bluuebunny/crossref_metadata_2025_split huggingface dataset:
RADARSAT-2 Derived Sea Ice Information for Operations in the Arctic
Authors: Sharma Jayanti , Rabus Bernhard , Ma Andy , Nadeau Christian 
Published: June 2014

Abstract
Synthetic aperture radar (SAR) has been extensively used for the derivationof valuable information regarding sea ice properties and conditions. This workfocuses on the use of RADARSAT-2 ScanSAR Wide images (500×500 km swaths with50×50 meter pixels) to provide sea ice information for operations support inthe Arctic. Our developed processes generate several products that supportnavigation and operations in ice infested waters:Sea ice images, i.e.delineating and mapping sea ice relative to the open water,Seasonal trendcharts of sea ice over an area of interest and,Automated ice featuretracking and pressure zone mapping.
Using the RADARSAT-2 dual-polarization images and automated techniques, seaice maps are generated to identify regions of open water and of sea ice. Fromthe sea ice maps, total ice concentration is derived and combined withhistorical concentration maps. The output seasonal trend charts can be used toassist in monitoring Arctic sea ice extent and sea ice identification to aidwith navigational safety operations. Finally, we develop an automated icefeature tracking that can track moving ice and from which pressure and driftzones are identified. Future work will involve the development of theprediction of movement of ice floes and packs, using the ice feature trackingtechnique as the foundation.
Springs: Subsea Seawater Treatment - Case Study
Authors: Pedenaud Pierre , Hallot Raymond , Skivington Graeme , Riviere Luc Kristian , Anres Stephane Jean 
Published: June 2014

Abstract
New local subsea processing systems will need to be developed to allow remotely located satellite oil fields to be produced economically. One such system treats seawater for injection into the reservoir.
As reservoir waters often contain elevated concentrations of barium or calcium, treatment systems need membranes to remove any sulfates that may form in the seawater before it is injected into the reservoir, in order to avoid severe scaling.
SPRINGS (Subsea PRocess and INjection Gear for Seawater) is a collaboration project between Total, Saipem, Veolia Water and VWS Westgarth. It was initiated in 2007 and aims to provide robust solutions featuring the use of membranes for treating seawater on the sea bed in deepwater areas.
SPRINGS has now reached qualification stage and a first industrial application is planned for 2015.
This paper describes the SPRINGS development project, including an update on the latest progress to date. It presents a specific case study conducted in the Gulf of Guinea which illustrates the commercial and technological advantages, along with the limitations, of deploying this technology for future remote applications.
It compares the conventional field architecture utilized in conjunction with water injection from FPSO topsides with the architecture required for a SPRINGS solution on the ocean floor.
The information provided allows operators to consider an alternative development strategy for the application of membranes to water injection in remote satellite fields.

Introduction
The development of isolated subsea fields, far from existing production centres or from the shore, and sometimes in very harsh environments such as deep offshore, West of Shetlands or the Arctic seas, has led Total E&P to develop new building blocks of innovative subsea processing.
One block required for the development of subsea oilfields is the treatment of seawater for injection (sometimes going as far as desulfation, if the reservoir water contains significant levels of barium or calcium), to maintain pressure and optimize recovery of reserves.
Recommended Practice for Unbonded Flexible Pipe Employing Composite Armour Material
Authors: Yu Liang , Barbosa Neto Teofilo , Kalman Mark 
Published: June 2014

Abstract
This paper presents proposed requirements for qualifying composite reinforcement for the hoop and tensile reinforcement layers of unbonded flexible pipe, and progress towards meeting those requirements by one manufacturer.
Due to lighter weight and resistance to corrosion and fatigue, composite materials are being implemented for the hoop and tensile reinforcement in unbonded flexible pipe. By reducing the weight of the pipe up to 50% or more, riser system and installation top tensions are substantially reduced. The lower weight and tension reduces project CAPEX, installation cost and risk by enabling lighter weight capacity floating production systems and installation vessels.
Currently ISO 13628-2/API 17J Specification for Unbonded Flexible Pipe [1] does not apply to composite reinforcement, largely because of the limited operational experience with composite materials. Proposed requirements to be included in Annex H of API 17B Recommended Practice for Flexible Pipe [2] as guidelines for composite armour, are summarized in the paper. As operational experience is gained, it will be proposed to include these requirements and learnings in a future revision of ISO 13628-2/API 17J. The efforts of one manufacturer to develop and implement a design methodology and qualification program to meet the proposed requirements are presented.
Most flexible pipe manufacturers are in various stages of developing and commercializing unbonded flexible pipe with composite armour. Yet, there has not been agreement in the flexible pipe community on product requirements. Without industry concurrence on requirements, manufacturers can expend significant funds developing and qualifying a design methodology which does not meet target requirements. This paper describes the first effort to obtain industry consensus on target requirements for unbonded flexible pipe with composite armour.
UOE Pipes for Ultradeepwater Application
Authors: Combaud F. Santos , Liessem Andreas , Schroeder Jens Santos , Fluess Peter , Reepmeyer Oskar , Maerten Bernadette , Buirette Christophe 
Published: June 2014

