bluuebunny/crossref_metadata_2025_split huggingface dataset:
Environmental Factors Associated With Social Participation of Older Adults Living in Metropolitan, Urban, and Rural Areas: The NuAge Study
Authors: Levasseur Mélanie , Cohen Alan A. , Dubois Marie-France , Généreux Mélissa , Richard Lucie , Therrien France-Hélène , Payette Hélène 
Published: February 2015

Objectives. We compared the social participation of older adults living in metropolitan, urban, and rural areas, and identified associated environmental factors. Methods. From 2004 to 2006, we conducted a cross-sectional study using an age-, gender-, and area-stratified random sample of 1198 adults (aged 67–82 years). We collected data via interviewer-administered questionnaires and derived from Canadian censuses. Results. Social participation did not differ across living areas (P = .09), but after controlling for potential confounding variables, we identified associated area-specific environmental variables. In metropolitan areas, higher social participation was associated with greater proximity to neighborhood resources, having a driver’s license, transit use, and better quality social network (R2 = 0.18). In urban areas, higher social participation was associated with greater proximity to neighborhood resources and having a driver’s license (R2 = 0.11). Finally, in rural areas, higher social participation was associated with greater accessibility to key resources, having a driver’s license, children living in the neighborhood, and more years lived in the current dwelling (R2 = 0.18). Conclusions. To enhance social participation of older adults, public health interventions need to address different environmental factors according to living areas.
Revolutionary, Evolutionary Ideas for Lowering the Cost of Gas Separation
Authors: Rassenfoss Stephen 
Published: February 2015

CO2 removal
Demand for a better way to remove carbon dioxide (CO2) from natural gas led to the creation of a new material at Rice University in Houston that does something unprecedented on the molecular scale, and might even change gas processing.
For professor James Tour, the fundamental science behind this porous carbon material created in his laboratory “is really profound.” The black powdery material developed by a Rice graduate student, Chih-Chau Hwang, absorbs nearly its weight of carbon dioxide by creating long polymer chains of carbon dioxide at a pressure level that is elevated, but easily attained, in a gas processing facility.
For Tour, it is an exciting development because the carbon dioxide polymer structure, which was observed using spectroscopy, is something that he said has never been seen in nature, and only rarely in labs at extreme pressures. But the pioneering chemist recognizes that for those developing new oilfield technologies, what matters is what it can do, not how it might do so.
Rice’s patents have been licensed by Apache Corp., which supported research seeking a new material for gas separation for the past 2½ years. On the plus side, it appears to be energy-efficient, can hold a large volume relative to its weight, and is highly selective at grabbing carbon dioxide without also removing some natural gas as well.
The investment by the independent oil company reflects the exploration and production industry’s appetite for improved methods that are more compact, cost less to run, and occupy less space. One indication of that is the increased demand for improved membrane-based separation methods, which are far more compact and adaptable to offshore environments than liquid chemical separation methods using amines.
Cameron recently began selling a new, more efficient membrane material, called PN-1 multifiber membrane element, which was developed in partnership with Petronas, the Malaysian national oil company. Better carbon dioxide removal is a pressing concern in southeast Asia, where many large gas deposits have not been developed because of carbon dioxide levels that can equal the gas in the ground.
Production growth there, and in far-flung regions from Russia to Brazil, will require dealing with higher levels of carbon dioxide and hydrogen sulfide, which often are found together and removed using similar processes.
Searching for Solutions to Induced Seismicity
Authors: Jacobs Trent 
Published: February 2015

