bluuebunny/crossref_metadata_2025_split huggingface dataset:
ARKTOS Shear Zone Evacuation Craft Design Development
Authors: Hall T.A. , Seligman B.H.J.W. 
Published: December 2011

Abstract
The ARKTOS Evacuation Craft has been the primary means of emergency evacuation on Arctic and Caspian Sea bottom founded oil exploration and production facilities for over 20 years.
Oil production strategies are currently being developed by major oil companies beyond the Beaufort Sea Shear Zone, where the polar pack and landfast ice meet. The Shear Zone is formed by the moving polar ice pack shearing against the inshore ice that is held fast to the coastal seabed and the shore. Large, irregular ice features can be formed as a result of the shearing action as well as open leads with vertical ice freeboards.
A major area of concern for any development within and beyond the Shear Zone is Escape, Evacuation, and Rescue (EER) capability, due to the extreme environmental conditions that will be encountered. In response to a major oil company initiative, a conceptual design for a 75 person ARKTOS Amphibious Evacuation Craft suitable for operation in this region has been developed.
This paper describes continuing development of the ARKTOS Shear Zone Craft design, including the affect on performance in ice of increased Craft track width, extended track carriages, increased water jet thrust and hydrostatic drives in combination with inching mode. Also covered are self-righting capability and davit launching from a production platform onto ice or into open water.

Introduction
Existing offshore oil developments on the North Slope of Alaska are situated on natural or manmade gravel islands that are located within the Landfast Ice Zone. The Landfast Ice Zone extends between the coastline and the barrier islands and up to a few thousand feet beyond. ARKTOS Craft have been used for crew evacuation on all of these installations to date and are typically parked near the edge of the islands, and should an evacuation be necessary, are simply driven away from the island over the land-fast ice, through open water or broken ice/water mixture (Figure 1).
With the push to explore and develop Beaufort Sea oilfields further offshore within the Shear Zone and the Pack Ice Zone, gravity based or large floating offshore structures will be required. Personnel evacuation systems for these structures will face even more extreme conditions than the evacuation craft on existing U.S. Beaufort Sea offshore structures such as heavier sea states and mobile ice floes with substantial ice features.
U.S. Geological Survey Circum-Arctic Resource Appraisal
Authors: Gautier Donald L. 
Published: December 2011

Abstract
Among the greatest uncertainties in future energy supply is the amount of oil and gas yet to be found in the Arctic. Using a probabilistic geology-based methodology, the U.S. Geological Survey has assessed the area north of the Arctic Circle. The Circum-Arctic Resource Appraisal (CARA) consists of three parts:Mapping the sedimentary sequences of the Arctic (Grantz and others 2009),Geologically based estimation of undiscovered technically recoverable petroleum (Gautier and others 2009, discussed in this presentation) andEconomic appraisal of the cost of delivering the undiscovered resources to major markets (also reported at this conference by White and others).
We estimate that about 30% of the world's undiscovered gas and about 13% of the world's undiscovered oil may be present in the Arctic, mostly offshore under less than 500m of water. Billion BOE-plus accumulations of gas and oil are predicted at a 50% probability in the Kara Sea, Barents Sea, offshore East and West Greenland, Canada, and Alaska. On a BOE basis, undiscovered natural gas is three times more abundant than oil in the Arctic and is concentrated in Russian territory. Oil resources, while critically important to the interests of Arctic countries, are probably not sufficient to significantly shift the current geographic patterns of world oil production.