Abstract
Offshore oil & gas construction pipes for deep water are exposed to high collapse pressure, to high axial loads and partly to fatigue in the girth welds. Pipes suitable for this application are characterized by heavy wall thickness, higher strength material, by tighter tolerances and high fracture toughness properties. Looking into water depths of 10,000 ft (3,000 m) and above these properties are becoming increasingly more crucial.
Today the UOE pipe making process is best suited to produce longitudinal welded pipes of the same dimension in large amounts with short deliveries and low costs. Additionally to the UOE forming process generally the DSAW welding is applied in order to accommodate the high productivity requested to take full benefit from the high efficiency of the UOE process. Both fabrication methods have been limited to a wall thickness up to ca. 1.50?? (38.1 mm) wall thickness and the grade API 5 L X-70 to deliver the requested high fracture toughness and tight tolerances.
State of the art plate production, integrated R&D activities between plate supplier and pipe manufacturer create a position where the delivered pipes fulfil the extreme requirement for the ultra deep water business. Tendon pipes with 1.70?? (38.1 mm) wall thickness in X-75 were delivered with the fracture toughness requested, a wall thickness up to 2.0?? (50.8 mm) is possible and material grades higher than X-80 can reach into deeper water without changing the standard design for pipe based tools. This article takes reference to the above mentioned products and provides an outlook what will be available in the near future.

Introduction:
New larger offshore oil & gas fields justifying bigger scale investments and being able to serve larger markets are moving further out into the open sea. Most of the important oil & gas offshore areas are reaching water depths of 6,500 ft (2,000 m) and more. Areas like the Brazilian East Coast, the West Coast of Africa, the eastern part of the Mediterranean Sea, the Atlantic Margin and others are to be named. In these projects pipes are used not only for pipe lines in order to transport the fluids but also as structural components, partly in combination with the use as a liquid transportation tool. The challenges pipes have to withstand in this environment are becoming progressively more severe. Growing collapse pressures, high axial loads and increasingly fatigue loads are some of the most important challenges designers and pipe producers have to create solutions for. Over all beside the technical solution to be created the safe and long term operation is driving very much the economics for these projects which finally is the basis for a positive final investment decision.
Wet Gas Performance of a Low Energy Gamma Ray Multiphase Meter
Authors: Brister Casey Michael 
Published: June 2014

Abstract
There is a perception in the industry that the accuracy of low energy gamma ray multiphase meters suffers in wet gas or high GVF environments. This is generally attributed to the low density of the process flow having a much more reduced effect on the gamma ray beam and thus a reduced overall accuracy of measurement. These perceptions can have a dramatic impact on the cost of installations for monitoring Wet Gas flow where alternatives to multiphase meters can be tens of millions of dollars more expensive.
This paper describes a successful performance test of a 88mm (7?? ID) venturi, low energy gamma ray, multiphase meter at the CEESI wet gas facility in Colorado, USA on 31 October 2012. The test was performed at CEESI, an independent third party test facility which is well known in the industry for its high quality & accurate wet gas flow loop.
The performance test was witnessed by participants from:Exxon Mobil BP Chevron MaerskTullow Oil WoodsideLetton-Hall Group CEESI Test FacilityFramo Engineering Schlumberger
The test envelope for the flow test was in the wet gas region with Gas Volume Fractions (GVF) range from around 97 % to over 99.5 % and a wide range of Water Liquid Ratios (WLR). The number of flow periods in the test matrix was limited due to the requirement to complete the flow test in a single day. Participants were also given the opportunity to propose flow rates for the flow periods run during the day of testing.
New Deep Water Frontiers in the South Atlantic Equatorial Margins
Authors: Mello Marcio Rocha , Takaki Tikae , Fontes Carlos Alberto , Mohriak Webster , Barbanti Silvana Maria , Azambuja Filho Nilo Chagas , Bender Andre A 
Published: June 2014

