bluuebunny/crossref_metadata_2025_split huggingface dataset:
Mock-up de habitação: relação entre concepção, desenvolvimento e execução no ensino de projeto
Authors: Imbronito Maria Isabel , Almeida Eneida de 
Published: May 2016

O presente artigo constitui o relato de uma experiência didática exercitada no presente momento, que permite estabelecer uma reflexão sobre o ensino de projeto e os fundamentos teóricos próprios do campo disciplinar da arquitetura. Trata-se de um exercício proposto na disciplina Introdução ao Projeto de Arquitetura e Urbanismo, aplicado a alunos do primeiro ano de projeto do curso de Arquitetura e Urbanismo da Universidade São Judas Tadeu. O exercício é composto por diferentes etapas, que são descritas e têm os objetivos apresentados no decorrer do artigo. A última etapa, correspondente à construção dos mock-ups em escala 1:1, possibilita a execução de um elemento complexo e a experiência de ocupar e perceber o espaço construído. Ao visar uma construção real, tanto do ponto de vista da organização do espaço como do domínio técnico-construtivo, o exercício de projeto de arquitetura dá ênfase às implicações, para a aprendizagem do aluno, do enfrentamento de aspectos construtivos em sincronia com a própria concepção do espaço. O interesse é assinalar que a atividade de construção do mock-up oferece ao processo de projeto elementos materiais concretos para a manipulação simultânea de múltiplas prerrogativas do projeto, propiciando a experimentação e verificação in loco da complexidade do sistema estrutural em suas propriedades físicas, especialmente nas relações entre o dimensionamento (e modulação) das peças, a estabilidade do conjunto e a própria forma. As considerações feitas procuram estabelecer parâmetros para o desenvolvimento futuro de uma pesquisa no ensino de Projeto de Arquitetura no que tange à relação entre a matéria e o espaço, bem como o aperfeiçoamento constante do sistema construtivo utilizado.
Comments: A Pivotal Month
Authors: Donnelly John 
Published: May 2016

Editor's column
This month should offer key clues to the direction of the oil market over the next several months. OPEC countries will meet on 5 June in Vienna in a regular meeting to discuss their current supply to the market and production quotas. And government figures released this month should begin to get a better handle on the decline in US production.
OPEC’s last meeting, in November, contributed to the steep drop in oil prices when Saudi Arabia decided it would no longer play the role of “swing producer” and would instead defend market share. Although many took this as provocative, several executives speaking at the recent IHS CERA conference in Houston noted that OPEC fears prolonged high oil prices could lead to faster development of alternative energy, and the cartel is engaged in a “price discovery exercise” to determine the sustainability of US shale producers. “I think it’s going to be very useful to the industry to have a clear understanding of the resilience of these resources, how robust the resources are, and how they are able to withstand different price environments,” said ExxonMobil Chief Executive Officer Rex Tillerson. Most of the executives at the conference agreed that the current price downturn would last a while and that the current situation seemed closer to the downturn that occurred in the mid-1980s, rather than more recent price downturns.
The OPEC strategy is definitely having an impact on North American production. The US Energy Information Administration last month lowered its 2015 and 2016 crude oil production growth forecasts. Its latest Short-Term Energy Outlook predicts that US crude production this year will increase 530,000 B/D (revised down from 550,000 B/D) and that 2016 growth will be 20,000 B/D (revised down from 80,000 B/D). US producers have cut spending, idled more than half of the country’s drilling rigs, and eliminated thousands of jobs. The number of active rigs working in the US had fallen for 23 weeks in a row as of mid-May.
Guest Editorial: Keeping Reservoir Stewardship on Course
Authors: Harrison Bob 
Published: May 2016