Introduction
The U.S. Geological Survey (USGS) has completed an assessment of the yet-to-find, technically recoverable petroleum in the Arctic. The Circum-Arctic Resource Appraisal (CARA) provides probabilistic estimates of the numbers, sizes, and aggregate volumes of oil, gas, and natural gas liquids in undiscovered accumulations (Gautier et al. 2009). Most discoveries will probably be made on the continental shelves, under less than 500 meters of water.
The CARA is a geologically study of the potential for new discoveries of conventional oil and/or gas in accumulations larger than 50 million barrels of oil or 300 billion cubic feet of natural gas north of the Arctic Circle. So-called unconventional resources such as coal bed methane, heavy oil and bitumen, and gas hydrates were not included in the study.
Before the assessment could be conducted, it was necessary to compile a consistent map of the sedimentary basins of the Arctic, delineated according to geologic age, tectonic history, thickness of sedimentary strata, and structural style (Grantz et al. 2009). Using the new map, the Arctic was subdivided into 69 geologically defined subsets called Assessment Units (AUs); the AU boundaries are available as digital shape files online (USGS 2009).
Resource Appraisal Technology for Undiscovered Arctic Petroleum
Authors: White L.P. Red , Verma Mahendra , Gautier Don 
Published: December 2011

Abstract
The Circum-Arctic Resource Appraisal (CARA) comprises three components:a geological map of Arctic sedimentary basins published by Grantz and others in 2009,a geologically based assessment of undiscovered technically recoverable resources published by Gautier and others in 2009, andan economic appraisal of the cost of delivering the undiscovered oil and gas resources to major markets.
This third component - the economic appraisal of the technically recoverable resources assessed by the CARA - is presented here for the first time in North America.
The economic appraisal consists of a prototype technology that augments the CARA assessment of technically recoverable resources with the addition of an economic benchmark. Our approach to this appraisal is to integrate the results of six separate technical efforts:the geologically based assessment of undiscovered technically recoverable resources,an empirically based statistical model of well flow rates,an experimental design model,a field development, production, and transportation model,a statistical cost estimation mode, anda hypothetical transportation system connecting the Arctic petroleum Provinces to major markets in the northern hemisphere.
The results of these six models are integrated in a Monte Carlo simulation of potential oil and gas accumulations for each CARA assessment unit (AU). Key parameters such as the number of fields, their volumes, well productivities, water depths, drilling depths, and distances from shore are simulated for each field in each AU. Exploration, development, production and transportation costs for each field and AU are estimated and then aggregated. The Monte Carlo simulation generates resource cost-volume curves for each AU and Province, displaying the probability range of volumes of oil or gas available to major markets as a function of unit cost. These Province curves are aggregated to a Circum-Arctic total.
The USGS is seeking collaborative relationships in the research and development of technology for the economic appraisal of undiscovered resources.
Overview of Case Studies for Draft ISO 19906
Authors: Thomas Graham A.N. , Masterson Dan , Spring Walt 
Published: December 2011

Abstract
The new international code ISO 19906 "Petroleum and natural gas industries - Arctic offshore structures" [1] was published in December 2010 after more than nine years of development, see Spring et al. [2]. Under the ISO process for standards development, ISO/DIS 19906 (the draft for public comment) was published in January 2009 and distributed to all ISO member countries for review and comment by June 2009. During this five-month period the opportunity was taken to perform case studies to ensure that the provisions of the code and its references were sufficiently complete for an experienced and knowledgeable engineer to design the structures within its scope. The objectives were to identify errors and gaps, ensure that diverse structures were adequately addressed, and to collate comments to the ISO draft for consideration by the Technical Panels with delegated responsibility for the provisions as they prepared the Final Draft. This paper sets out the case studies performed and the improvements arising in the final document resulting from comments provided by the organisations performing the case studies.