Abstract
Petroleum exploration along the West African and South American Equatorial Margin has led to important oil discoveries along both margins. Similar geochemical characteristics of these finds suggest analogous petroleum systems with enormous potential in the conjugate margin sedimentary basins. The Jubilee giant oil discovery offshore Ghana has an estimated recoverable reserve of about 600 million barrels. In the area that was once connected to the equatorial West African margin, but is now separated by the Atlantic Ocean, two discoveries have recently been announced. Tullow Oil announced the Zaedyus discovery offshore French Guinea, with 72m net oil pay in turbidite sandstones. Petrobras and BP announced the Pecem discovery in the northern Brazilian margin, with 140m of net pay in 2,129m water depth in the Ceará Basin. These discoveries appear to have a very similar geologic evolution, source rock facies, and oil types suggesting similar petroleum systems. Additionally, the integration of high resolution geochemical data from oils recovered from boreholes offshore the other basins along the South Atlantic Equatorial Margin has revealed four separate source rock systems: 1- an Aptian/Barremian calcareous black shale associated with a lacustrine brackish to saline anoxic environment; 2- a Late Aptian calcareous shale deposited in transitional environments, as indicated by oils found in the Ceará and Potiguar basins; 3- an Albian/Cenomanian/Turonian marine shale corresponding to an anoxic event widespread in the West African salt basins, particularly in the deep water settings of the Ghana and Angola continental margins. Similar oils have also been registered in the Foz do Amazonas Pará-Maranhão basins and in five ultra-deep water accumulations discovered recently (2011–2012) in the Sergipe Basin; 4- Paleocene-Eocene shales deposited in deltaic environments in the Niger Delta, the Amazon Cone, and Pará-Maranhão Basin. This work aims to restore these basins to their previous pre-breakup locations and to support new exploration efforts. Despite similarities shown above, simply matching discoveries in the conjugate margin basins, for example the Tano Basin offshore Ghana, with the Ceará Basin in northern Brazil, does not necessarily yield the entire story that may lead to a successful end. There is a great deal of contrasting sedimentary and structural development peculiarities from basin to basin and margin to margin. The application of a high-resolution petroleum system approach can lead to better exploration models for these basins and provide clues on the best strategy for drilling the new prospects that have been identified in the ultradeepwater regions of the South Atlantic Equatorial Margin.
Understanding the Full Extent of the R&D Capability Within Brazilian Universities
Authors: Dudgeon Christopher , Vahora Shahnawaz , Atie Helene 
Published: June 2014

Abstract
E&P companies in Brazil are required to invest in R&D projects with Brazilian universities as part of the special participation fee. Industry wide, this levy is expected to be cumulatively worth USD 10 Billion by the year 2022 and therefore the need exists for E&P companies to maximise value obtained through these R&D investments by understanding the full extent of the R&D capability within Brazil. A comprehensive and independent analysis of the E&P research capabilities of leading Brazilian R&D institutions has been carried out. The resulting R&D Landscape Map can now help the decision making process by identifying and selecting R&D institutions with the capability and resource capacity to deliver world-class results. Three E&P companies have recently collaborated with a firm of consultants to develop this R&D Landscape Map, a unique undertaking which has never been completed to this level of detail. This paper highlights some of the key results and conclusions from this multi-operator project, which comprised three phases of work. These phases included the development of an international university benchmarking diagnostic, primary research amongst Brazilian universities, and subsequent analysis and benchmarking. In the first phase, seven ‘world-class’ oil and gas research universities were visited in the USA and Europe. The objective of these visits was to create a calibrated diagnostic for assessing world-class excellence for conducting research across three dimensions - quality of working together, quality of resources, and track record. In the second phase, detailed visits were made to 48 shortlisted E&P research departments in Brazil, in order to carry out an independent and comprehensive assessment of their R&D resources, including staff and facilities. Finally, an assessment was made of how well the Brazilian research groups compare to their US/ European counterparts using key performance indicators. Recommendations were made as to how value may be maximised from this huge investment in R&D, for the benefit of all stakeholders including the government, E&P companies, universities and research organisations, and the Brazilian people.

