bluuebunny/crossref_metadata_2025_split huggingface dataset:
Structure and Hydrocarbon Prospects of the Russian Western Arctic Shelf
Authors: Stoupakova A.V. , Kirykhina T.A. , Suslova A.A. , Kirykhina N.M. , Sautkin R.S. , Bordunov S.I. 
Published: June 2014

Abstract
The Russian Western Arctic Basins cover the huge area including the Barentsand Kara seas, the western part of the Laptev sea and adjacent territories withsome archipelagoes and islands (Spitsbergen, Franz Josef Land, SevernayaZemlya, Novaya Zemlya, etc.). They comprise the Barents and Kara Basins, thenorthern areas of the Timan-Pechora Basin, the North West Siberia, includingYamal and Gidan peninsulas and the Yenisey-Khatanga Basin. Within the RussianWestern Arctic basins the following main tectonic elements can be identified:extensional depressions (Central-Barents, Yenisei-Khatanga, West Siberia, EastUrals) with sedimentary thickness is more than 12–14 km; platform massiveswith average thickness of sediments of 4 – 6 km, monoclines and tectonic steps, like transition zones between extensional depressions and platform massives. Western Arctic basins are filled by mainly Palaeozoic and Mesozoic sedimentarysuccessions. In the sedimentary cover of this large region, many commonstratigraphic complexes and unconformities can be traced within Palaeozoic andMesozoic complexes that show similarity of geological conditions of theirformation. Analysis of the Russian Western Arctic basins, their structures andhydrocarbon prosepctivity shows the areas, which are favourable for hydrocarbonaccumulations. Deep depressions, as areas of long-term and stable sinking, arehighly promising zones for the accumulation of predominantly gas fields. Theyform regional gas accumulation belts, extending for thousands of kilometres, where the largest fields can be expected in the zones of their intersectionwith the major tectonic elements of another strike. Within the Barents-Karashelf, the large belt of predominantly gas accumulation extends from the northof the West Siberian province through the South Kara basin and into the BarentsSea. The second potential belt of predominantly gas accumulation may beassociated with the North Barents ultra-deep depression. On the flanks of thedepressions the sedimentary cover profile does not contain the complete set ofoil-and-gas-bearing complexes, identified in the central parts of theextensional depressions. The reservoirs can be filled by HC due to the lateralmigration of fluids from the neighbouring kitchens or from their own dominantoil-and-gas source rock strata. For the formation of oil accumulations, themost favourable are platform massifs and ancient uplifts areas.
Numerical Prediction of Spilled Oil Behavior under Sea Ice Conditions: Modification of the 2011 Model
Authors: Nakazawa N. , Ono J. , Yamaguchi H. , Ohshima K.I. , Kurokawa A. 
Published: June 2014

Abstract
This report describes an updated version of the numerical prediction systemfor oil spilled under sea-ice conditions in the Sea of Okhotsk that wasdeveloped by the authors and presented at ATC 2011 (Paper Number: OTC 22123). Our previous version enabled the computation of high resolution predictions ofthe ice-spilled-oil behavior using only PCs; a one-week forecast of spilled oilbehavior could be computed in a few hours. This previous method computed thebehavior prediction serially: first step, computation of sea-ice behavior forthe entire Okhotsk Sea (grid size of 16 km × 16 km); second, higher resolutioncomputations (grid sizes of 4 km × 4 km or 2 km × 2 km) using the dataresulting from the first step such as ice concentrations and velocities asboundary conditions; third, final computation of predicted sea-ice andspilled-oil behavior; and fourth, processing and displaying the results in agraphical interface. Since shorter computation times would be advantageous foroil-spill cleanup procedures, we modified the previous serial method to enableparallel computation not only to shorten the processing time but also todisplay spilled-oil/sea-ice images as the computation progressed. This paperincludes an example of computed predictions that model the behavior of spilledoil under three conditions, namely, in open water, in water at the margins ofice-covered water, and in ice-covered water, all located near Soya Strait.
Freeze-Up Processes in the Alaskan Beaufort and Chukchi Seas
Authors: Leidersdorf Craig B. , Scott Christopher  P. , Vaudrey Kennon D. 
Published: June 2014

