bluuebunny/crossref_metadata_2025_split huggingface dataset:
Multiplex Immunoassays of Peptide Hormones Extracted from Formalin-Fixed, Paraffin-Embedded Tissue Accurately Subclassify Pituitary Adenomas
Authors: Strathmann Frederick G , Borlee Grace , Born Donald E , Gonzalez-Cuyar Luis F , Huber Bertrand R , Baird Geoffrey S 
Published: December 2011

AbstractBACKGROUNDThe current gold standard for diagnostic classification of many solid-tissue neoplasms is immunohistochemistry (IHC) performed on formalin-fixed, paraffin-embedded (FFPE) tissue. Although IHC is commonly used, there remain important issues related to preanalytic variability, nonstandard methods, and operator bias that may contribute to clinically significant error. To increase the quantitative accuracy and reliability of FFPE tissue–based diagnosis, we sought to develop a clinical proteomic method to characterize protein expression in pathologic tissue samples rapidly and quantitatively.METHODSWe subclassified FFPE tissue from 136 clinical pituitary adenoma samples according to hormone translation with IHC and then extracted tissue proteins and quantified pituitary hormones with multiplex bead-based immunoassays. Hormone concentrations were normalized and compared across diagnostic groups. We developed a quantitative classification scheme for pituitary adenomas on archived samples and validated it on prospectively collected clinical samples.RESULTSThe most abundant relative hormone concentrations differentiated sensitively and specifically between IHC-classified hormone-expressing adenoma types, correctly predicting IHC-positive diagnoses in 85% of cases overall, with discrepancies found only in cases of clinically nonfunctioning adenomas. Several adenomas with clinically relevant hormone-expressing phenotypes were identified with this assay yet called “null” by IHC, suggesting that multiplex immunoassays may be more sensitive than IHC for detecting clinically meaningful protein expression.CONCLUSIONSMultiplex immunoassays performed on FFPE tissue extracts can provide diagnostically relevant information and may exceed the performance of IHC in classifying some pituitary neoplasms. This technique is simple, largely amenable to automation, and likely applicable to other diagnostic problems in molecular pathology.
Experimental Evidence for Nitrogen as a Deep Acceptor in ZnO
Authors: Tarun M.C. , Iqbal M. Zafar , McCluskey M.D. , Huso J. , Bergman L. 
Published: December 2011

ABSTRACTWhile zinc oxide is a promising material for blue and UV solid-state lighting devices, the lack of p-type doping has prevented ZnO from becoming a dominant material for optoelectronic applications. Over the past decade, numerous reports have claimed that nitrogen is a viable p-type dopant in ZnO. However, recent calculations by Lyons, Janotti, and Van de Walle [Appl. Phys. Lett. 95, 252105 (2009)] suggest that nitrogen is a deep acceptor. In our work, we performed photoluminescence (PL) measurements on bulk, single crystal ZnO grown by chemical vapor transport. Nitrogen doping was achieved by growing in ammonia. In prior work at room temperature, we observed a broad PL band at ∼1.7 eV, with an excitation threshold of ∼2.2 eV, consistent with the calculated configuration-coordinate diagram. In the present work, at liquid-helium temperatures, the PL emission increases in intensity and red-shifts by ∼0.2 eV. A peak is observed at 3.267 eV, which we tentatively attribute to an exciton bound to a nitrogen acceptor. Our experimental results indicate that nitrogen is indeed a deep acceptor and cannot be used to produce p-type ZnO.
Nitrocellulose and BKNO3 Based Igniters for Gun Systems.
Authors: Rozumov Eugene , Adam Carlton P. , Manning Thelma G. , Laquidara Joseph M. , Chung Kimberly , Park Duncan , Panchal Viral 
Published: December 2011

