bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reactive Hemophagocytic Syndrome in Adult Korean Patients with Systemic Lupus Erythematosus: A Case-Control Study and Literature Review
Authors: KIM JI-MIN , KWOK SEUNG-KI , JU JI HYEON , KIM HO-YOUN , PARK SUNG-HWAN 
Published: December 2011

Objective.To determine the characteristics of hemophagocytic syndrome (HPS) in adult Korean patients with systemic lupus erythematosus (SLE).Methods.We reviewed the medical records of 1033 adult patients with SLE for a recent 14-year period and identified 15 patients who had developed HPS. Forty-two age- and sex-matched patients with SLE admitted for other manifestations were included as disease controls. Features of HPS in these patients were analyzed.Results.Reactive HPS occurred from some distinct causes during the course of SLE. HPS was associated with SLE in 11 patients (4 at onset of SLE and 7 at SLE flare), infection in 3 patients (2 bacterial infection; 1 viral infection), and drug use (azathioprine) in 1 patient. Common clinical features included fever (93.3%), hepatomegaly (60.0%), and splenomegaly (60.0%). Steroid pulse therapy (46.7%), immunosuppressants (46.7%), and intravenous immunoglobulin (46.7%) were frequently used for treatment of HPS. One patient (6.7%) died. Compared with SLE patients without HPS, those with HPS showed a higher SLEDAI score (p = 0.003) and lower levels of plasma leukocytes (p < 0.001), hemoglobin (p = 0.013), and platelets (p < 0.001) as well as a higher serum C-reactive protein level (p = 0.039) and a lower serum albumin level (p = 0.004).Conclusion.HPS was observed in 1.5% of adult Korean patients with SLE. The occurrence of HPS was most frequently associated with the SLE disease activity. Profound pancytopenia, a high SLEDAI score, and notable changes in the level of acute-phase reactants can be the characteristics of SLE patients with HPS.
Simultaneous Juvenile Idiopathic Arthritis and Diabetes Mellitus Type 1 — A Finnish Nationwide Study
Authors: POHJANKOSKI HEINI , KAUTIAINEN HANNU , KORPPI MATTI , SAVOLAINEN ANNELI 
Published: December 2011

Objective.To describe the occurrence and main clinical and laboratory findings of patients having both juvenile idiopathic arthritis (JIA) and diabetes mellitus type 1 (DM-1) in a period of 30 years.Methods.Eighty-two patients having simultaneous JIA and DM-1 were identified in the reimbursement registers of the Finnish National Institute of Insurance during the period 1976–2005. Data on their clinical histories were collected from patient files.Results.Occurrence of simultaneous JIA and DM-1 increased 4.5-fold between the first (1976-85) and the last (1996–2005) decade. Prevalence of uveitis was 7%, of rheumatoid factor seropositivity 15%; 22% of patients had a third autoimmune disease [autoimmune disease (AID)], and 16% had serious psychiatric problems.Conclusion.The occurrence of patients with the 2 diseases, JIA and DM-1, increased over 3 decades. The prevalence of uveitis was low, the number of seropositive patients was high, and further cases of AID were frequent. Patients had multiple additional problems necessitating multiprofessional care.
Assessment of International Standards for Safe Exploration, Production and Transportation of Oil and Gas in the Barents Sea
Authors: Saebo Erling , Cammaert Gus 
Published: December 2011

Abstract
In 2007, Norwegian Foreign Minister Jonas Gahr Store initiated the " Barents 2020" project - a joint Norwegian-Russian project dedicated to establishing acceptable health, environmental protection and safety standards in the Barents Sea. Russia's experience of operations in harsh climate regions and Norwegian expertise in the field of offshore operations has resulted in the successful implementation of the project on the harmonization of standards for environmental protection and safety in a vulnerable Barents Sea. Cooperation continues and is now entering a new phase with the aim of preparing industry guidelines for selected topics not only for the Barents Sea, but also with a pan-arctic perspective. The main sponsors of the project are now Gazprom, Statoil, ENI, Total, Shtokman Development AG (SDAG), the Oil and Gas Producers Association (OGP) and Det Norske Veritas (DNV). The project is to be completed by December 2011. The main objective of this paper is to summarize the current findings and recommendations from the various expert groups involved in the project.