Abstract
This paper characterizes the processes that presently occur during freeze-upin the Alaskan Beaufort and Chukchi Seas, based on joint-industryinvestigations conducted in 2009-10, 2010-11, and 2011–12. The studies weredesigned to address five specific objectives:describe the ice conditionsthat evolve during the freeze-up and early winter seasons;locate and mapfeatures of potential importance for offshore exploration and productionactivities, including ice movement lines, leads, polynyas, first-year ridgesand rubble fields, and multi-year floes;locate and quantify ice pile-upson natural shorelines and man-made structures;correlate significantchanges in the ice cover with the corresponding meteorological conditions; andcompare present-day freeze-up processes with those that occurred in the1980s.
Each study included an analysis of meteorological data, ice charts, andsatellite imagery in concert with a series of aerial reconnaissance missions. The study findings are presented in seven categories:air temperatures,first-year ice growth,the timing of freeze-up,landfast ice,multi-year ice,ice pile-ups, andextraordinary ice features discoveredoff the Chukchi Sea coast.
An Improved Method of Extremal Value Analysis of Arctic Sea Ice Thickness Derived From Upward Looking Sonar Ice Data
Authors: Ross E. , Fissel D. , Marko J. , Reitsma J. 
Published: June 2014

Abstract
In the Beaufort Sea, observations of extreme draft sea ice features havebeen identified from upward looking sonar (ULS) datasets spanning severalyears. Using analysis methods from extreme value theory, the estimated 100-yearreturn values of the maximum ice draft have been derived. In addition, theapplicability of these statistical techniques to the Northeast Greenland iceregime is examined using one year of ULS data at two locations from 2008 to2009.
The methods have been developed for the Beaufort Sea region andsubsequently, further refined for use in estimating extreme ice hazards offNortheast Greenland. These estimates provide inputs to the design of offshoreplatforms and ships in support of oil and gas activities in these ice-infestedwaters.
Previous studies in the Canadian Beaufort Sea derived an empirical upperlimit on the maximum sea ice thickness resulting from deformation processesbased on the relationship of maximum ice thickness as a function ofsimultaneous values of undeformed ice thickness. Using the more extensive ULSice keel data sets now available, these methods were re-evaluated and updated. Similar analyses were carried out on ice thickness measurements obtained offNortheast Greenland which reveal distinct differences in the ice regime ofthese two geographical areas.
Improvements to extremal value statistical analysis methods for longrecurrence intervals of 100 years for ice draft (D100) are based on the threeparameter Weibull distribution which has been optimized for application to verylarge sea ice keels using a peak over threshold selection approach. Theseresults were compared to the maximum draft limit and undeformed ice thicknessrelationship. We developed techniques to refine at a high resolution the lowerthreshold on maximum draft and examine the implications of this filtering onD100. This is an important consideration as selecting the lower maximum draftthreshold is a balance between retaining enough observations to ensurestatistical robustness and sampling only the extreme tail of the maximum draftdistribution. Methods for performing these statistical analyses arepresented.
Developing a Turret Mooring System for Arctic FPSO units
Authors: Van Der Nat C.G.J.M. , Heideman R.R. 
Published: June 2014

Abstract
The prospect of large oil and gas reserves in fields below Arctic waters hasdriven the design development of production solutions for these areas. Thispaper presents the development of an Arctic Turret Mooring System technologywhich facilitates year-round station keeping of floating offshore structures, like FPSOs in the Arctic environment. The Arctic turret mooring system candisconnect the mooring when the FPSO encounters extreme ice loads, which couldotherwise damage its hull or mooring system. When disconnected, a mooring riserbuoy supports the production risers and control umbilicals. The system isdesigned to quickly disconnect and re-connect the mooring riser buoy. Especially the fast re-connection will reduce the downtime to the productionsystem when disconnection is necessary.
The Bluewater Arctic Turret is based on further development of existingBluewater know-how and designs of (quick) disconnectable Turret MooringSystems. However, in addition to existing designs, the Bluewater Arctic Turretuses a unique and patented design that allows the mooring riser buoy to bereleased from the turret, while being subject to the large (horizontal) mooringloads. In this design, the mooring riser buoy is released from the turret tosink below the FPSO hull, before the mooring system is disconnected from theturret. Following disconnection, the mooring riser buoy descends further to asafe equilibrium depth away from ice hazards. This allows the disconnected FPSOto sail from its production location and later return for reconnection andquickly resume production. The paper presents the unique Bluewater ArcticTurret Mooring concept, its design basis, the development process as well asconsideration to key aspects such as operational and safety issues.
Development of SCS Sandwich Composite Shell for Arctic Caissons
Authors: Marshall P.W. , Sohel K.M.A. , Liew J.Y. Richard , Jiabao Yan , Palmer A. , Choo Y.S. 
Published: June 2014