ABSTRACTCommon igniters such as black powder, benite, and boron potassium nitrate (BKNO3) are routinely employed in all calibers of gun systems. Armament Research Development Engineering Center (ARDEC) has pursued efforts to improve the ignition of gun propellants which has been demonstrated to be the root cause of many tribulations for gun systems. We have developed several extrudable nitrocellulose-BKNO3 based igniter materials that are more energetic, and exhibit smaller ignition delay times than most traditional igniters. We have demonstrated this via static firing. High speed video during static testing has demonstrated significantly more consistent, intense, and rapid flame generation in comparison to Benite leading to improved ignition effectiveness of the propellant bed.
Gaussian distribution of Schottky barrier heights on SnO2 nanowires
Authors: Amorim Cleber A. , Berengue Olivia M. , Araújo Luana , Leite Edson R. , Chiquito Adenilson J. 
Published: December 2011

ABSTRACTIn this work, we studied metal/SnO2 junctions using transport properties. Parameters such as barrier height, ideality factor and series resistance were estimated at different temperatures. Schottky barrier height showed a small deviation of the theoretical value mainly because the barrier was considered fixed as described by ideal thermionic emission-diffusion model. These deviations have been explained by assuming the presence of barrier height inhomogeneities. Such assumption can also explain the high ideality factor as well as the Schottky barrier height and ideality factor dependence on temperature.
Novel Approach to More Effective Plug and Abandonment Cementing Techniques
Authors: Ferg Thomas E. , Lund Hans-Jacob , Mueller Dan , Myhre Morten , Larsen Arne , Andersen Patrick , Lende Gunnar , Hudson Charlie , Prestegaard Cato , Field David 
Published: December 2011

AbstractThe effectiveness of a permanent abandonment plug is measured by its ability to bridge the wellbore cross section both vertically and horizontally, including all annuli, with a plugging medium which can withstand the rigors of the environment to which it is exposed (Figure 1 – Barrier Requirements). The most common method for placing a plug in cased hole with an uncemented annulus has required section milling of the casing, making a clean out run and underreaming of the open hole prior to placing a balanced cement plug. A new method is presented which creates a permanent abandonment plug through the use of a system which perforates uncemented casing, washes the annular space and then mechanically places the cement across the wellbore cross section in a single run. This paper outlines the design methods, laboratory testing and operational elements that were assessed during the development phase, as well as the results of field trials used to qualify this technique.
1000 Km of Under Ice Seabed Survey with an AUV
Authors: Mills Richard , Fergsuon James , Laframboise Jean-Marc , Kaminski Chris , Crees Tristan 
Published: December 2011

AbstractIn March and April 2010, an ISE Explorer Autonomous Underwater Vehicle (AUV), built for Natural Resources Canada (NRCan), was deployed to Canada's high Arctic. Its mission was to undertake under-ice bathymetric surveys in support of Canada's submission to establish the outer limits of its continental shelf under the United Nations Convention on the Law of the Sea (UNCLOS). During this deployment several under-ice records were broken and several new technologies were demonstrated.NRCan's AUV is an ISE Explorer class vehicle, with several innovative additions to make it suitable for arctic survey work. Most notable are a 4000 m depth rated variable ballast system, a 1500 Hz long-range homing system, and under-ice charging and data transfer capabilities. A Short-Range Localization (SRL) system was also developed for close range positioning. The homing and SRL systems were developed by Canadian defense scientists and engineers at DRDC (Defence Research and Development Canada).The Explorer's range was extended to approximately 450 km by adding a hull section to accommodate extra batteries. The scientific payload onboard included a Seabird SBE49 Conductivity-Temperature-Depth (CTD) sensor, Knudsen singlebeam echosounder, and a Kongsberg Simrad EM2000 multibeam echosounder. In order to optimize battery endurance, the plan was to only turn on the EM2000 at strategic locations (i.e. potential sea mounts) along the mission path.The Main Camp near Borden Island (78°14’N, 112°39’W) was the launch site for the AUV. It was launched from an 8 m by 3 m ice hole, cut through 2 – 3 m thick ice. After several test dives, the first mission was a transit to a Remote Camp, 320 km to the northwest. The AUV autonomously homed into the Remote Camp and was secured with the help of a small remotely operated vehicle (ROV). Without being removed from the water, it was charged and survey data was downloaded, all through a 1.3 m by 2 m ice hole. Subsequently, a second survey mission was undertaken in a region known as the Sever Spur (~79°N, 115°W), which returned back to the Remote Camp. Finally, it embarked on a return transit mission to the Main Camp for recovery. The AUV spent 10 days under ice before being successfully recovered. In total, close to 1000 km of under-ice survey was accomplished between the 3 missions. The AUV reached depths of 3160 m and transited at an average speed of 1.5 m/s at an altitude of 130 m above the seabed. From operating entirely under ice, to surveying in such a challenging environment, to the distances and objectives, this is an historic milestone in AUV and polar science. ISE, DRDC and NRCan are now preparing for a 2011 deployment to collect additional arctic survey data.
Offshore Pipeline Installation in Arctic Environment
Authors: Lange Frank , van Zandwijk Kees , van der Graaf Jan 
Published: December 2011