Induced Seismicity
A sharp rise in seismic events in some areas of the United States where oil and gas production is booming is leading regulators and the industry to examine whether the two are related. And beyond that—what can be done to address the situation. In the first 6 months of this year in Oklahoma, for example, 268 earthquakes measuring higher than magnitude 3.0 have taken place in a state that experienced no more than three earthquakes a year of that magnitude from 1991 to 2008. The data comes from both the Oklahoma Geological Survey (OGS) and the United States Geologic Survey (USGS), the respective state and federal agencies tasked with studying the natural sciences, including earthquake hazards.
Mark Zoback, a Stanford University geophysics professor and a director of the Stanford Center for Induced and Triggered Seismicity (SCITS), said that although it has been known since the 1960s that fluid injection is capable of triggering earthquakes, the ongoing sequence of small to moderate magnitude seismic events so far inside the interior of a continental tectonic plate is unprecedented. One of the leading fault mechanics experts in the world, Zoback’s research is heavily cited by both government and industry studies on induced seismicity.
“This kind of increase in seismicity has not been seen in the modern era, so it is a very unusual phenomenon,” said Zoback, who wrote or cowrote nearly 300 technical papers. “Many of these are earthquakes that are above magnitude 3.0, which means that they are being widely felt.”
In January, the USGS issued a report titled “Man-Made Earthquakes Update.” It said the rise in seismicity in the central and eastern US that started around 2009 has coincided with the injection of waste water from oil and gas operations into deep disposal wells in several states, including Colorado, Texas, Arkansas, Oklahoma, and Ohio.
University R&D Around the World
Authors: Betz Jack 
Published: February 2015

R&D on Campus
As the task of finding and producing hydrocarbons becomes more difficult, complex, and costly, the number of universities focusing on finding solutions has risen. Whether the frontier is heavy oil, deep water, or remote locations, efforts within academia are under way to solve the next generation of technical challenges confronting hydrocarbon E&P operations. Because many noteworthy research and development (R&D) efforts exist at universities all over the world, the intent is not to cover all of them but to present a sampling from many geographical locations. Part 2 of this article will appear in the October issue of JPT.
The Pennsylvania State University was chartered in 1855 as Farmers’ High School, located in Centre County, Pennsylvania, USA. In 1862, the school officially changed its name to the Agricultural College of Pennsylvania. The US Congress passed the Morrill Land-Grant Act in 1862. The act donated federal public land to each state. When each state sold the land, the proceeds were to be used for the endowment, support, and maintenance of at least one college where not just traditional classical studies would be offered, but agriculture and engineering would be taught in a new, practical, scientific manner.
Competing with five other schools, the Agricultural College received the Pennsylvania land-grant endowment in 1863 when the state legislature designated the college the land-grant institution of Pennsylvania. Penn State remains Pennsylvania’s only land-grant institution.
The school’s name was changed to Pennsylvania State College in 1874. The college was elevated to university status in 1953 and renamed The Pennsylvania State University.
Penn State has taught petroleum-related classes since 1896 and today has an active upstream research program including studies on such topics as fluid dynamics, reservoir engineering, and improved oil and gas recovery. In addition, Penn State’s College of Earth and Mineral Sciences established the Institute for Natural Gas Research in 2013, and several Penn State colleges fund the Penn State Marcellus Center for Outreach and Research, the university’s education and research initiative on unconventional gas plays.
Technology Focus: Completions (September 2014)
Authors: Clem Nicholas , Clem Nicholas 
Published: February 2015

Technology Focus
Have you ever been tasked with explaining the oil and gas industry, or more specifically the completions sector, to a family member or friend? Of course you have. Unfortunately, there is no simple way to explain the complexities of our industry, especially to someone without prior knowledge. What usually happens is you find yourself oversimplifying and understating the importance of what we do on a daily basis. But the fact of the matter is that our industry and the challenges it presents have no easy explanation.
Completions is just one piece in the world’s largest jigsaw puzzle that is the oil and gas industry. From the wellhead to the casing shoe, including everything in between, all components and processes ultimately harmonize into a singular system aimed to provide a safe and efficient conduit for the production of one of Earth’s most valuable natural resources. Whether complementary or enabling, advances in completions technologies continue to push the realm of what is possible and allow the exploitation of assets that were deemed impossible previously.
Whether it is a remotely actuated valve set miles beneath the Earth’s surface, a milling tool with a voracious appetite, or a complementary suite of solutions that ignited a revolution, the end game is the same. It is this end game that leads to economic growth and ultimately an improved quality of life for people all around the globe. Without the continued advancement in technology required to meet the demands of the ever-evolving oil and gas industry, the production of energy would become jeopardized. It is this constant advancement of technology that makes the completions sector so unique and so critical to the process of energy production.
The following papers highlight just a few key technological breakthroughs that are certain to have an effect on how completions are designed and deployed for years to come. Reliability, efficiency, and production optimization are common themes that continue to resonate throughout the sector and are further supported by the papers selected for this feature. I am encouraged by the technologies being developed every day in this industry, but I am most excited about what is yet to come. JPT
A High-Pressure/High-Temperature Bridge Plug
Authors: Carpenter Chris 
Published: February 2015