Abstract
There is a wide range of offshore structures which may be constructed byeither steel or concrete materials to be used in the arctic region, such assteel tower platforms, caisson-retained islands, shallow-water gravity-basecaisson, jack-up structures, bottom-founded deep-water structures, floatingstructures, well protectors, seafloor templates and breakwaters. One commonfeature of these structures is that they must be able to resist the highlateral forces from the floating ice and transmit these forces to thefoundation. This study explores the use of Steel-Concrete-Steel (SCS) curvedsandwich system for arctic caisson structures. SCS sandwich system, whichcombines the beneficial effects of steel and concrete materials, has promisingbenefits over conventional plates and stiffeners design and heavily reinforcedconcrete design because of their high strength-to-steel weight ratio and highresistance to contact and impact loads. Shear connectors have been proposed toprovide bonding between the external steel plates and high-performancecementitious core materials. Finite element analyses and large-scale testresults showed that SCS sandwich panels without mechanical bond enhancement arevulnerable to interfacial shear failure and impairment of structural integritywhen subject to shrinkage and thermal strains, accidental loads, and impact. The proposed SCS sandwich system features mass-produced mechanical shearenhancement and/or cross-ties. It can reduce structure complexity, particularlyin the number of weld joints which are prone to fatigue, hence increasingservice life, cutting down the cost of fabrication, and reducing the manpowercost to operate, inspect, and maintain the structure in the long run. Considering local ice load, the punching shear and shell bending strength ofthe SCS sandwich composite shell is studied experimentally. Test results showedthat the SCS sandwich panels, which are designed using the ISO ice load, arecapable of resisting the localized contact and punching loads causedthereby.
Novel Energy Efficiency Technologies for Reduction of Offshore COEmissions
Authors: Walnum Harald T , Mazzetti Marit J , Neksa Petter Luis , Hemmingsen Anne Karin T 
Published: June 2014

Abstract
This paper will discuss novel technologies for increasing the energy efficiency of offshore oil and gas platforms. Three case studies are in progress based on actual oil producing platforms, two on the Norwegian Continental Shelf (NCS) and one in the Brazilian Basin. The current focus is on developing compact, novel bottoming cycles for recovery of waste heat from the gas turbine as well as heat recovery from the compressor train for gas export. The technologies investigated utilize steam as well as alternative working fluids, such as CO2 and hydrocarbons. All the fluids investigated in this project are natural working fluids hence they will not cause any unexpected environmental issues in the future.
A case study was performed looking at an eighteen year period of operation on an actual platform and a scenario where one gas turbine is removed and replaced with a CO2 bottoming cycle utilizing the the exhaust heat from one of the other gas turbines. The beauty of this scenario is that it would not increase the weight on the platform since the crate containing the gas turbine to be removed is of a similar weight to a crate that contains a CO2 bottoming cycle. The substitution would not affect the ability to cover the heat demand on the platform as a Waste Heat Recovery Unit (WHRU) can be installed on the platform's other gas turbine.
The case study indicates significant reduction in CO2 emissions of 22%, or 63 000 tonnes/yr, and does not involve adding additional weight or volume to the platform. If operating on the NCS the annual savings in reduced fuel costs and CO2 tax from implementing Scenario 2 would be US $17M, albeit much lower in other territories.
Value of Well Test Acquisition Strategy and Advanced Interpretation Methodology in Peregrino Field
Authors: Vasconcelos Daniel Francisco Maia , Torres Diego Martins 
Published: June 2014

Abstract
The Peregrino field is a heterogeneous heavy oil field located offshore Brazil in the Southern Campos basin. The field is planned to be developed with 30 geosteered long horizontal producers completed with ESPs for lift and 7 water injectors. As per July 2013, 19 producers and 3 injectors are on stream. The reservoir deposits are characterized as complex shallow marine and gravity driven sedimentation processes in shore phase to offshore environments.
Information deduced from the pressure transient analysis (PTA) are highly valuable in complex and heterogeneous reservoir deposits for increased reservoir understanding enabling optimization of the production and development strategy. The well test information has the potential to provide average rock properties on a larger scale related to permeability, sand continuity, fluid properties and distance to reservoir boundaries (such as erosional features, faults and fluid contact) that can be used as conditioning points for reservoir modeling and characterization.
This paper provides a description of the PTA acquisition strategy and the advanced interpretation methods for ensuring high quality data and maximized derivation of information that can be used to optimize the production and development strategy for the Peregrino field. High viscosity oil, wells with long reservoir sections, ESPs for lift and well interference makes this especially challenging. Since the pressure waves propagate slowly through the reservoir, the deconvolution technique has been implemented in order to maximize the value of repeated PTA in the same well and thereby enabling identification of reservoir features with the minimum amount of downtime for the production wells and also enhancing its value as a predictive tool. The reservoir information is used to update the reservoir model, optimize the well spacing and optimize placement of wells in relation to the oil water oil. The importance of prioritizing this type of data acquisition from day one in the field development will also be presented.

