bluuebunny/crossref_metadata_2025_split huggingface dataset:
Levitating the Pentagon
Authors: Laycock Joseph P. 
Published: March 2013

On 21 October 1967 Allen Ginsberg, Abbie Hoffman, and Ed Sanders of the band The Fugs, and others, organized an “exorcism” of the Pentagon in which several thousand demonstrators participated. Most historians have regarded this event as “a put on” or at best as “performance art.” This article takes seriously the nominal status of the ritual as a “sacred” or “magical” event. It argues that the organizers were utilizing innovative strategies of social action to alter the terms of debate regarding the Vietnam War.
Inasmuch as these strategies drew on “secret” insights into the nature of social reality, they were seen as “magical” and in continuity with pre-modern esoteric traditions. Finally, it is argued that the new left turned to such tactics out of a deep frustration with traditional forms of democratic political engagement.
Ferdinand Oyono'sUne vie de boyon the World Literary Stage
Authors: Moore David Chioni 
Published: March 2013

Some of you know that my grandfather was a cook for the British in Kenya, and though he was a respected elder in his village, his employers called him “boy” for much of his life.—Barack Obama, president of the United States, speaking to the Parliament of Ghana, Accra, 11 July 2009How do you saykhakiin fourteen languages? assuming that the answer is, in most cases, more or lesskhaki, what might that word mean? This question occurred to me three years ago as I was sitting in my Minnesota office with a student—a brilliant sophomore economics major from Hanoi—trying to understand a thorny text from Cameroon. The text before us was the Vietnamese translation of Ferdinand Oyono's landmark 1956 francophone anticolonial novelUne vie de boy, which I had been pondering for years. A central figure in the novel, the village's French commandant, was often depicted in “son short kaki” (“his khaki shorts”). Though I don't speak Vietnamese, I could make out enough of its modified Latin alphabet to recognizekakiseveral times in the 1997 translation. In seeking its Vietnamese meaning, I knew that at least six languages were already in play:kakicame to Oyono's French from English, which got the word in the mid-nineteenth century from Hindi-Urdu (where it means dust-colored), which got it from the Persian(transliterated “khakeh”), meaning dust (“Khaki”). What is more, Oyono's novel purports to be translated from the Ewondo, wherekakicertainly meant something too. But in Vietnamese? My instinct was thatkhaki, at least in Vietnam, would signify what it did in Cameroon: the iconic colonial oppressor's fabric. But when my student, Phuong Vu, saw the word in Vietnamese, she immediately searched for an image on her laptop, then showed me a photo of the greatanticolonialleader of Vietnam: the khaki-wearing Ho Chi Minh. Seeking a further data point, I asked my dean, the Somali scholar Ahmed Samatar, whatkhakimeant in his mother tongue. His reaction, too, was instant: “my grandfather was the first man in our village to wear khaki: it signifies modernity!”Khaki:one word, worldwide. But clearly not a monosignifying word, since it means, at minimum, dust, dust-colored, modernity, colonization, and anticolonial resistance. To paraphrase Langston Hughes, what kind of a translation can you make out of that?
Investigation of Low Frequency Water Hammer for Extended Reach Applications
Authors: Macdonald R. , Jennings B. , Vecseri G. 
Published: March 2013

Abstract
Horizontal wellbores typically encounter inefficiencies due to friction during both drilling and completions operations. In severe cases, further advancement of the bit or downhole tools is almost impossible due to the inability of existing technology and methods to overcome downhole friction forces. This problem, seen in drilling, completions, and intervention activities, is particularly acute in coil tubing deployed bottom hole assemblies (BHA). Fluid hammer tools are often used in an attempt to mitigate this friction, with varying degrees of success. Current commercially available fluid hammer tools are preset mechanical systems operating at relatively high frequencies from 12 to over 40 Hz. These tools, which cannot be deactivated once installed in the BHA, typically exhibit a large pressure drop which can rise even further with increased flow. It is proposed that a downhole pressure oscillation tool be developed that provides the capability to manage downhole pressure oscillation amplitude independent of flow rate. It is also proposed that such a tool, operating at low frequencies, could simultaneously encode downhole measurements within the pressure pulse signal. This paper presents experimental data collected in the development of such a system and further explores the theory that high amplitude oscillations at lower frequencies impart significant motive force to the BHA enabling extended reach.
Development of a New CT Life Tracking Process
Authors: Newman Kenneth R 
Published: March 2013

