphatichydrocarbon molecules with the empirical formula CnH2n+2 (n is most commonly&gt;18).
Paraffin can exist in three forms:Macrocrystalline: these tend to be dominated by straight chained n-alkanesand are classically defined by paraffin deposits found in subsea and exportpipelines.Semi-microcrystalline: this is an intermediate form of macro- andmicrocrystalline paraffin.Microcrystalline: these tend to be cycloalkanes and branched alkanes oftenassociated with asphaltenes and other solid deposits. These are normallyencountered in tank bottoms as a sludge-like deposit.
Paraffin precipitation increases the viscosity of crude oil creating higherdrag and pressure. Deposition on the walls of tubulars, flowlines and pipelinescan increase surface roughness and create a higher differential pressure. Physical restriction of the pipeline can also occur, creating less flow orincreased energy costs to maintain flow.
A Long-term Monitoring Array for Landslide Precursors: A Case Study at the Ligurian Slope (Western Mediterranean Sea)
Authors: Stegmann Sylvia , Sultan Nabil , Garziglia Sebastien , Pelleau Pascal , Apprioual Ronan , Kopf Achim , Zabel Matthias 
Published: April 2012

Abstract
The Nice Slope, situated in the French part of the Ligurian Margin, representsa landslide-prone area, where different factors favour slope instability:Seismicity up to ~M6,rapid sediment deposition in the Var fluvial system,groundwater discharge along the coastal aquifer,creeping ofsensitive clay layers, andhuman activity (land reclamation, construction). In 1979, a catastrophic failure occurred in the Var pro-delta, that destroyedthe Nice new harbour extension, mobilised ~8.7×106 m3 material, and initiated atsunami wave of 2–3m. This event led extensive research efforts first directedat understanding the triggers of the failure. In later years, some furtherstudies allowed to detect the occurrence of mechanically weak sediments outsidethe area that failed in 1979. This, along with the detection of freshened porewater and excess pore pressure development raised concerns as to the presentday and future slope stability.
Hence, at present, progressive weakening of the shallow sediment is monitoredusing a long-term array in collaboration between Ifremer Brest and MARUMBremen. It comprises two multi-level pore pressure probes (Ifremer piezometers, one installed in the 1979 scar, one in the unaffected slope further E) as wellas a tilt-meter instrument (Ifremer) that will observe the deformation rate ofthe upper 8 m of sediment in real-time. In addition, an osmotically drivenfluid sampling-lance (MARUM) collects pore fluids for geochemical studies atthe levels of the pore pressure ports of the piezometers to identifyground-water discharge. With temporary OBS installations and onshoreseismometers in place, the array will allow us to distinguish between thevarious factors that are presently affecting the stability of the NiceSlope.
The Modelbase: An Architecture for Organizational Adaptive Decision-Making
Authors: Whiteside Michael William 
Published: April 2012

Abstract
This paper describes the application of the modelbase, newly developed softwarearchitecture for adaptive forward-looking processes, for organizationalstrategic management and complex project design and decision-making underconditions of uncertainty and change in the offshore oil and gas industry. Themodelbase is designed to maintain a live model of the organization againstwhich new opportunities and alternative designs can be tested and adapted asnew information is obtained.
The technology described has potentially wide application across the industrybut particularly in the following areas:Enterprise Strategic Decision-MakingAdaptive Development Strategic Design and ManagementEnterprise Knowledge-Sharing and re-use
The paper show that the application of the techniques embedded in themodelbase, enable the organization to obtain a collective understanding of thefuture challenges and uncertainties facing the business, and this leads to bothbetter and more adaptive decision-making which in turn increases the " strategicproductivity" of the organization and significantly adds to the organizationalwide value created by new developments, exploration and research.
The methods described in the paper have significance to the industry in thefollowing areas:New methods for managing models, collaborative model building and knowledgesharingMethods for adaptive organizational, development and infrastructuredesignActive learning and dynamic optimization of the E&P process fromexploration through to production

Introduction
The oil industry, like other industries has to date focused its performancemanagement initiatives on operational efficiency and short-term tacticaldecision-making. The methods used for long-term decision-making underuncertainty that decide the strategic investment in exploration, innovation andcapital projects, the industry's engines of growth, are largely based on thosedeveloped by Hertz1 for general project evaluation and by Newendorp2 and othersfor specific problems in the oil industry in the 1960's and 1970's. WhenNewendorp did his work, most of the analysis was intended to be performed byhand with aid of scientific calculators.
Since that time the power of the personal computer / workstation has grown byapproximately one half a million times, we can now perform analyses in secondson a laptop computer that were inconceivable in the 1970's on the most powerfulmainframe. Cloud and Multi-core architectures extend this capability massivelyand the available power continues to expand exponentially, the oil industry isone of the largest users of such systems. This power enables the ability to runenterprise-wide simulations and investigate literally millions of alternativestrategies with embedded options, under different conditions of uncertainty andto run this on demand as new opportunities or external events dictate.
A Challenging Mating Operation Between VLCC Class FPSO and Soft Yoke Mooring System in Extremely Shallow Water
Authors: Wang Alan Minglun , Yuan Ruhua , Zhu Shaohua , Li Huailiang , Xie Weiwei , He Min 
Published: April 2012