Abstract
In the arctic environment the installation of pipelines offshore and in the area between land and sea is a challenge. The remote logistics, the short and unpredictable season and the trenching and burial in often not well known possibly permafrost soils require novel approaches all under the requirement of leaving a minimal environmental footprint. Based on the experience Heerema Marine Contractors (HMC) has in the installation of pipelines and pipeline trenching and studies performed for the Baydaratskaya Bay crossing and for the Beaufort Sea, approaches will be presented for the installation of pipelines in arctic and extreme environments. They are based on recent studies partly done in-house and partly for and with industry clients.
Offshore Arctic Drilling System Selection Process: Water Depths from 50 - 500 meters
Authors: Simpson Richard 
Published: December 2011

Abstract
Recent offshore lease sales in Canada have made available the opportunity to explore for oil and gas in the Polar Arctic regions of the Beaufort Sea. BP Exploration Operating Company Limited (BP) was awarded Exploration Licenses 449, 451, and 453 in 2008. The focus of this paper is upon selection of an Offshore Arctic Drilling System for Exploration Licenses 451 and 453 as, BP formed a Joint Venture in 2010 with Exploration License 449 where operatorship was designated to another company.
Due to the wide range of ice conditions and water depths in the lease areas, determining the most capable Offshore Arctic Drilling System is a complex undertaking. Detailed are the considerations and methodologies utilized to recognize and quantify the key challenges involved. Once identified, these challenges were divided into discreet elements so as to progress multiple solutions in parallel in order to determine the true limits of opportunities to provide for a safe and efficient drilling program.
Rapid progress was obtained through extensive collaborative engagement with Drilling Contractors, Vessel Operators (including Ice Breaking, Anchor Handling, and Supply Vessel), Remote Imaging Service Providers (Satellite and Autonomous Vehicles), Numerical Modeling Specialists, Vessel Designers (Naval Architects and Marine Engineers), Equipment Manufacturers (Dynamic Positioning Systems, Mooring Systems, Thrusters), Drilling Subject Matter Experts, and recognized individual Arctic Experts.
New Well Foundation Concept, As Used at a Norwegian Sea Well
Authors: Sivertsen Trond , Strand Harald 
Published: December 2011

Abstract
A new and safer, high load capacity well construction concept has been developed. This new well foundation system as installed at a Norwegian Sea well location by Det norske oljeselskap ASA, is described herein, as well as its use and recovery. Heavy Blow Out Preventers (BOP) are normally used on drilling rigs designed for deep water and arctic applications, and heavier BOPs will have a negative impact on the stability of the well head. To mitigate these negative impacts, a new suction anchor type well foundation concept; CAN (Conductor Anchor Node) has been developed. The CAN unit provides sufficient load capacity for safely carrying heavy BOPs as well as X-Mas trees, thus protecting the well from fatigue capacity "consumption" in the drilling phase. The use of the concept will also reduce cuttings and cement disposal to the sea, which may be further important aspects in arctic and sensitive marine environment areas.
The CAN will also mitigate the risks of the well becoming over-loaded by undesired, accidental loads, e.g.: as a result of a rig drive off/drift off situation. This is achieved by mobilising substantial carrying capacity from the soil through the CAN's large cross sectional area and captured soil mass. This is an important aspect in view of risk mitigation and improving possibilities of applying contingency means in case of undesired events or disasters, such as the Macondo case.
The concept offers significant advantages in reducing rig time; as it enables pre-rig conductor installation, thus reducing top-hole construction costs and rig failure risk exposure. The concept's viability and advantages have been demonstrated by a number of full scale applications ranging from 270 m to 1 150m water depth on the Norwegian Continental Shelf.
The CAN will be a facilitator for safe jetting of conductors (only short length conductor needed), as well as being an enabler for achieving successful cement jobs (if installed by drilling and cementing), as the conductor remains supported and motionless during cement set-up.
Think Before You Shoot: Planning and Piloting Seismic to Maximize Value - Russkoye Field Case Study
Authors: Zhukov Artem , Priebe Hermann , Demushkin Alexey 
Published: December 2011