Introduction
The new ISO 19906 has been developed in Working Group 8 (WG8) of ISO Technical committee TC67/SC7 "Offshore structures". Experts from all arctic nations and from most other nations involved in the design of offshore structures in arctic and cold regions participated in WG8. Consequently, all the arctic nations and all European nations have undertaken to adopt ISO 19906 into their sets of national standards, and ISO 19906 is expected to be adopted worldwide for design of arctic offshore structures. WG8 and its supporting industry therefore decided to initiate a programme of case studies both to validate the standard and to start the process of industry engagement.
WG8 established TP10 "Case studies and calibration" in June 2008 to execute a calibration study and to perform case studies on ISO/DIS 19906. The members were volunteers from around the world, many from the oil and gas companies who would be future owners and operators of arctic offshore structures..
TP10 defined eight cases for study. Each case was for a specific structure type in a specified arctic region, with key parameters defined but otherwise it was left to the performer of the study to bring their experience and knowledge to complete the scenario. Proposals were sought from organizations around the world, including consultants, design contractors, universities, research institutes and classification societies. Forty seven offers were received, from North America, Europe and Russia, of which fifteen were contracted using industry funding and one was offered at no cost TP10 held five meetings and corresponded extensively by email and telephone conference calls. The OGP (the International Association of Oil and Gas Producers) facilitated funding from oil companies participating in WG8 and TP10 to fund TP10's activity. The OGP also acted as the administrator for the contracts required to execute the work directed by TP10.
Approach to Performance, Operability and Risk Assessment of the Shtokman Floating Platform in Ice
Authors: Liferov Pavel , Le Marechal Guillaume , Albertini Marc-Marie , Metge Michel , ter Brake Erik 
Published: December 2011

Abstract
The Shtokman Gas Condensate Field (SGCF) is located 610 km from Murmansk in the Barents Sea. The water depth at location is around 340 m. The offshore facilities of the SGCF Phase 1 development will include ice-resistant ship shape disconnectable turret moored floating platform (FP). Significant sea ice invasions occur at Shtokman in approximately 3 out of 10 years, on average. Icebergs may also occur in the SCGF area. Ice and iceberg management are planned to support the FP operations. The present paper describes the methodology to assess performance, operability and risk of the FP in waters where occasional invasion of sea and glacial ice is anticipated.

Introduction
Challenges with ice-related design and operating philosophy for the Shtokman FP have been described in [Ref. 1]. In brief, the main challenge is to achieve an appropriate reliability level and at the same time minimize operational downtime at acceptable costs. Table 1 summarizes the main ice-related challenges as identified in the pre-FEED and updated during the FEED, categorized by the accidental scenarios.
Actions have been taken in order to address the challenges and quantitatively assess the risks. It shall be emphasised that no attempt was made to target the design of individual components to achieve the target reliability level for the entire system, i.e. floating platform with respect to ice actions. This is simply because it would have been too speculative given all the uncertainties involved. On the contrary, it was decided early to establish challenging but realistic design targets for the main systems (e.g. hull, mooring and disconnection system) and in parallel, work on design of the operational measures, including assessment of their efficiency and reliability. Further, quantitative operability and risk assessments of the entire system have been performed to evaluate potential needs for optimisation.
The objective of this paper is to present the approach developed and used for assessing performance, operability and risk of the Shtokman Floating Platform with regard to sea and glacial ice. The content of this paper is based on numerous studies performed to provide input for the Final Investment Decision.
Reliability of Power Supply in Remote BGV/RGV Stations Along the Pipeline, a Key Factor for Arctic Pipelines Operation
Authors: Gropper Jean 
Published: December 2011

1. INTRODUCTION
One of the most serious problems in strategic pipeline projects is the need for reliable power for unattended stations in the severe environments under which these pipelines must continuously operate (temperatures as low as −55°C (−67°F) in winter, roads to the stations inaccessible for long periods of time making the stations inaccessible for maintenance crews, etc).
The objectives for high reliability in RGV operation, telecommunications, cathodic protection and SCADA systems in strategic projects have become staggering. In areas not serviced by commercial power, the problems faced by the power systems designers are very stringent since power generators must operate continuously on a 24 hour-per-day basis 365 days per-year.
The high reliability of the power supply in remote stations along the pipeline can be achieved by:–Selection of the most reliable remote power generators–Providing adequate redundancy of power generators
Telecommunications, SCADA, cathodic protection facilities along oil and gas pipelines are mission-critical, carrying vital performance, telemetry and control data.
The use of specially designed, arctic type, Closed Cycle Vapor Turbogenerators and their associated non-electric heating systems in arctic telecommunication systems has solved two of the most stringent problems of the pipeline operators: reliable remote power up to 4 kW is provided with maintenance requirements reduced to a visit only once in 6 months or more, and required temperature ranges in equipment shelters are maintained, assuring correct operation of the sensitive electronics, without any need of electrical power.
This paper reviews the key criteria to consider in selecting power solutions for remote site applications and CCVT performance is reviewed. The paper goes on to present case histories, including the Alaska pipeline, that demonstrate the field reliability and performance of CCVTs over the last thirty five years.