Guest Editorial
The French term, déja vu, which means literally “already seen,” is the feeling that you have previously experienced something you are currently experiencing. Two thirds of adults claim to have sensed this phenomenon, but this figure rises to 100% when one considers professionals in the oil and gas industry, which is undergoing yet another boom-and-bust cycle.
Besides the real concern that the recently announced staff layoffs will only hasten the “big crew change” (as some “golden oldies” may decide to call it a day this time around), one hopes that operators will maintain good stewardship of their wells and fields and resist the temptation to cut back on essential data acquisition.
Reservoir stewardship, in which operators accept the responsibility to shepherd and safeguard the assets of a company or a country, involves the periodic review of asset performance to ensure productivity and recovery targets are met and maintained, and to guide future work plans. Continuous reservoir appraisal and surveillance are essential to minimize production losses from downtime in wells, facilities, and export systems. Unfortunately, it is evident that some operators (and governments) pay only lip service to good reservoir stewardship, especially when oil and gas prices are low.
Sometime ago, I read a student thesis that looked at options for reducing costs in the unconventional “factory drilling” process. It concluded that significant time and money could be saved if formation evaluation services were eliminated from the well program. The project sponsor was happy with the result and the student graduated, but I was appalled that this suggestion could ever be taken seriously. Unconventional reservoirs have complex pore systems, very low interparticle permeability, contain free and adsorbed gas, and exhibit variable water salinity, all of which make their characterization a major challenge for the geoscientist.
Therefore, more core data (not less) are needed to calibrate the responses of logging suites, which also require enhanced measurement services as opposed to standard tool strings. The taking of core permits subsequent rock typing to include dynamic properties and fracturability and allows partitioning of the reservoir into zones that reflect quartz content and producibility.
Dissolvable Plug and Perf System Eliminates Mill-Outs in Multistage Stimulations
Authors: Aviles Isaac , Dardis Michael , Jacob Gregoire 
Published: May 2016

Technology Update
Of all the technologies that have propelled the unconventional boom in the United States over the past 15 years, plug and perf (P&P) remains the No. 1 method for stimulating multistage wells, enabling operators to achieve significant economic gains in previously inaccessible reservoirs.
Unconventional wells have become longer, with laterals extending as far as 10,000 ft and beyond. When combined with tighter spacing between stages, this growing lateral length has dramatically increased stage counts. In North American land activity, stages per lateral have nearly doubled in most basins since 2008, thanks in part to increased efficiencies in P&P operations.
P&P relies on the use of a wireline or electric line to convey perforating guns and plugs to isolate sections of a reservoir for hydraulic fracturing. After the well is stimulated, the plugs are milled out with some type of mechanical intervention, such as the use of coiled tubing (CT).
Over the years, P&P has been improved with the development of composite plugs, as opposed to permanent-style plugs, that can be milled out in a continuous operation, pump-down operations to replace mechanical conveyance, and toe-initiator valves, which eliminate the need to mechanically convey perforations for the initial stage of the P&P operation.
Despite these advances, mechanical intervention remains costly and risky, and in some instances may damage the recently placed fractures. In cases of low reservoir pressure or extended-reach laterals, milling can be especially problematic. Returns do not easily reach the surface, and friction and helical buckling effects can often result in CT lockup, preventing the CT from reaching the required depth to remove plugs in the toe section of the well. Debris left behind from milled-out plugs in the wellbore can result in the CT becoming stuck, thus driving up costs and further delaying production.
These limitations signaled the need for the industry to move a step beyond conventional P&P technology. A new, dissolvable P&P system eliminates the need for mechanical intervention to remove plugs, enabling an unlimited number of stages to be stimulated. Launched in February, the dissolvable P&P completions system has been successfully implemented in many of the major unconventional plays in North America.
Turning Weakness Into Strength: Hydraulic Pipe-Recovery System
Authors: Churchill Mike 
Published: May 2016