Abstract
A new process has been developed to track the life of coiled tubing (CT) strings. This paper documents the development of this process, including the material models and the software tools used by the process. The results of this process are a prediction of the CT life and diametrical change along the length of the CT. When the process is used for multiple CT strings, statistical metrics about the strings can be mined from a web based database.
Successful Case Histories for the Next Generation 3D CFD-Derived Fluidic Oscillator
Authors: Howard Robert , Martinez Ismael , Hunter Tim 
Published: March 2013

Abstract
Near-wellbore (NWB) stimulation continues to evolve and change over time as a wide variety of tools and processes designed to target this problem area of the borehole are being developed. Fluidic oscillators (FOs) are amongst some of the most simple and successful tools to affect this region; however, even after decades of multidiscipline industry development, there is still room for improvement.
This paper discusses the search for the perfect oscillator design for NWB stimulation using solid modeling and 3D computational fluid dynamics (CFD). These tools allowed fast and efficient evaluation of hundreds of concepts to optimize features of the selected design without the need for prototype testing during each design iteration. As a result, many months of development time were saved by eliminating repeated manufacturing and testing activities. The best possible solution was then validated in the laboratory using rapid-prototype models, machined prototypes, and ultrahigh-speed photography.
The main purpose of this paper is to focus on the case histories collected during field testing and commercialization of the new design. Pre- and post-treatment production figures, infield well comparisons with competing technologies, and repeat treatments originally performed with previous versions best showcase the superior performance from the advances made to the tool and treatment process and are used whenever possible.
The results prove what laboratory testing predicted—the improvements translated to superior stimulation results.
Innovative Coiled Tubing Technology to Improve Performance in Horizontal Completions
Authors: McClelland Garry , Tubing Global 
Published: March 2013

Abstract
Recent technological innovations in seismic imaging, directional drilling and hydraulic fracturing and other completion techniques have made development of unconventional hydrocarbon resources economically feasible. Coiled tubing is an integral component in completing most unconventional wells. However, the life of coiled tubing used in such applications has been negatively affected by higher well pressures often coupled with larger pipe diameters relative to wall thicknesses ("D/T Ratios"), as well as sinusoidal and helical buckling unique to horizontal completions. Such stresses frequently manifest in bias welds present in certain portions of the coiled tubing string, affecting both fatigue life and potentially operational safety.
It has long been understood that higher wall thicknesses improve the fatigue performance of coiled tubing, including bias welds. However, higher wall thicknesses throughout the length of the tubing may increase the weight of the coiled tubing strings to unacceptable levels. Technology now exists to provide coiled tubing strings with greater wall thicknesses at the bias welds while maintaining the thinner nominal wall thickness over the majority of the body of the tubing. This provides the ultimate in design flexibility for engineering a coiled tubing string with optimized reach, weight, overpull, fatigue life and safety.
This paper presents data demonstrating the improved performance of coiled tubing with increased localized wall thickness at the bias welds, and outlines the string design flexibility offered by this technology for engineering the next generation of coiled tubing.
Successful Oriented Hydrajet Perforation and Fracture Stimulation of a Highly Deviated Tight-Gas-Producer Well Completed in the Casing/Liner Overlap Section
Authors: Gomez Francisco , Al-Asiri Mohammed , Al-Mutary Talal , Abass Hazim , Sierra Leopoldo , Vielma Jose R. 
Published: March 2013

Abstract
Hydraulic fracturing is essential for stimulating tight-gas reservoirs, where hydrocarbon recovery is optimized by placing long and conductive fractures. It has been established in the oil and gas industry that placing hydraulic fractures in vertical wells can be achieved with a good degree of confidence; however, when the wellbore is deviated from the vertical plane, completion challenges can negatively impact the proper placement of the fracture and stimulation. Moreover, if wellbore deviation is very high (greater than 65°) and the formation to be fracture stimulated is located in the overlap of the last casing and production liner, achieving effective stimulation can be even more challenging.
Perforation, completion, and fracture stimulation of tight-gas reservoirs performed in highly deviated wellbores that are located in the overlap of the casing/liner is not common practice within the industry; when this situation is encountered, performing effective fracture stimulations is often considered impossible because of operational challenges and screenout risks.
This paper presents a case history of a successful perforation and fracture stimulation of a deep tight-gas reservoir where the wellbore was highly deviated (65°) and was located between a 7-in. casing and 4 1/2-in. liner overlap. Wellbore perforation was performed using an innovative oriented hydrajetting process, where the perforated interval was aligned to the plane of the maximum stress. Additionally, this paper documents the innovative isolation of the openhole section located below the zone to be fractured using a chemical packer.
Combining Tools to Increase Efficiency in Challenging Wellbore Cleanouts
Authors: Li J. , Lindsey B. J. , Rahimov K. , Smith S. 
Published: March 2013