2. CRITERIA FOR SELECTING POWER SOLUTIONS FOR REMOTE SITES
There are a number of critical parameters which must be assessed when selecting a power solution for a network or a specific remote site.

Reliability.
Because these critical remote sites are difficult (and expensive) to reach - or are inaccessible for part of the year, reliable operation is extremely important. Reliability is typically measured in terms of Mean Time Between Failure (MTBF). CCVT technology has a proven performance history, demonstrating over 200,000 hours MTBF for the turbine and 30,000 hours MTBF for the entire system. These data are based on thirty seven years of field experience.
Cathodic Protection Design Considerations for Offshore Structures in the Arctic Environment
Authors: Weldon Clark P. 
Published: December 2011

Abstract
The Arctic imposes unique challenges for design of cathodic protection (CP) systems for offshore structures. These include alternative structure designs, and environmental factors such as pack ice, high water resistivity, extreme tidal velocities and amplitudes, and severe weather. Traditional approaches to CP design for offshore structures are typically not suitable for service in Arctic conditions. Adaptations include almost exclusive use of impressed current or hybrid CP systems, versus traditional sacrificial anode designs, specialized anode deployment and cabling systems, and design of CP monitoring equipment suitable for Arctic conditions.
The effect of Arctic conditions on CP current requirement, anode current output, anode material selection, anode configuration, cabling systems and power supplies is discussed. Case histories of specialized CP designs for offshore structures in the Russian Arctic and Cook Inlet are presented. These case histories include relevant CP design, construction, installation and operating details.

Introduction
Cathodic protection using distributed weld-on aluminum alloy anodes has become the offshore industry standard for corrosion control on immersed surfaces of offshore structures in most oil producing areas of the world. Aluminum anodes with a design life equal to the expected service life of the platform are welded to the structure in the fabrication yard. Use of coatings is typically limited to the splash zone areas and the inside of ballast tanks on floating structures. These stand-alone sacrificial anode systems are essentially maintenance free, except in the rare instances where anode retrofit is required to extend the platform service life. The use of impressed current cathodic protection (ICCP) systems is generally limited to floating vessels such as FPSOs or drill ships, and for anode retrofit.
With respect to cathodic protection design, offshore structures located in Arctic/subArctic regions subject to the presence of sea ice, frigid temperatures and other extreme environmental conditions often require a different approach. The demands of the Arctic environment impact cathodic protection design in two general ways - electrochemically and mechanically. Electrochemical impacts include, but are not limited to, increased current requirement, higher seawater resistivity, reduced anode performance and higher rectifier voltage requirements. Mechanical affects are considered those that impact the design of cathodic protection hardware with respect to resistance to physical damage. These include the damage from ice impact and/or abrasion, freezing and wave/current forces. In some cases, mechanical and electrochemical effects are combined, as in the mechanical removal of calcareous deposits by ice or wave action, which increases current requirement.
Supramolecular Dye Inclusion Single Crystals Created from 2,3,6‐Trimethyl‐β‐cyclodextrin and Porphyrins
Authors: Tsuchiya Youichi , Shiraki Tomohiro , Matsumoto Takashi , Sugikawa Kouta , Sada Kazuki , Yamano Akihito , Shinkai Seiji 
Published: December 2011