Abbreviations
In this report the following abbreviations are frequently referred to:API - American Petroleum InstituteCSA - Canadian Standards AssociationDIS - Draft International StandardDNV - Det Norske VeritasEER - Escape, Evacuation, and RescueHSE - Health Safety and EnvironmentIMO - International Maritime OrganisationISO - International Organisation for StandardizationMARPOL - International Convention for the Prevention of Pollution from ShipsNORSOK - Norwegian offshore Petroleum Industry StandardOGP - International Association of Oil and Gas ProducersRP - Recommended PracticeWG - Working Group

Conclusive Summary
The purpose of the Barents2020 project is to recommend HSE standards for common Norwegian - Russian application in the Barents Sea, for safeguarding people, environment and asset values in connection with oil and gas activities, including marine transportation. The underlying assumption is that petroleum operations in the Barents Sea should be at least as safe as those in the North Sea. Phase 1 of the project lasted from October 2007 to October 2008. The results of Phase 1 were documented in 5 " position papers??. These papers provided the basis for further work in Phase 2, lasting from November 2008 to March 2009, resulting in the special topics prioritized for further study in expert working groups in Phase 3. The selection of topics for further work was carried out in close cooperation between the Norwegian and Russian participating organizations. The process was constructive and quick, based on both Russian and Norwegian proposals. There was full agreement between the parties that these topics are important issues which need to be addressed in relation to safeguarding oil and gas operations in the Barents Sea.
Limit State Design Methodology for Offshore Pipelines against Ice Gouging - Industry Guidelines from the ICEPIPE JIP
Authors: Davies Graeme , Marley Mark , Mork Kim 
Published: December 2011

Abstract
Ice loads on buried pipelines through ice-soil-pipeline interaction is a field with limited industry experience. As exploration in Arctic and cold climate regions increases it is of great importance to understand and to design for the challenges offshore pipelines must be able to withstand in these harsh areas with a suitable level of confidence. Together with thirteen industry partners, DNV has carried out a joint industry project in order to better define and therefore understand the Arctic specific challenges to pipelines. This project has developed initial industry guidelines for offshore pipelines in cold climate regions, in general and for ice scour in particular.
A major design issue for Arctic offshore pipelines in shallow water is ice keels gouging the seabed and imposing loads on the pipeline through ice-soil-pipeline interaction. The industry has somewhat limited experience with deep ice gouges and ice keels interacting with buried pipelines. A common practice has been to bury the pipeline well below the deepest registered gouge mark in the relevant geographical area with the objective to limit the pipeline response. In order to render future projects in regions with severe ice gouges economically feasible whilst still being sufficiently safe there is a need to utilise modern design principles based upon statistical methods, advanced FE models calibrated to ice gouging tests, limit state design principles and strain based design.
The ICE PIPE JIP provided the introduction of a more systematic approach for the identification, quantification and ranking of design uncertainties, and how this could be adopted to existing pipeline design methodologies and criteria. This paper presents some pertinent results and recommendations from the ICEPIPE JIP. The paper presents a sample case study for how the assessment of some elements of statistical uncertainty can be used in the definition of the 100 year return period ice gouge depth. This paper highlights one methodology for approaching this and it is emphasised that not all the steps that would be required in design are included in this brief paper. A discussion on the use of advanced FE tools in the ICE PIPE JIP is also presented.
The Arctic Regulatory and Stakeholder Experience
Authors: Pavia Gene , Blue Shannon , Renkert Lindsay 
Published: December 2011

Abstract

Description of the Proposed Paper:
UMIAQ, LLC (UMIAQ) is a member of the Ukpea??vik Iñupiat Corporation (UIC) Family of Companies. UIC was incorporated in 1973 pursuant to the Alaska Native Claims Settlement Act as the Village Corporation of Barrow, Alaska. UIC provides social and economic benefits to more than 2,200 Iñupiat shareholders and incorporates the traditions of our ancestors into our business practices.
UMIAQ was formed to meet the growing service demands of the oil and gas industry operating on the North Slope of Alaska. UMIAQ has technical professionals experienced in strategic planning, permitting, and regulatory compliance. Our understanding of arctic operations and federal, state, and local permitting processes integrated with active local, regional, and regulatory stakeholder engagement has played a key role in advancing energy projects.

Application:
This abstract is based on our staff's decades of experience working in the stringent regulatory environment of the oil and gas industry in Alaska; particularly the North Slope. Understanding the unique Social, Political, Operational, Regulatory, and Technical (SPORT) drivers that shape onshore and offshore exploration and development projects is imperative to working in the Arctic. It is anticipated that increased regulatory and stakeholder scrutiny in the wake of the Macondo Blowout will introduce additional delays and regulatory burdens here in Alaska as well as in other domestic offshore settings.