Abstract
Accurate reservoir models are an important pre-requisite for optimum development of oil and gas fields. In order to build these models good quality input data from well logs and seismic surveys are essential. The integration of these data provides a robust groundwork for generating reliable maps of subsurface structures and credible predictions of reservoir presence and quality distribution. Such well-constrained models can add technical and commercial value when used to generate, evaluate and optimize field development scenarios and production profiles.
Many hydrocarbon fields in Russia were discovered back in the 1960-70s and therefore are often short on good quality well and seismic data. Geological and geophysical data (especially well logs) were acquired a relatively long time ago and can no longer meet increasingly rigorous standards essential to support reservoir quality prediction and to maintain and update subsurface models (that integrate geological and seismic information) throughout life of field. It is the quality of this data, however, that drives optimization of well pad drilling, development drilling success rates and better reservoir management on field margins.
Key limitations associated with vintage log data are as follows:
Logs were traditionally run exclusively over main pay zones without investigating the full length of the wellbore; Limited logging programs with a modest range of log types (commonly missing formation density logs, full-wave sonic logs, etc.); Lack of vertical seismic profiling (VSP) data to accurately tie well and seismic data; Poor quality of well data acquisition and processing.
Potential For Oil And Gas Projects In The New Oil And Gas Province Shared Between Russia And Norway
Authors: Bulakh Maria , Zolotukhin A. B. , Gudmestad O. T. 
Published: December 2011

ABSTRACT
The recent agreement between Russia and Norway regarding the border between the countries in the Barents Sea offers unprecedented opportunities for Norwegian-Russian cooperation in developing oil and gas fields. In this paper we summarize information about the agreed state borders in the former disputed ("grey") zone of the Barents Sea, see Figure 1, and suggest possible scenarios for the oil and gas fields’ development.
The "Grey Zone" area is about 175 thousand km2 in which, according to official estimates, is concentrated around 1% of world's undeveloped oil reserves. The resources of the former disputed territory are potentially about 410 million tons of oil and nearly 6 trillion cubic meters of natural gas. According to preliminary estimates the largest deposit is the Fedynskoe field. Its resources are expected to be around 10-12 billion boe or but may potentially be as high as 18 billion boe.
The "Grey Zone" can be regarded as a key for development of hydrocarbons in. the Barents Sea area due to following circumstances: it has favorable environmental and geographical conditions such as being year-round ice free, relatively shallow water – 200-300 meters and short distance to shore about 100 km. Its location is appropriate for easy organization of export of oil and gas from the northern regions.
The financial costs of the development of the "Fedynskoe raising" (Fedyn Arch) will be significantly lower than in other Barents oil and gas areas further North or East. There might be huge interest by investors in this area. The investments on the Shtokman field development could be reduced taking into account the possibility of a joint infrastructure solution for these fields’ development.
It seems interesting to consider an integrated planning. In the present paper we are discussing possible options for development and arrangement of the Fedynskoe field in relation to scenarios of Shtokman field planning.
Despite the favorable ice conditions in this region we cannot exclude the possibility of drifting sea ice and icebergs. Taking into account the tendency of ice melting it is needed to maintain ice drift forecasting. Furthermore, polar low pressures and sea spray icing are important operational and design considerations.
An analysis of existing technical solutions and facilities gives ideas for creating extraordinary and sophisticated oil and gas centre(s) in the Barents Sea region.
The Kara Sea Offshore as a Strategic HC Recourse Base in the 21st Century-Possible Solutions of Developing According to the Estimate of the Economy Uncertainties by Fuzzy Theory
Authors: Bulakh Maria , Zolotukhin A. B. , Gudmestad O. T. 
Published: December 2011