AbstractIn Nature, chromophoric groups play various roles, such as oxygen carriers, electron donors, light sensitizers, which are achieved in many cases by control of their aggregation modes in proteins. Host–guest chemistry between cyclodextrins and porphyrins has attracted great interest from supramolecular chemists because of their unique structures and functions that mimic those of proteins with chromophoric prosthetic groups. To mimic Nature’s contrivances, the host–guest systems between cyclodextrins and porphyrins have frequently been studied. It is really surprising, however, that to date no detailed structural information of these complexes has been obtained from single‐crystal analysis. In 2011, we reported the first successful isolation of a dye inclusion single crystal (DISC) between 2,3,6‐trimethyl‐β‐cyclodextrin (TMβCD) and 5,10,15,20‐tetrapyridylporphyrin (TPyP), and analyzed its X‐ray crystal structure. The crystal structure revealed not only the real complex mode but also the attractive orientation of TPyP in the DISC. Herein, we present new strategies to prepare DISCs of TMβCD for several porphyrins and provide crystal structures, details of the complex modes, and optical properties. We believe that the present study has various important implications not only for the basic crystal analysis of inclusion complexes but also for potential applications that use these single crystals.
Extended field stereotactic radiosurgery for recurrent glioblastoma
Authors: Koga Tomoyuki , Maruyama Keisuke , Tanaka Minoru , Ino Yasushi , Saito Nobuhito , Nakagawa Keiichi , Shibahara Junji , Todo Tomoki 
Published: December 2011

AbstractBACKGROUND:Stereotactic radiosurgery (SRS) is among the few therapeutic options for glioblastoma that recurs after standard radiation and chemotherapy, but its efficacy has been limited.METHODS:Since November 2007, the authors have modified the clinical target volume by adding a 0.5‐ to 1‐cm margin to the gadolinium‐enhanced area (extended field SRS), in contrast to conventional SRS using no margin to set the clinical target volume. A total of 35 recurred glioblastoma lesions in 9 patients were treated with conventional SRS between December 1990 and January 2007, and 14 lesions in 9 patients were treated with extended field SRS.RESULTS:The median follow‐up periods were 7 months (range, 3‐29 months) and 8 months (range, 6‐27 months), respectively. The local control rate was 47% for conventional SRS and 93% for extended field SRS (P = .0035), and the numbers of radiation necrosis observed in SRS‐treated lesions were 2 and 4, respectively. The median overall survival from the diagnosis was 24 months (range, 14‐57 months) for conventional SRS and 21 months (range, 15‐51 months) for extended field SRS (statistically not significant). Seven patients treated with conventional SRS died during follow‐up, 6 from progression of the SRS‐treated tumor, whereas 7 patients treated with extended field SRS died during follow‐up, 6 from remote intracerebral dissemination.CONCLUSIONS:Extended field SRS was superior to conventional SRS in the local control of small recurrent lesions of glioblastoma, although a further device to suppress remote dissemination may be necessary to increase survival. Cancer 2012. © 2011 American Cancer Society.
Highly Water‐Dispersible Fe3O4 Single Nanocrystals: Gram‐Scale Preparation by a Solution‐Phase Route and Application for the Absorption of Cd2+ in Water
Authors: Guan Xiao‐Hui , Zheng Bo‐Tian , Lu Min , Guan Xin , Wang Guang‐Sheng , Guo Lin 
Published: December 2011

AbstractFe3O4 nanocrystals with narrow particle size distribution (10–15 nm) were produced in high yield by using a simple solution‐phase method at room temperature. In this approach, the iron oxide nanocrystals can be continually prepared through controlling the pH value of the solution. The as‐synthesized Fe3O4 nanoparticles are single‐crystalline and exhibit high saturation magnetization. New adsorbents of Fe3O4 nanocrystals immobilized on bacterial cellulose (FNBC) were prepared by a simple blending method in the hope of removing heavy metal ions from aqueous solutions. The FNBC showed significantly higher affinity for removing Cd2+ compared to BC. In addition, the effect of characteristic parameters such as pH value, adsorption time by simulating the adsorptive kinetics, and adsorptive isotherms were also investigated.
Towards Allopumiliotoxins: A Concise Synthesis of the Indolizidine Core
Authors: Vijaykumar Bodduri V. D. , Mallesham Pitchakuntla , Chandrasekhar Srivari 
Published: December 2011

AbstractThe common bicyclic indolizidine core present in several allopumiliotoxins was synthesized by the sequential use of a Crimmins' aldol reaction, an SOCl2‐mediated SNi displacement, and an intramolecular nucleophilic acyl substitution (INAS) as the key transformations.