Results, Observations, and Conclusions:
Energy project approvals are negotiated with regulatory decision makers. Laws, regulations, policies, and people dictate successful project approval acquisitions. A regulatory road map that includes frontloading pre-application processes and active approval facilitation surfaces project constraints early, and allows active management of issues including baseline data requirements, project approval criteria, mitigation, and compliance stipulations. Refined approaches and methods have proved successful in securing usable regulatory approvals while minimizing the risk of delays introduced by successful appeals and litigation challenges.

Significance of Subject Matter:
Executing a robust regulatory plan that integrates and balances SPORT drivers with proactive stakeholder outreach plays a key role in advancing energy projects in Alaska.
Application of the Buoy Network in the Barents Sea
Authors: Mathisen Jan-Petter , Bidlot Jean-Raymond 
Published: December 2011

Abstract
In order to collect data in support of weather forecasts, in particular for Polar Lows, two Wavescan metocean buoys were deployed in the western and central Barents Sea. In addition, another buoy was deployed off the northern coast of Norway, the latter buoy also provides data to a ship traffic emergency management system. As these data are freely available, they have also been used to validate weather forecasts from several meteorological agencies such as the European Centre for Medium Range Weather Forecasts (ECMWF). Generally model and observations agree well. As expected, some discrepancies exist. Some of these differences points to modeling issues and some to observations.

Background
The production of gas at Snøhvit, the development of the Stockman and Goliat fields and the recent border conflict settlement concerning the maritime border between Russia and Norway have resulted in increasing operational activities within the oil & gas sector in the Barents Sea. Moreover, there are several other key activities in the Barents Sea, such as fishing and the long-distance transportation of hazardous materials along the coast of northern Norway.
In order to support these activities in such a harsh environment, reliable weather forecasts are essential, in particular for safe operations. This is especially important due to the occurrence of Polar Lows in this area, as they are usually associated with rapid changes in weather and wave conditions. Various operators and contractors have highlighted the difficulties encountered with unpredictable downtime due to these peculiar local environmental conditions.
Even though the area of the Barents Sea is 13 million mFigure 1. These three buoys are now the backbone of the Barents Sea observing network. 2 or almost twice the size of the North Sea, there are few systematic in-situ meteorological observations between Bear Island in the West and Novalja Zemlja to the East. In order to collect data to support weather forecasting activities, Statoil deployed two Wavescan metocean buoys in the western and central Barents Sea during the winter of 2007. In addition, the Norwegian Coastal Administration and the Norwegian Radiation Protection Authority deployed another buoy off the northern Norwegian coast at the end of 2007. An additional purpose of the latter buoy was to obtain real time data in the case of shipping accidents along the coast.
Production of Light Oil from a Shallow Frozen Reservoir: A Redevelopment Case Study of the Umiat Oil Field, Northern Alaska
Authors: Hanks Catherine , Shimer Grant , Davis Jeremy , Wentz Raelene , Godabrelidze Vasil , Shukla Chinmay , Levi-Johnson Obioma , Huckaby Allen , McCarthy Paul , Mongrain Joanna , Dandekar Abhijit , Bangia Vijay 
Published: December 2011

Abstract
Shallow light oil accumulations in reservoirs within the permafrost are rarely recognized and, when identified, are often considered uneconomic because of their shallow depths and low reservoir energy. Horizontal drilling technology will improve the economics of these shallow accumulations, but a better understanding of the reservoir and fluid behavior under these low temperature and pressure conditions will improve recovery and lower development risk. However, little data is available on how a rock/ice/light oil system behaves at low pressures. This information and a robust reservoir model are needed to evaluate the effectiveness of different production methods in this type of accumulation.
The Umiat field of northern Alaska was discovered in the 1940's and is a remote, shallow, light oil accumulation consisting of multiple deltaic and marginal marine Cretaceous sandstones deformed by a thrust-related anticline. While the accumulation may be significant (1.2 billion barrels OOIP), it is shallow and partly in the permafrost zone.
New sedimentologic and structural studies indicate the reservoir has a complex permeability structure that will both impact both the placement of horizontal wells and subsequent reservoir performance. Reservoir sands generally consist of prograding wave-dominated shoreface deposits with good vertical permeability overlain by river-dominated deltaic deposits with poorer vertical permeability. Two different sets of natural fractures may also impart a strong permeability anisotropy to the reservoir.
The temperature profile of the reservoir will also impact reservoir performance and will have to be incorporated into the reservoir simulation. Fluid flow experiments on samples of the Umiat reservoir at sub-freezing temperatures show a reduction in gas and oil relative permeability in the presence of interstitial ice, with the greatest reductions at lower temperatures. A representative Umiat oil sample has been recreated and used to calibrate an Equation of State (EOS) model that can then be used to predict the properties of a representative Umiat fluid in the simulation.
Design Considerations for an Arctic Intervention Vessel
Authors: Berg Tor Einar , Berge Bjorn Ola , Hanninen Saara , Suojanen Reko-Antti , Borgen Henning 
Published: December 2011

