bluuebunny/crossref_metadata_2025_split huggingface dataset:
Le dispositif de soin psychique à domicile : une mise en travail du figé
Authors: Blanquet Brigitte , Benoit Sara 
Published: October 2015

Le soin à domicile constitue un nouveau paradigme pour des sujets en situation de vulnérabilité psychique. Le psychiste y « délocalise » sa pratique en prenant en considération les éléments concrets du décor et l’ambiance in vivo , comme outils de compréhension favorisant ainsi la figuration des pannes inscrites sur les murs. Le décor familial est porteur des traces de l’histoire familiale traumatique et vient immobiliser la pulsion de mort. Ce travail à domicile sollicite de façon privilégiée la sensorialité et la communication primitive. Il permet au clinicien de mettre en travail les éléments figés et les solutions post-traumatiques que ces sujets ont mis en place pour survivre.
Raël, fils de Yahvé et messager des Elohim : les soubassements délirants d’une secte « ufologique »
Authors: Lamote Thierry 
Published: October 2015

La réflexion sur les phénomènes « sectaires », généralement organisée autour de quelques notions qui présupposent le charlatanisme et l’escroquerie, échoue à saisir aussi bien les logiques qui animent ces mouvements que les questions qu’ils soulèvent quant à l’état du lien social dans nos démocraties libérales. Ce sont ces logiques que nous tenterons de discerner dans les linéaments du système délirant édifié par Claude Vorilhon, le leader du groupe. Nous découvrirons alors que ce mouvement, né d’un délire paranoïaque et situé à la croisée de la technoscience et du néolibéralisme, est en parfaite conformité avec les valeurs qui sous-tendent notre époque postmoderne.
New early Eocene Siricomorpha (Hymenoptera: Symphyta: Pamphiliidae, Siricidae, Cephidae) from the Okanagan Highlands, western North America
Authors: Bruce Archibald S. , Rasnitsyn Alexandr P. 
Published: October 2015

AbstractWe describe three new genera and four new species (three named) of siricomorph sawflies (Hymenoptera: Symphyta) from the Ypresian (early Eocene) Okanagan Highlands: Pamphiliidae,Ulteramus republicensisnew genus, new speciesfrom Republic, Washington, United States of America; Siricidae,Ypresiosirex orthosemosnew genus, new speciesfrom McAbee, British Columbia, Canada; and Cephidae,Cuspilongus cachecreekensisnew genus, new speciesfrom McAbee and another cephid treated as Cephinae species A from Horsefly River, British Columbia, Canada. These are the only currently established occurrences of any siricomorph family in the Ypresian. We treat the undescribed new siricoid from the Cretaceous Crato Formation of Brazil as belonging to the Pseudosiricidae, not Siricidae, and agree with various authors that the YpresianMegapterites mirabilisCockerell is an ant (Hymenoptera: Formicidae). The Miocene speciesCephites oeningensisHeer andC. fragilisHeer, assigned to the Cephidae over a century and a half ago, are also ants. Many of the host plants that siricomporphs feed upon today first appeared in the Eocene, a number of these in the Okanagan Highlands in particular. The Okanagan Highlands sites where these wasps were found also had upper microthermal mean annual temperatures as are overwhelmingly preferred by most modern siricomorphs, but were uncommon in the globally warm Ypresian, only found then in higher elevations and highest latitudes.
Subsea Separation Behavior of a Brazilian Crude Oil: Experiment and Simulation
Authors: Noik C. , Muller S. , Karnitz O. , Ramalho J. , Steinhauser A. P. , Grave E. 
Published: October 2015