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 166382, ’A State-of-the-Art Completion Technological Innovation: The First 25,000-psi, 500°F Permanent Bridge Plug,’ by Tony Ruffo, SPE, Guijun Deng, SPE, James Doane, SPE, Gary Anderson, SPE, Douglas Lehr, SPE, and Scott Collins, SPE, Baker Hughes, prepared for the 2013 SPE Annual Technical Conference and Exhibition, New Orleans, 30 September-2 October. The paper has not been peer reviewed.
Conventional high-pressure/ high-temperature (HP/HT) packer and bridge-plug technology is generally limited to long-term operation at 15,000 psi and 450°F. A great deal of research-and-development effort has been put into extending performance beyond these limits. Recently, an innovative approach was applied to this problem, with the objectives of increasing these limits and enabling long-term isolation in ultra-HP/HT wells. This approach resulted in the development of an ultra-HP/HT permanent bridge plug for long-term exposure at 25,000-psi pressure and temperatures of 500°F.
Introduction
The process of completing an ultra- HP/HT well with temperatures approaching 500°F and hydrostatic pressures approaching 35,000 psi is evolving at a rapid pace, and the industry has identified a need for a standalone barrier to isolate the shoe track in these wells. This barrier is required in these applications to mitigate uncertainties related to shoe-track integrity. Historically, bridge plugs for use in ultra-HP/HT applications (greater than 20,000-psi differential pressure and 450°F) have not been available in the marketplace, but the demand for competent, long-term isolation has led to the development of new HP/HT technologies—specifically, ultra- HP/HT bridge plugs.
Recently, an operator of an ultra-HP/ HT well identified the need for a bridge plug capable of operation at a 25,000-psi pressure differential (from above and below) and at 500°F. This bridge plug was required to function in a 6?-in. outer diameter (OD) casing over the weight range of 57.58 to 60.1 lbm/ft. Furthermore, the bridge plug had to meet validation and International Organization of Standardization requirements and possess an estimated service life equal to that of the 6?-in. casing.
A materials-screening and -qualification program was used in the design of the bridge plug. The result was a list of three perfluoroelastomer compounds that were evaluated for various seal configurations. Three metallic alloys were also identified for use in the pressure-containing, structural, gripping, and sealing components in the bridge plug. A surface-treatment-qualification program also identified two coatings for use in combating friction and galling. This effort required 18 months.
Automated Managed-Pressure Drilling Protects Caprock Integrity
Authors: Carpenter Chris 
Published: February 2015