Abstract
Huge reserves of hydrocarbons at the Kara Sea offshore region which is adjacent to the west coast of the Yamal Peninsula are to be developed in the nearest years. This large oil and gas area has prospective resources about 56 trillion barrels of oil equivalents (boe). The Russia Federation has not other regions with similar concentrations of the undeveloped hydrocarbons. Creating this unique the Kara Sea gas production centre could provide in the years 2015-2030 a production at least 800 billion Sm3 of gas per year providing both domestic and external demand with this fuel. The paper presents the main problems and possible solutions of developing such a harsh region in the Arctic conditions.
Hindered Strength Development in Oil Well Cement due to Low Curing Temperature
Authors: Reinås Lorents , Hodne Helge , Turkel Mirkamil A. 
Published: December 2011

AbstractThis paper reports laboratory test results on early strength development of Portland Class G oil well cement slurries with different W/C ratio at ambient and low temperatures. One commercial slurry has been included for reference to industrial practices. The slurries have been cured and tested under laboratory conditions (+20°C) and at lower temperatures (+7°C, +4°C and 0°C) believed to be more representative of arctic and deepwater seabed conditions. Compressive strength development has been monitored using Ultrasonic Cement Analyser (UCA). The test results quantifies delayed initial setting and hindered development of compressive strength at low curing temperatures and with increasing W/C ratio.In arctic subsea wellheads the curing condition for lead cement close to seabed will be low in temperature due to cooling from low seabed seawater temperatures. The time to reach 50 psi (0,345 MPa) compressive strength can be more than 24 hrs depending on the slurry temperature and its W/C ratio. Initial setting is delayed significantly with decreasing temperature and with increasing W/C ratio. Rate of compressive strength development is also significantly delayed with decreasing temperature and with increasing W/C ratio. Most lead cement systems used have a high W/C ratio. Typical time between cementing and connection of the BOP/riser in North Sea operations is 24 hrs. Once a subsea BOP/riser gets connected to a wellhead dynamic loading will start, resulting in movements of the surface casing relative to the conductor casing. This is a local effect concentrated to the upper part of the surface casing. If loading of the surface casing starts before the cement has developed ample strength, localized failure of the cement should be expected to occur.
Environmental Baseline Research in the Canadian Beaufort Sea
Authors: Pyc Cynthia , Fortier Martin 
Published: December 2011

Abstract
It is generally understood that hydrocarbon exploration in the circumpolar Arctic will increase in the coming years to meet growing global energy demands. Concurrent with consumer demand is an equally important obligation to demonstrate adequate environmental understanding and risk-based operations planning prior to conducting responsible exploration and development. This is particularly the case in sensitive, extreme and remote environments like the Arctic.
To demonstrate environmental knowledge and inform project planning and equipment selection early in the exploration drilling phase, BP Exploration in Canada collected environmental, geotechnical and geochemical data in the southern Beaufort Sea over two field seasons in 2010 and 2011. The research was conducted as part of the ongoing research effort of ArcticNet; an independent academic network of Canadian and foreign university and government scientists. From the Canadian research icebreaker CCGS Amundsen, a multi-disciplinary team of academic researchers and industry experts collected data on ocean circulation, chemistry and productivity; zooplankton, ichthyoplankton and benthos distribution, diversity and abundance; baseline contaminant levels in sediment and water; surface meteorology; ice properties and concentration; and marine mammal presence and movement. In addition, a significant geotechnical, geohazards and geochemical survey was completed using the hull-mounted sonars and coring equipment of the vessel.
The large amount of information collected is already informing operational plans related to drilling equipment, drilling design and environmental impact assessment. Key technical input includes ice-loads related to bearing capacity of drill systems; and sediment strength measurements input to anchoring and casing design. Geochemical analysis of piston cores collected during the field program has provided insights into the petroleum system of the area. Multibeam echosounder, high-resolution images of the sea floor are providing the accurate geohazards identification and understanding critical to safe well placement and design.
This paper describes how environmental data was obtained through industry-academia collaboration over two field seasons and how the data may input into oil spill trajectory modeling, cutting disposal modeling, environmental impact assessment, as well as mitigation and monitoring strategies.