Abstract
A VLCC class FPSO has been successfully hooked up to a pre-installed rotationalSoft Yoke Mooring System (SYMS) located in extremely shallow water of 27.6meters, where the rotational SYMS is situated on the top of a jacketsubstructure. The extremely challenging mating operation is mainly due to theimmediately contiguous FPSO and SYMS, which are located in the close vicinitywith a net clearance less than 12 meters and the high-risk vessel maneuveringin a confined space between the two yoke arms.
The FPSO-SYMS mating operation was performed in March 2009, which coversvarious installation phases. Upon FPSO handover at the field, the three towingtugs are reconfigured into positioning tugs while two additional tugs areconnected to the FPSO. After an on-site positioning trial is performed, thepositioning spread moves the FPSO extremely cautiously approaching towards theSYMS to engage the lower ends of the pendulums into the uni-joint forks on thetop of the floating yoke arms supported on the temporary buoyancy pontoons. Thevessel is aligned to the yokes with the help of the positioning spread whilemaintaining heading towards the prevailing weather. The FPSO is moored to theturntable on the SYMS tower with four substantial Dyneema ropes cross-connectedwith a master link in the middle before any attempt at connecting the pendulumsto the SYMS is made. The positioning spread maintains the vessel steady so thatthe mating can be done by connecting the yoke arms to the pendulums. Theballast tanks of the yoke arms are ballasted with concrete slurry while theanti-yaw tanks are filled with fresh water mixed with anti-corrosion inhibitorand anti freeze. Only after the ballasting is finished, the FPSO is consideredstorm-safe and can the positioning spread be released.
This paper gives a comprehensive description of the FPSO-SYMS matingoperations, as well as how to successfully apply the findings of model testsand virtual simulations to the different installation phases. This enables theFPSO to be hooked up as rapidly as possible co-incident with safe practice. Lessons learned from the offshore operations are also addressed.

Introduction
The VLCC class FPSO "Hai Yang Shi You 117" is located at the Penglai 19-3 fieldin the northern Chinese waters to the southeast of the Bohai Bay, close toBohai Straits. The field development includes a rotational SYMS installed onthe top of a jacket substructure and a VLCC class FPSO to be connected with theSYMS via two pairs of yokes and pendulums, as well as six wellhead platformsand one central riser/utilities platform linked with six subsea pipelines andsix submarine cables. The water depth is approximately 27.6 meters while theenvironment is relatively benign and multidirectional. Refer to Fig. 1 for athree-dimensional illustration of the FPSO and SYMS system upon mating.
Improvements to Deepwater Subsea Measurements RPSEA Program: Evaluation of Flow Modelling
Authors: Toskey Eric D. 
Published: April 2012

Abstract
This report documents a project to improve subsea flow measurements to allowthe flow rates of individual wells to be known more accurately. Becauseproduction revenues are determined from flow rates, improved flow measurementreduces the financial risk to stakeholders, including producers and the U.S.government. Improved measurement also helps to improve reservoir recovery. Inthis project, commercially available flow models were evaluated for theirsuitability as virtual flow meters, to augment or replace hardware devices forthe determination of flow rates in deep water wells. The goal of this projectwas to develop methods for evaluating flow models, and to report on theefficacy of these models to predict flow rates. Several flow models were usedin the study, which also includes a survey of the available models.

1. Introduction

1.1. What is a Virtual Flow Meter?
Virtual flow meters (VFM) are a method for determining the flow rate of a wellby means of modeling the flow. A VFM model may consist of a single well to anentire field of co-mingled wells. The models are fed data from sensorsinstalled at various measurement points (nodes). Typically pressure andtemperature sensors are used, which are available downhole (perhaps at multiplepoints), at the wellhead, and at the surface. With the pressure and temperaturedata at each node provided as an input, the VFM model computes the flow rate ofthe well. Typically, the model is tuned periodically using available flow data. Once tuned, the model is capable of determining the well flow rate with onlythe pressure and temperature nodal data. The flow models employed with VFMsystems may be built from first principles, but this is not the only method forVFM modeling. Flow models may also be derived from statistical analysis ofmeasurements acquired at different nodes along the production system.
An important observation is that VFM software is not something that must beinstalled at the same time as the physical multiphase flow meters, as long ascare is taken to install proper sensors to be used at the various nodes. Thefault tolerant nature of the VFM system is an advantage, since a failed "hard"sensor will reduce the number of nodes, but will not cause a complete loss ofinformation.
While VFM technology appears to be maturing rapidly, it is not yet generallyaccepted an equivalent replacement for good physical metering. VFM models areemployed as a back up to a physical meter to be used in case the primarymetering system is unable to function, or as an augmentation of physicalmetering to reduce measurement uncertainty.
Some of the commercial VFMs use the technique of Nodal Analysis for the flowrate prediction. This method utilizes available transmitters (pressure andtemperature) and a mathematical model of the complete flow path from bottomhole to the topside facility. This method requires considerable input data, including well and pipeline profiles, the diameters of all components ofsections, sensor locations, fluid properties, choke geometry, etc.