Young Technology Showcase
Introduction
Stuck pipe has traditionally been a challenge for the oil and gas industry; in recent years, operators have become even more determined to reduce the effect of stuck-pipe issues. Even with the best planning and practice, there is a significant probability in certain wells that some of the string will not come back out of the hole. While losing a bottomhole assembly is never ideal, the time wasted in trying to free it and in redrilling afterwards can be far worse.
HyPR HoleSaver
The results of Churchill Drilling Systems’ collaboration with drilling crews in the North Sea and the Gulf of Mexico and extensive research and development resulted in the creation of the HyPR HoleSaver, the first hydraulic pipe-recovery system. In March 2015, the system had its first major deployment, optimizing stuck-pipe contingency in zones highly vulnerable to differential sticking. Although no stuck-pipe issues arose, the tool significantly reduced the cost-overrun risks. The tool is now being considered for imminent deployment by a number of other major operators and leading independents, to reduce costs and risks in a wide range of upcoming wells across the globe, particularly in the Gulf of Mexico.
The tool consists of a full-strength sub positioned in the drillstring, which is severed in a couple of hours (Fig. 1). A jetting dart is launched and lands inside the sub, jetting the internal American Petroleum Institute (API) pin connection.
At the conceptual stage, a number of questions had to be considered. Could significant time savings actually be delivered from the point at which the decision is made to sever the string until sidetracking or fishing commences? With its expertise in dart-activated tools, Churchill Drilling Systems decided to determine whether applying dart-related principles in a new approach could cut wait times significantly.
The Need for a New Method
A major delay in severance often accompanies the mobilization of specialist equipment or personnel. This is compounded in remote locations or when moving restricted equipment, such as explosives or hazardous chemicals. Ideally, any new method should be self-operated by the user, or at least should allow cutting-and-retrieval operations to begin while third-party services are mobilized.
Mining Daily Driller’s Reports Looking for Telling Patterns
Authors: Rassenfoss Stephen 
Published: May 2016

Data Mining
There is a lot of information buried in drilling reports written every day, but little of it appears in computer databases.
Numbers from daily drilling reports can be added to databases along with data from sensors on the rig that can be crunched in seconds by a computer. But the perspective of the drillers is only available to a person reading the reports. Turning those sometimes personal, always jargon-filled observations into a form a computer can analyze is a challenge the oil industry is beginning to take on.
BP created a system able to mine the daily reports filed by drillers, seeking what a paper on the project (SPE 173429) describes as “insightful.”
The project used natural language processing to seek out key words and phrases related to drilling, and pattern-recognition software to identify common concerns. The paper described it as an “automatic discovery of unobservable events.”
The results were displayed in the form of word clouds. These graphic displays highlighted the size and prominence of terms related to drilling performance appearing frequently in reports. The goal is to begin using this unstructured data—documents not in the form of a computer database—to answer a pressing question:
“How can we pinpoint the progress of things that could impact the performance and the cost of the well” as it is being drilled, said Mohamed Sidahmed, a data analytics scientist at BP, who recently spoke about the three-well project at the SPE Digital Energy Conference and Exhibition in The Woodlands, Texas.
“You might be able to spot the most high-frequency events, but most of the time, there are subtle issues that do not reveal themselves obviously,” Sidahmed said. For example, during the test, the analysis highlighted driller comments about a mud pump 3 weeks before it broke down.
Language Learning
BP is the first oil company to report using these data-mining methods for drilling monitoring. Its goal is to increase safety and efficiency. These techniques have been previously used for analyzing trends on the Internet and monitoring by intelligence agencies.
Technology Focus: Coiled-Tubing Applications (June 2015)
Authors: Crabtree Alex 
Published: May 2016