Increasing confidence and efficiency of process unit are major challenges for subsea field development. In such conditions, subsea liquid-liquid separation is still an important issue. Moreover, related to water depth, only compact separators with short residence times can be installed. The key point developed in this paper is to evaluate the water-oil separation regarding the oil properties including the effect of gas. A joint Industrial Program was performed in IFPEN on water separation efficiency in collaboration with Petrobras and ExxonMobil.Experiment and numerical analysis of tests were performed on a facility platform. The GOwSP platform used is an industrial test facility designed to research and to test multiphase equipments. The closed loop is under pressure and temperature control to simulate real operating conditions. The material used is a crude oil supplied by Petrobras, synthetic brine and natural gas. The tests were performed in a horizontal separator unit implemented with specific instrumentation such as interface profiler gauge. The separation efficiency is calculated from flow mass balance. Various operating conditions were studied such as; gas and liquid flow rates, water fraction, temperature, pressure. Special attention was taken on pressure effect and gas/oil ratio.Thus, a 1D model previously developed was used for tests simulation in order to predict the separation efficiency as a function of the operating production conditions. The 1D-model is based on an "experiment-modeling" methodology. The model is developed based on physical laws describing emulsion destabilization under only gravity effect and then it is extrapolated in case of fluid flows. Simulations shown a good accordance with experiment results. Whatever the conditions, most of simulation of the separation efficiency are within a 20% relative error margin. Classical behaviour of separation efficiency increase with oil residence time and temperature is confirmed as a decrease with initial water content increase. Simulations permitted to underline the important influence of oil characteristics viscosity, density on separation efficiency. At tested operating conditions, the gas had a slight influence on oil/water separation.
Flow of Complex Fluids Through Porous Media: Application in Oil Recovery
Authors: Carvalho M. S. 
Published: October 2015

The most common oil recovery method used for displacing oil and maintaining the reservoir pressure is water injection. However, in most cases, the recovery efficiency of this method is limited by the high fluid mobility ratio and reservoir heterogeneities that limit the macroscopic efficiency of reservoir sweep and pore scale oil displacement.
The non-linear flow behavior of complex fluids through porous media gives rise to multiphase flow displacement mechanisms that operate at different scales, from pore-level to Darcy scale. Experiments have shown that injection of oil-in-water emulsions and viscoelastic polymer solutions can be used as an effective enhanced-oil recovery (EOR) method, leading to substantial increase in the volume of oil recovered. The mechanisms responsible for increasing the recovery factor in different EOR methods are not fully understood.
Here, we summarize recent pore-scale studies on oil displacement by oil-water emulsion and viscoelastic polymer solutions. Visualization of the flow of complex fluids through a transparent network of micro-channels, which serves as a model of a porous media, reveals that the non-linear flow behavior improves the pore-level displacement efficiency, leading to lower residual oil saturation.
Optimized Centralizer Placement for Pre-Salt Formation
Authors: Samuel Robello , Wang HanYi 
Published: October 2015

Abstract
While exploring deeper water depths, large hydrocarbon deposits have been found below salt formations. These reservoirs are located in formations called "pre salts". Salt formations create favorable conditions for trapping hydrocarbons but also introduce challenges in well drilling and completion because of their mobile nature. The rock salts behave in a visco-elastic manner and deform under pressure. This deformation is called "creep" and occurs over time once the salt is disturbed. Creep begins the instant the drilling penetrates the salt formation and occurs because of instability and formation stresses. Completion of the well does not stop the creep process. This continual creep causes an increase in load on the casing and causes excess stress on the well completions during the lifetime of the well. Creep can eventually cause the casing to collapse.
Poorly designed casing, centralizer placement against the salt formation, and the cement job can be at risk for casing collapse during production. Previous studies have demonstrated eccentricity can increase the stress load on casing dramatically in salt formations. To avoid eccentricity, the placement of centralizers in the salt formation is very important. Presently, there is no method for optimizing centralizer placement; hence, it remains a challenging problem.
This study presents a geomechanical model, which treats the formation, cement, and casing as a whole system. The eccentricities of casing in wellbores having different borehole inclination and centralizer placement are derived from analytic solutions. The creep behavior of the salt formation and the stress load on the casing are calculated using the finite element method. The results of this model can be used as input parameters for optimum wellbore design, centralizer placement, and wellbore integrity analysis to predict the in-situ casing stress throughout the lifetime of a well. This paper also presents derivations of the generalized methodology for optimum placement of centralizers and the application of the model in a field case. Simulations examples have been performed and are reviewed in this paper. In addition, this paper documents the mathematical simulation results under different well profile and well geometry scenarios.
A Review of Fitness-For-Service and Life Extension Assessment Methodologies Relating to Corrosion Features in Fatigue Sensitive Risers and Pipelines
Authors: Masson C. , Lou J. , Saranyasoontorn K. , Jesudasen A. S. , Zeng W. , Wang L. , Hahn G. D. 
Published: October 2015