Abstract
This paper describes ongoing work to tailor make an offshore intervention vessel for operations off the coast of Norway and in Svalbard waters. Operational requirements have been specified using subject matter experts from oil and shipping industries, equipment manufacturers and research organizations. A business case has been prepared for a vessel operating from a base in Northern Norway and serving two potential fields, one close to the coast of Finnmark (Goliat field) and the other one in the Olga Basin east of Svalbard. Available metocean and ice data have been collected and used for a parameter variation study of vessel characteristics. These data has also been used when selecting sea-state conditions to be used in the initial model test studies performed in MARINTEK's towing tank and ocean basin. The measured vessel response characteristics have been discussed with equipment manufacturers in an attempt to specify operational limits for key intervention tasks.

Background
Several studies point to a future need to increased production of offshore oil and gas in the Arctic region. The newly agreed Russian - Norway delimitation line in the Barents Sea will open up for increased activities in the Norwegian part of the Barents Sea. Most of the Norwegian part of the Barents Sea has a year-around open sea condition, but in the north-eastern part there is seasonal ice up to 3–4 months of the year. Designing an intervention vessel for operating under these conditions is a challenge as it needs high operability in both open water and first year ice.

The CIVARCTIC project
MARINTEK started work to describe a research and development project for an Arctic construction and intervention vessel in early 2008. A project proposal was approved by Research Council of Norway in June 2008 and the project started September that year. Project partners were:StatoilSTX Europe (now STX OSV Design)Norwegian University of Science and TechnologyMARINTEKAker Arctic TechnologyVTT
As shown in Figure 1 there is a number of design considerations for an arctic construction and intervention vessel. It has to be a stable working platform during intervention work in open seas, have low operational emissions during transit and operation, have sheltered working spaces to allow operations in the winter season and must be able to perform specific intervention operations in first year ice with a thickness up to 0.7.
10 Years of Sub Arctic Subsea Projects - Stepping Stones for Arctic Development
Authors: Allen S. 
Published: December 2011

Abstract
The Technip Group has conducted several subsea harsh environment projects over the last fourteen years, from Terra Nova and White Rose on the Grand Banks of Newfoundland in Eastern Canada to SnØhvit in Northern Norway and is preparing for future projects such as Goliat, also Northern Norway. These projects can be considered as true stepping stones towards oil and gas development in the Arctic region.
This paper, based primarily on operational experience, will provide an overview of the challenges faced working off the coast of Eastern Canada in the Jeanne D'Arc Basin, offshore Sakhalin Island and in Northern Norway, with specific reference to experience gained on the following projects: Terra Nova; White Rose; White Rose North Amethyst Extension; Sakhalin II and SnØhvit. The lessons learned from operations in harsh environments in relatively remote locations can be used to better prepare for any future operations undertaken in the Arctic.
The Terra Nova Project, conducted during the period 1997 through 2001 was the first sub-arctic subsea mega project. It was the first to use large scale open glory hole construction for iceberg protection and the first to deploy a disconnectable riser system in a harsh environment. Following on from Terra Nova, the White Rose project was built with strong reference to lessons learned from Terra Nova. Most recently, the White Rose North Amethyst extension project has expanded the knowledge base further. Offshore Sakhalin construction operations were successfully conducted with significant sea ice coverage. Construction offshore northern Norway brings its own challenges and lessons learned, particularly with respect to project planning and logistics.
It is not necessarily the individual challenges offered by the various environmental elements that make working in such areas so demanding, but the combination of wave, current, wind, fog, ice, soils and short season make the subarctic and arctic a very unique area of the world to undertake offshore operations. In addition to the environmental challenges, Northern Norway, Eastern Canada and Sakhalin offer excellent examples of working in remote areas with a lack of significant infrastructure and a reduced supply chain to call on.
This paper provides a point of reference for both operators and contractors looking to understand possible challenges associated with producing oil and gas in the Arctic and Sub-Arctic regions including: logistics, equipment specifications, installation planning, wellhead protection and the associated construction challenges and operations management within an environmental sensitive area.