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 170152, ’The Successful Application of Automated Managed-Pressure Drilling To Protect Caprock Integrity by Narrow-Margin Drilling in SAGD Wells,’ by Nadine Osayande, Elvin Mammadov, and Sheldon Sephton, Weatherford Canada, and Vincent Boucher, Suncor Energy, prepared for the 2014 SPE Heavy Oil Conference—Canada, Calgary, 10-12 June. The paper has not been peer reviewed.
This paper presents a drilling solution through application of an automated managed-pressure-drilling (MPD) technique proved to identify and react to actual wellbore pressures and detect and control gains and losses while still having the ability to maintain a constant bottomhole pressure (BHP) while drilling through tight windows. The paper demonstrates the successful application of advanced automated MPD technologies on the Dover well close to Fort McMurray, Alberta, Canada.
Introduction
A well in the Dover field had multiple failures in the liner that resulted in excessive sand production, causing the well to be shut in. After reviewing the options of well repair or redrilling the horizontal section to install a new slotted liner, it was determined that redrilling was the best option.
After the well-schematic analysis and in collaboration with the operator, the combination of a proprietary control system and MPD techniques was recommended along with a water-based mud (WBM) weight to drill the well and still be able to maintain the BHP required to overbalance the formation. The capability to detect microinfluxes/-losses while drilling, combined with an automated control system covering the drilling parameters [including the surface backpressure (SBP) and constant BHP], allowed the well to be drilled while maintaining the downhole pressure values as required.
This approach additionally mitigated the challenges with weighted-WBM systems. For this particular well, reservoir temperature had cooled down to 145°C. If the well was not circulated for a period of time during drilling operation, mud temperature would increase, which would lead to the breakdown of the polymers and the loss of suspension of weighting material, effectively reducing the density to values near water density, thus creating an underbalanced situation.
Redrilling a producer well in a shallow, overpressured, hot reservoir was a first for the operator in this area. Typically, during any completion workover, full fluid/mud losses occur, so the potential of these to occur during drilling operations was considered high.
Sulfide-Scale-Formation and -Inhibition Tests for a Gas-Condensate Field
Authors: Carpenter Chris 
Published: February 2015

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 169798, ’Sulfide-Scale-Formation and -Inhibition Tests for a Gas/ Condensate Field With Severe Scaling Conditions,’ by Cyril Okocha and Kenneth S. Sorbie, Heriot-Watt University; Christian Hurtevent and Salima Baraka-Lokmane, Total; and Marcus Rossiter, Total E&P, prepared for the 2014 SPE International Oilfield Scale Conference and Exhibition, Aberdeen, 14-15 May. The paper has not been peer reviewed.
This paper describes various sulfide inhibitor-testing techniques that have been applied to candidate products for the management of zinc sulfide (ZnS) and lead sulfide (PbS) in a gas/ condensate field with a known relatively severe ZnS/PbS scaling problem. The paper presents sulfide static- and dynamic-test measurements along with thermal-aging results that show some encouraging results in terms of ZnS/ PbS inhibition.
Glenelg Field
The Glenelg field is a gas/condensate field discovered in 1999 by exploration; production began in 2006. Glenelg is located in the southern part of the central graben of the North Sea, and it is part of an area where there have been a number of gas/condensate discoveries within Jurassic and Triassic (Fulmar) sandstone formations. For a geological description of the field, please see the complete paper. The Glenelg reservoir has three producing layers (A, B, and C), with the top of the reservoir at approximately 5815-m true vertical depth with diverse reservoir characteristics: thickness ranging from approximately 50 to 150 m, porosity of between 13 and 17%, permeability between 0.3 and 60 md, and water saturations in the range of approximately 28–89%.
Scaling-risk studies for Glenelg show that the primary scaling risk is from calcium carbonate (CaCO3) both in the well and in the production facilities, with halite in the production facilities attributable to the high salinity, as is the case with other high-pressure/ high-temperature gas/condensate wells nearby. However, pressure/volume/temperature studies showed hydrogen sulfide (H2S) content at approximately 30 ppm, with anticipated levels of H2S at approximately 55 ppm during production, although approximately 5 ppm was measured from core barrels. The petrographic reservoir-characterization and -connectivity study shows evidence of pyrite, sphalerite, bitumen, and iron minerals in the reservoir. The presence of H2S is indicated to be as a result of thermochemical sulfate reduction.
Fatigue behavior of calcium containing AZ91 magnesium alloys*
Authors: Amberger Dorothea , Blickle Tina , Höppel Heinz Werner , Göken Mathias 
Published: February 2015