The objective of this paper is to share experience gathered from the ongoing integrity management of brownfield production flowlines, to help support future improvements in Fitness-For-Service (FFS) and Life Extension (LE) assessment methodologies, specifically for the case of corrosion features located in regions of higher fatigue loading.
The paper describes the nature of the problem being considered. This is followed by a brief review of the current state of flowline inspection technology to provide additional context. Industry standard practice and complementary literature relating to the assessment of corrosion features subject to fatigue loading are then reviewed. A possible enhancement to existing FFS methods for such cases is described. A hypothetical example is used to compare the different FFS assessment methods, including the "enhanced method." The findings are then reviewed and discussed addressing the limits of applicability and the advantages and disadvantages of each method, and conclusions are drawn.
Today's inspection equipment can provide information about the condition of a flowline, which is of great value for FFS and LE assessments. However, it will likely be some time before there are inspection tools available that can reliably detect and accurately size cracks growing from within corrosion features. This is particularly challenging when considering inspection over an extended length of flowline and within a practical timeframe. Therefore it is important to have a robust, rational and standardized method for assessing the fatigue life of detected or suspected corrosion features in the absence of specific knowledge about existing fatigue cracks within those features. Industry standards are somewhat limited in addressing this scenario with two quite different methods suggested.
The hypothetical example presented in this paper shows how those two methods might lead to inappropriate decisions regarding fitness-for-service, depending on specific circumstances. An initial investigation of an incremental enhancement in the methodology suggests that meaningful improvement is possible, and that further work in the area could be of significant value to the industry, helping to ensure appropriate run-repair-replace decision-making in the future.
A Data Mining Approach to Model Portfolios Oil Assets at High Risk
Authors: Cervantes Bravo R. , Fernández E. , Jiménez Nieves E. , Suma Tairo G. 
Published: October 2015

Management and portfolio evaluations is one of the crucial tasks that accurately account for valuating a petroleum asset. Usually, variations in input parameters and uncertainty on the evaluation of oil assets affect those processes, as it has been occurring with the price of oil in the last year.
This paper presents a new systematic process for the evaluation of portfolios of oil and gas fields where the performance and economic value of an entire portfolio decrease rapidly. The automated cash flow-curve analysis tool presented here uses an event detection algorithm combined with the design of quantile regression technique to provide a robust probabilistic estimate of future PDP (proved-developed-producing) reserves on a well-by-well basis. Individual well behaviors then aggregate stochastically to provide expected field and portfolio declines, with uncertainty ranges. Future well trends are estimated using probabilistic type-curves computed by data mining algorithms with a high-level of granularity.
Most discussions and publications to date have centered on the methods to perform portfolio optimization. However, very little emphasis was put on using analytical and data mining methods to evaluate faster the status of a given portfolio. This paper will focus on the use of data mining related methods in analyzing oil assets/engineering data, identifying correlations, development of industry-based algorithms and in the determination of relationships that influence root cause and consequence of failure in mature fields.
This paper proposes a new approach for mature fields. It includes models with technical Data Mining reserves estimation (either applied for volumetric calculations or performance data based in technical of Extracting hidden knowledge), an scenario matrix to account for the risk expressed in expectation curves, an estimation of the "Pseudo-limiting" risk and value terms, and defining a hierarchy of portfolio with data mining technique. Furthermore, it proposes a methodology of life-cycle assessment and surveillance of reserves estimation by integrating of the "Pseudo-limiting" risk and the ratio expected value to capital investment under the concepts of risk management.
The developed models showed good performance with minimal prediction errors. These results are promising, lending credence to the application of computational Intelligence for even more complex reservoir systems. They should also boost confidence in the use of advanced well structures for field applications.
The consideration of such needs bring up the following purposes:
Extracting hidden knowledge or information not trivial of dataset to be used in making decision.
Discovery of unknown models [1] [2] in order to discover meaningful patterns and rules [3].
Flow Assurance as a Show Stopper for Subsea Factory - Use of Subsea Separation for Mitigation and Elimination of Risks
Authors: Tienhaara Mika 
Published: October 2015