Technology Focus
The oil industry has responded rapidly to the decline in oil prices of these last few months. As in past downturns, the rig count has fallen quickly, with the US land rig count having been particularly hard hit. The Baker Hughes rig count for US land rigs shows a fall from 1,866 at the beginning of June 2014 to 1,028 at the start of April 2015, a decrease of 45%. A large portion of this reduction has occurred in the shale plays.
In prior industry cycles, declines in rig activity have not affected the coiled-tubing (CT) market immediately. In fact, an increase in the CT sector has been observed in some past down cycles. CT had been predominantly an intervention method used to aid or maintain existing production. However, the focus in the US CT market has shifted to supporting completion operations in the shale plays. Anecdotal opinion at the Coiled Tubing and Well Intervention Conference and Exhibition in Houston this year suggested that there is a greater and more immediate effect on the CT market in the US. Opinion similarly suggested that activity outside of the US land market is responding as it has in previous cycles.
The CT industry, like all other sectors in our industry, will respond to today’s new market conditions. Technical innovation, as evident at the CT conference, will continue. The focus of this innovation may shift toward improving processes and their efficiency—namely, doing more with less. This repurposing brings an opportunity to drive and recognize the value of these innovations. Perhaps this period in the cycle will allow for a consolidation of knowledge and incremental development of today’s technologies.
The papers in this year’s feature represent innovation, the adaptation of existing technologies, and overcoming operational problems. They demonstrate the transfer of knowledge from other sectors of our industry. By using that knowledge, each paper shows that technical innovation is still possible in this current climate and continues to move the CT industry forward.
Coiled-Tubing-Deployed Shutoffs in Alaska With a Polymer Gel and Microfine Cement
Authors: Carpenter Chris 
Published: May 2016

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 173655, “Coiled-Tubing-Deployed Gas and Water Shutoffs in Alaska With a Polymer Gel and Microfine Cement,” by D.B. Robertson, SPE, BP; M.A. Brown, Petrotechnical Resources of Alaska; L.H. Duong, SPE, BP; O.V. Ivanova, Schlumberger; and A. Tambe, SPE, BP, prepared for the 2015 SPE Coiled Tubing and Well Intervention Conference and Exhibition, The Woodlands, Texas, USA, 24–25 March. The paper has not been peer reviewed.
A common problem in oil and gas wells is excess free gas or water production from only certain portions of the completed interval. A coiled-tubing-deployed profile-modification technique was developed primarily to shut off excess free-gas production from the heel of cased-and-perforated horizontal oil wells. The technique has also been used for water and gas shutoff in both vertical and horizontal wells in a variety of lower-completion types.
Introduction
Coiled-tubing work has a well- established track record in North Slope of Alaska oil fields involving several thousand interventions of various types. Fig. 1 is a photograph of a typical Arctic-winter coiled-tubing operation.
Most of the approximately 1,700 wells in the Prudhoe Bay field penetrate either an extensive gas cap or the aquifer in the sandstone reservoir. Mechanisms for excess free-gas or water production can be related to poor primary-cement jobs of production liners, fluid-contact movements over time, coning, or corroded or damaged liners. In general, any through-tubing-profile modification that can be performed to reduce excess free-gas and water rates and increase oil rate or time on production is beneficial to overall field production. With many candidate wells, there has been a continuous evolution in job design and execution techniques over the years.
Pilot to Full-Field Polymer Application in One of India’s Largest Onshore Fields
Authors: Wilson Adam 
Published: May 2016

This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE 169146, “Pilot to Full-Field Polymer Application in One of the Largest Onshore Fields in India,” by Dhruva Prasad, Amitabh Pandey, SPE, M. Suresh Kumar, and Nitish Koduru, SPE, Cairn India, prepared for the 2014 SPE Improved Oil Recovery Symposium, Tulsa, 12–16 April. The paper has not been peer reviewed.
A normal five-spot polymer-flooding pilot has been conducted at the Mangala field, one of the largest onshore fields in India, and results are encouraging in terms of additional oil recovery and reduction of water cut. Polymer flooding has the potential to improve sweep efficiency in the field significantly and to increase expected ultimate recovery (EUR). The project is one of the largest in the world in terms of scale, polymer usage, and related facility and logistics.
Introduction
The main reservoir unit in Mangala field is the Fatehgarh group. Five reservoir units (FM1–FM5) have been named from the top down. Mangala contains waxy sweet crude oil with gravity ranging from 20 °API near the oil/water contact to 28 °API higher in the oil column. The crude has an in-situ oil viscosity of 9–22 cp, with live-oil wax-appearance temperature approximately 6°C lower than the average reservoir temperature of 65°C. The oil also has a high pour point of 40–45°C, which had a great influence on all aspects of the project and process design.
The development plan involved implementing a hot waterflood from production startup to maintain reservoir pressure and sweep reserves effectively.
On the basis of appraisal data, it was realized from the start that Mangala was a candidate for an enhanced-oil-recovery (EOR) process. Detailed laboratory evaluations and simulation studies suggested chemical flooding as the appropriate EOR process for the field. A polymer-flood pilot was conceived on the basis of laboratory and simulation results. The pilot has been successful in terms of reducing water cut and increasing oil rate. Full-field implementation is now planned for Mangala.
From Streamlines to Fast Marching: Rapid Simulation and Performance Assessment of Shale-Gas Reservoirs by Use of Diffusive Time of Flight as a Spatial Coordinate
Authors: Zhang Yanbin , Bansal Neha , Fujita Yusuke , Datta-Gupta Akhil , King Michael J. , Sankaran Sathish 
Published: May 2016