Abstract
The low density of magnesium alloys makes them attractive for light weight constructions. However, important aspects are the rather poor mechanical properties of the most commonly used Mg alloy AZ91 (approximately 9 wt.-% Al, 1 wt.-% Zn), which limits its use in, e. g., power train applications. Alloying AZ91 with Ca leads to a significant improvement of creep resistance. To investigate the influence of the Ca addition on the fatigue behavior, symmetric push pull tests have been performed on AZ91 alloys with an addition of 0, 1 and 3 wt.-% of Ca, respectively. At relatively high amplitudes, the Ca containing alloys show a decrease in fatigue life compared to Ca-free AZ91. However, with a decrease in amplitude, the fatigue life of the alloy with 3 wt.-% Ca are comparable with the Ca-free AZ91 alloy and with a further decrease in amplitude the alloy with an addition of 3 wt.-% Ca has an even higher fatigue life than the Ca-free alloy. All alloys contain pores due to the casting process.
Persistance de l’Absurde dans la dramaturgie tchèque post-1989 [The Persistent Use of the Absurd in Post-1989 Czech Dramatic Art]
Authors: Boutin Véronique 
Published: February 2015

The Persistent Use of the Absurd in Post-1989 Czech Dramatic Art
The quest of the existence of the world and its uncertain boundaries runs the risk of confronting itself with existentialist fears. Both contemporary Czech playwrights Antonín Přidal and Petr Zelenka who wrote respectively Noc potom and Příběhy obyčejného
šílentsví (2001), give us two plays with the notion of the Absurd, thus perpetrating the Czech literary tradition. Pridal’s ‘ in camera’ gives a vision of an illogical dreamlike universe in which Blanche, the protagonist accused of being a nark for the communist regime, is looking for a meaning to her life while dreaming of finding the witness who will rehabilitate her. With Zelenka, Petr can’t face the brutal reality of the world and sinks deep into a grotesque madness which will lead him to committing suicide, a suicide his mother had foreseen in her dream. Both plays reflect the post-1989 society without being political pamphlets and invite us to encounter characters who are incapable of adapting to today’s world.
Le changement de construction des numéraux supérieurs à « cinq » en vieux slave [The New Syntax of Numerals Higher Than ‘5’ in Old Church Slavonic (OCS)]
Authors: Le Feuvre Claire 
Published: February 2015

The New Syntax of Numerals Higher Than ‘ 5’ in Old Church Slavonic (OCS)
In the new syntactic pattern of numerals higher than ‘ 5’, the quantified noun agrees with the numeral, instead of being a complement in the Genitive plural. The new pattern is limited to oblique cases, and the majority of instances in OCS are found in prepositional phrases. This leads to the following hypothesis : in prepositional phrases with prepositions governing the Genitive case, the quantified noun in the Genitive, governed by the numeral, was reanalyzed as governed by the preposition, and promoted to the status of head of the numeral phrase, the numeral becoming a modifier, as is the case for smaller numerals from ‘ 1’ to ‘ 4’. The extension to non prepositional oblique cases seems to be secondary. The immediate model, however, are not the smaller numerals, but the quantifiers of indefinite quantity such as koliko, which are characterized by a structural opposition between [ Quant. NGen.] in the direct cases, the quantifier being the head, and [ Quant. x Nx] in the oblique cases, where the quantified noun is the head and the quantifier an agreeing modifier. This structural opposition is old, and probably inherited for this type of non numeral quantifiers, it is found also in Latin (Nom. Acc. quantum argenti, but Abl. quanto argento, with determiner quantus agreeing with the head argento : the quantified noun
argenti, which is a modifier in the direct cases, is promoted to the status of head of the noun phrase in the oblique cases). The coexistence of two syntactic patterns for the quantifiers of indefinite quantity, in Slavic or in Latin, is justified from the semantic point of view, it is used to differenciate the function of evaluation (‘ how big ?’) and the function of quantification (‘ how many / how much ?’) of the same morphemes quantus/ quantum, kolikъ/ koliko. The numerals higher than ‘ 5’ borrowed this model through reanalysis in prepositional phrases : for numerals this syntactic duality is not meaningful, it merely reproduces that of the model. It is not necessary to assume with Žolobov 2006 that complex numerals such as ‘ 20’, ‘ 30’ played a role in the extension of the new syntactic pattern.