Field developments, from greenfield to mature field rejuvenation are challenging and there are various possible options. Attention to production risks and flow assurance issues are key in determining what type of production concept that is optimal for any field in question.
Sand production issues can have a severe impact on any field architecture but this can be remediated by the use of sand removal technologies. With the advances in separation technology and the feasibility of using subsea separation solutions, there can be many benefits in terms of reducing erosion and clogging risks as well as enabling prevention of gas hydrates. Subsea separation can be an important enabler for field development decisions.
Some key technologies for subsea separation solutions, such as gas/liquid separators, desanders and hydrocyclones have been qualified for subsea applications and have been proven topsides. Gas/Liquid separation can be part of subsea solutions aimed to minimize formation risks of gas hydrate in the risers. Ongoing development work can contribute to reduce complexity and total project costs for field developments.
Adequate technology qualification for new technology should be done utilizing a large-scale realistic conditions flow loop.
Internal Lining of Carbon Steel Flowlines With a Plastic Liner Based on a Fluorinated Polymer: Introduction of the Concept and Evidences on CAPEX and OPEX Reductions
Authors: Messina N. , Colladon M. , Fossati P. , Meynet C. 
Published: October 2015

Capex reduction and project management complexity are at the top of the list of the main drivers for subsea flowlines, together with the water depth and the opex increases. Rigid risers and flowlines remain the main solutions used for offshore fields but the new market conditions are forcing the industry to increase the attention towards more cost-competitive solutions over the current CRA-based ones.
This paper describes the main performances and characteristics of a fluorinated polymer, already used in offshore flexible risers, as potential use for internal lining of rigid flowlines.
The scope of the paper is: i) to provide the evidence on the positive impact on CAPEX and project management complexity brought by the lining solution, ii) to provide data on the flow assurance advantages and iii) to provide an insight on the positive impact on the OPEX reduction and on the operational complexity improvements.
The paper is composed of three sections. A first section will provide a mechanical analysis of the performance of the polymer in respect of the main technical requirements of the lining solution. Going through the existing track record in offshore, the main chemical and permeation resistance characteristics of the polymer are shown. The second section focuses on a cost analysis. A first Capex analysis, mainly based on material cost comparison, shows the advantage of using this lining solution over the CRA based ones. Then, starting from an overview of the main surface properties of the polymer proposed, this paper will also show wax-deposition test data and a drag reduction simulation analysis. The drag analysis was initiated from real service conditions, considering different types of service for the flowlines, and was done in comparison with existing metallic solutions. This analysis then provides an idea of the OPEX reduction and the operational advantages of the use of plastic lined pipelines vs metallic solutions.
The third section completes the paper with some results from real in-field tests, which were performed onshore, and also with a real track-record on a new lining technology, used offshore and based on the polymer here proposed.
Conclusions show CAPEX and OPEX advantages, the improvement in the project management, with the possibility to increase the level of the local content (where requested) of the project and then also the flow assurance advantages and the OPEX reduction associated to the lining solution.
The Development of the ULFPSO Concept Design
Authors: de Oliveira Allan Carre , Vilamea Eduardo Marçal 
Published: October 2015

Oil production in Brazilian pre-salt fields has already become reality and its production has been reaching successive records in recent years. The development of these areas has required a major technological development effort and the application of several innovative technologies successfully.
One of the most remarkable characteristics of the Brazilian pre-salt fields is the high flow rate obtained from the producing wells. For the development of production in the most recent giant fields of the pre-salt, the high flow rate wells encourages the use of larger diameter production lines, saving costs in subsea engineering. However, the increasing of the oil production and the presence of contaminants and high gas concentrations in the oil reservoirs are technological challenges that increase the complexity of the oil processing, allied to more strict environmental rules. The use of larger diameter lines also requires the use of SCRs (Steel Catenary Risers), economically more advantageous in relation to flexible lines in this scenario. However, the use of rigid lines requires a Floating Production Unit with low level of motions, which implies in a large unit, more expensive. The use of larger diameter lines also increases the oil production platform requirements, increasing the need for additional production plant area as well as the ability to withstand heavier process plants.
These features encourage the search for innovative solutions that maximize production by FPU and still offer economic advantages through economies of scale. Based on this scenario, it was developed a concept of Floating Production Storage and Offloading Unit called ULFPSO (Ultra Large FPSO), which is capable of supporting plants more complex than the current ones, with a larger weight and a larger footprint, coupled with the receipt of the production lines in a region less affected by the environmental loads, enabling also the use of SCRs for larger diameter lines. This paper presents the characteristics of this new concept and present preliminary analysis of its feasibility.