SummaryCurrent industry practice for characterization and assessment of unconventional reservoirs mostly uses empirical decline-curve analysis or analytic rate- and pressure-transient analysis. High-resolution numerical simulation with local perpendicular bisector (PEBI) grids and global corner-point grids has also been used to examine complex nonplanar fracture geometry, interaction between hydraulic and natural fractures, and implications for the well performance. Although the analytic tools require many simplified assumptions, numerical-simulation techniques are computationally expensive and do not provide the more-geometric understanding derived from the depth-of-investigation (DOI) and drainage-volume calculations.We propose a novel approach for rapid field-scale performance assessment of shale-gas reservoirs. Our proposed approach is dependent on a high-frequency asymptotic solution of the diffusivity equation in heterogeneous reservoirs and serves as a bridge between simplified analytical tools and complex numerical simulation. The high-frequency solution leads to the Eikonal equation (Paris and Hurd 1969), which is solved for a “diffusive time of flight” (DTOF) that governs the propagation of the “pressure front” in the reservoir. The Eikonal equation can be solved by use of the fast-marching method (FMM) to determine the DTOF, which generalizes the concept of DOI to heterogeneous and fractured reservoirs. It provides an efficient means to calculate drainage volume, pressure depletion, and well performance and can be significantly faster than conventional numerical simulation. More importantly, in a manner analogous to streamline simulation, the DTOF can also be used as a spatial coordinate to reduce the 3D diffusivity equation to a 1D equation, leading to a comprehensive simulator for rapid performance prediction of shale-gas reservoirs. The speed and versatility of our proposed method makes it ideally suited for high-resolution reservoir characterization through integration of static and dynamic data.The major advantages of our proposed approach are its simplicity, intuitive appeal, and computational efficiency. We demonstrate the power and utility of our method by use of a field example that involves history matching, uncertainty analysis, and performance assessment of a shale-gas reservoir in east Texas. A sensitivity study is first performed to systematically identify the “heavy hitters” affecting the well performance. This is followed by history matching and an uncertainty analysis to identify the fracture parameters and the stimulated-reservoir volume. A comparison of model predictions with the actual well performance shows that our approach is able to reliably predict the pressure depletion and rate decline.
John and Jacqueline Kennedy: Politics, culture and the “new frontier” of clothing
Authors: Čupić Simona 
Published: May 2016

Jacqueline Kennedy’s style is one of the mainstays of the history of fashion and popular culture, as well as contemporary politics. John Kennedy’s way of dressing garnered much less attention. Even though, at first glance, not as interesting as the first lady’s “fashion sense”, the president’s style was no less thought-out. If, however, we view the changes in clothing as social changes and a determinant of various kinds of social differentiation: marital status, sex, occupation, religious and political affiliation, the way in which the Kennedys were presented to the public becomes more interesting – from the (carefully planned) photos and appearances to art and culture. Having in mind that the 1960s were a time when the appropriation of popular and fictional came back into modern art, and that general changes inherent in the new lifestyle, as well as a layered image of American internal politics, and the cold war map of the world, the carefully thought-out image of the presidential couple can be viewed as a specific kind of metaphor for a complicated time.