Background
In recent times, pre-salt exploration in Brazil has seen some of the largest and most exciting discoveries in the world. The total reserves discovered are estimated to be anywhere between 70 to 100 billion barrels of oil equivalent. The first oil produced from the pre-salt layer was extracted from the Jubarte field off the southern coast of the State of EspÍrito Santo in September 2008 and production from the pre-salt reserves has been increasing gradually. Currently Brazil is producing 100,000 barrels per day of oil from its deepwater pre-salt fields, but it is targeting a tenfold increase to 1 million barrels per day by 2017 (Beckman, 2011).
Assessment and Mitigation of Low-Toughness Forged Mooring Components for Floating Structures
Authors: Gallagher Dan , Ku Albert 
Published: June 2014

Abstract
The ability to maintain stationkeeping throughout severe environmental loading is critical to the safe operations of permanently moored floating facilities. Failures of forged mooring components have been observed on these facilities and noted by the issuance of multiple safety notices by United States regulatory bodies (U.S. Department of the Interior Safety Alerts No. 259 on 16 January 2008 and No. 296 on 12 May 2011). These alerts highlighted the need for Operators to remain vigilant in ensuring that the mooring components present are of sufficient quality and toughness to prevent the observed failures from occurring in the future. This paper describes a study which includes the following three main components:a survey of existing facilities to determine the extent of forged low-toughness mooring connectors in service,develop a high-level assessment procedure to assess such connectors, andidentify potential mitigation activities.
The main findings of this paper confirm the existence of low fracture toughness connections. Operators, manufacturers and the classification societies have actively pursued improved manufacturing and certification processes which significantly improve the toughness values, which will be demonstrated in this paper. Assessment and mitigation processes are also summarized in this paper which can be employed by operators to reduce the risk exposure from the low toughness mooring components.

1. Introduction
Several incidents involving failure of forged mooring line anchoring system connectors have been observed on permanently moored facilities. Post-failure analyses indicated that manufacturing processes were defective for each case, namely the heat treatment applied at the manufacturer resulted in the material being unable to meet specified Charpy impact energy. Failure to meet this specification indicates a lower material toughness that may adversely affect fitness-for-service. These events led the U.S. Department of the Interior Minerals Management Service Gulf of Mexico OCS Region (MMS) and the U.S. Coast Guard, 8th District (USCG) to issue Safety Alert No. 259 on 16 January, 2008. This alert identified several recommendations including:Operators review mooring component specifications to ensure manufacturing and testing activities provide a product that meets usage demandsOperator specifications will include sufficient Charpy testing to ensure adequate material toughness for componentsOperators review required destructive and non-destructive testing of critical mooring component elementsOperators will review equipment inspection and handling requirements to ensure no damage is induced during transportation or installation
While the safety alert does not impose explicit mitigation for existing mooring systems, it does indicate that a proper understanding of existing mooring system state should be developed and procedures in place to prevent below specification connectors from entering service in the future.
Accurate Measurements of Liquid Condensate Rate With Multiphase Metering Technology Improves Ecological Impact of Well Test in Deepwater Well Offshore Brazil
Authors: Maizeret Pierre David , Theuveny Bertrand C , Essenfeld David , Reid David 
Published: June 2014

Abstract
Separators have a proven track record and are widely used in well testing operations. However, their range of applications is relatively narrow and they can encounter limitations with fluids for which separation is an issue. For example, in wet gas wells, when the liquid volume is small compared to the gas, or the gas and liquid are foaming, it is difficult to separate properly the phases, especially at high flow rates where the retention time in the separator vessel may be too short. Inefficient separation results in wrong measurements, which can not only have significant consequences for the assessment of commerciality of a new field, but also have a negative environmental impact if the burning process is also adversely affected, resulting, for example, in production of black smoke or imperfect burning leading to hydrocarbon discharge in the environment.
This paper describes a well test in a deepwater well offshore Brazil. To be able to accommodate different production scenarios, two separators and a multiphase meter were used to measure the flow rates. During the test, the comparison of the flow rates from the multiphase flow meter and those reported by the separator made possible the identification of some carry-over in the separator at high choke setting. When the choke size was increased, the separator gas rate increased while the liquid rate dropped at the separator, resulting in a very low condensate to gas ratio (CGR). The multiphase meter on the other hand, reported a constant CGR. At the end of the test, the same choke setting was used for a short period of time to confirm the behavior. The same observations could be made on the rates and a small amount of liquid could be seen in the gas flare. The final proof came from the analysis of the downhole samples which confirmed the CGR measured with the multiphase meter.
The consistent results from the multiphase meter make it ideal to validate the flow rate measurements from the reservoir and improve the burning efficiency reducing the HSE risks associated with well test operations.