Introduction
The Peregrino Field is located in block BM-C-7, in the southernmost part of the Campos Basin (Figure 1). The area is located 85 km southeast of the nearest coastline, approximately 100 km southeast of Macaé, Brazil. The Peregrino Field was discovered in 2004, with production start-up in 2011. The water depth in the area varies from 95 to 135 meters, over an area of approximately 350 km2. The reservoir depth in the field is between 2150 and 2350 meters TVD. The Peregrino Field is one of the heaviest offshore oil developments in Brazil. PVT properties for Peregrino are shown in Table 1.
Advanced Control Systems for Offshore Production Platforms
Authors: Simoes Saul , Santos Wilson Trindade , Campos Mario Cesar Mello Massa de , Pimenta Austin , Teixeira Alex Furtado , Von Meien Oscar Felippe , Stender Alberto Santanna 
Published: June 2014

Abstract
The discovery of new reserves of oil and gas located at great distances from the coast, with increasingly stringent regulations for safety, energy efficiency, environment and quality of products, poses new technological challenges for automation and control. Advanced control systems can play an important role to improve stability and profitability. The main objectives of advanced control systems are:Maximize the production;Ensure the specification of products;Minimize energy consumption;Minimize the process variability which increases safety and minimizes the flare (loss of products);Minimize operational costs, operating the equipment in a stable environment thus reducing the number of unscheduled stops resulting in lower maintenance and logistics costs.
Although advanced control system is a reality in many industrial areas (refineries, petrochemicals and gas plants), it is not widely used for offshore production units. There are many causes that justify why advanced control is not widely utilized in offshore platforms, like:A platform has many transients (shutdown, different well alignments, etc.), many disturbances (slugs), uncertainties and noise.Oil and gas production is never in a steady state because it is a time-varying process (gas-oil-rate, water cut, sand production, gas coning, water coning, etc.).Few instruments available, for example there aren't many pressures and temperatures instruments inside subsea pipelines and wells, etc.There are no advanced control specialists onboard to install and keep these tools working properly.
This paper will present some solutions to promote the use of advanced control on a platform, for example:New control strategies to minimize the effects of transients (adaptive algorithms to find out optimum PID tuning) and disturbances (anti-slug control) and also new algorithms to optimize the process.A methodology in order to help the implementation of these tools that change the way the operators interacts with the production process.
This paper will show and discuss some results of the implementations of these advanced control systems in offshore platforms, emphasizing the gains of stability and profitability. The offshore plants are becoming more complex and require these advanced tools to support the operators.

Introduction
The regulatory and advanced control, as well as real time optimization systems can provide many advantages for the industrial units, as improved stability and safety, respect to constraints and higher profitability. Figure 1 shows a schematic automation pyramid containing the regulatory and advanced control layers.
On the Role of HISC on Super and Hyper Duplex Stainless Steel Tubes
Authors: Salvio Filipe , S. Silva Bruno Raphael , dos Santos Dilson Silva 
Published: June 2014

Abstract
The Super duplex stainless steels (SDSS) are characterized by a remarkable combination of corrosion resistance and mechanical strength, mainly in chloride containing environments. Because of this, its demand is growing every year in offshore applications, becoming an alternative to the ferritic and austenitic stainless steels. Nevertheless, due to the lack of oil, the offshore companies are moving toward deeper waters and harsher environments, where it calls for the need of stronger materials. Facing this scenario, the Hyper duplex stainless steel (HDSS) was developed to achieve better properties than SDSS.
Despite the pronounced properties, the duplex grades can suffer environmentally induced cracking, as recorded in some failure cases of subsea structures. The driven force for these occurrences was the combination of three main factors: stress/strain, inappropriate microstructure and presence of hydrogen due cathodic protection (CP). In general, this set of events is called Hydrogen Induced Stress Cracking (HISC) within the offshore industry.
The SDSS and HDSS tubes in as-received condition were divided in two groups. One group was strain-hardened in order to simulate fabrication and laying operation. The second group was tested in annealed condition. For each, the tubes were cathodically charged for 160 hours in artificial seawater, under or without elastic stress, at cathodic potential equivalent of -1350 mVSCE. Then, the charged tubes were submitted to tensile testing and their HISC susceptibility was assessed. The fracture surfaces were analysed in order to identify the active micro mechanisms of failure.
The results showed that for the stressed/strain-hardened samples the embrittlement was more pronounced than the unstressed/annealed ones.

Introduction
Super duplex stainless steels (SDSS) are dual-phase steels containing austenite (γ) and ferrite (δ) as close to 50/50% distribution as possible. The synergic effect between both phases promotes a good combination of high mechanical strength and excellent resistance to stress corrosion cracking in chloride solutions, as well as in the presence of H2S and CO2. Due to the excellent agreement of properties, these steel grades are widely employed in the petroleum industry, highlighted in offshore applications such as subsea equipment, umbilical tubes and liner pipes [1–4].