Abstract
More than 30% of coiled tubing (CT) operations worldwide are related to debris removal from a wellbore. The process is affected by multiple variables including fluid properties/velocities, particle properties, wellbore geometry and deviation, pipe size and eccentricity, fill penetration rate, and wiper trip speed. Debris cleanout with CT is challenged by the achievable pump rates and lack of pipe rotation. This challenge is further compounded by highly deviated or horizontal well trajectories, especially in large-diameter wellbores with low bottom-hole pressures.
A hydraulically actuated, switchable circulation sub was developed a decade ago. While running into the well, forward jets of the sub help break down debris. While pulling out of the well, the tool is switched to a low resistance, backward jetting mode, which sweeps debris more efficiently using higher flow rates. However, in some challenging conditions such as compacted sand columns, or scale in extended wellbores, the sub has to be combined with other downhole tools to meet operational requirements. This paper discusses how to combine the switchable circulation sub with a tractor, water hammer tool, and a mud motor/bit. It goes on to demonstrate a means of verifying the tool is operated correctly using real time downhole signals transmitted by a small but robust conductor inside the CT.
The benefits of this combination are multi-fold. First, while running into the well the tractor or water hammer tool helps to reach target depth. While pulling out of the well, the switchable circulation sub cuts off flow to the lower BHA (bottom hole assembly), stopping the bit/PDM (positive displacement motor) and/or idling the tractor or water hammer tool. At the same time, the flow rate can be increased with relatively lower surface injection pressures improving the hole-sweeping efficiency and pipe fatigue life. A few field case histories are presented to demonstrate the benefits of these special BHAs in improving operational efficiency. The challenges, benefits, and lessons learned during these operations are reviewed.
Extending the Operating Life of Mature North Sea Assets by Big-Scale Offshore Installation of Large-Diameter Chrome Coiled-Tubing Velocity Strings
Authors: de Jonge R. M. , Ambergen D. , Tousis U. A. , Veeken K. , Hoekstra L. , Gesterkamp S. 
Published: March 2013

Abstract
In the Southern North Sea, many fields are suffering from declining gas production due to depletion of the reservoir and associated liquid loading. At some time during the operating life of offshore production facilities, the ability for these facilities to keep operating economically at a further decline in gas production, will need to be evaluated. To avoid early abandonment of these offshore assets, well deliquification or liquid unloading techniques, like Velocity String (VS) installations, are considered for extending the operating life of these mature fields.
Large diameter (2 3/8 and 2 7/8-in.) chrome coiled tubing (CT) strings are being installed in deep gas wells in the Southern North Sea, as part of a large-scale installation project, including some 20 wells over a period of two years. A self-propelled jackup work vessel is used to house all the coiled tubing, well test and associated equipment needed to enable well interventions on the small production platforms and NUI’s (Normally Unmanned Installations). Critical to the success of the project was the cross-discipline approach to preparing, selecting and testing appropriate coiled tubing hardware and tools, hazard analyses and logistical coordination.
In this paper the preparation of the project, the operational details and lessons learned are presented. Candidate well-selection criteria and the choice for the selected coiled tubing material and size are discussed as well. Due to the size of the project, which is a worldwide first of this magnitude and set-up, both in terms of investment and quantity of offshore installations, good case histories for large diameter offshore chrome velocity string installations are provided.
At time of writing not all the velocity strings have been installed. The velocity strings installed thus far have yielded incremental gas production of the order of 50,000-150,000 sm3/d (1.7 – 5.3 Mscf/day) per well, which is in line with expectations. Based on the initial production results and production expectations for the remainder of the wells, the production life of these assets is expected to extend with many years.
Stuck Coiled Tubing: Addressing the Risks in a Complex Operating Environment
Authors: Burgos Rex , Mallalieu Robin 
Published: March 2013

Abstract
Stuck coiled tubing (CT) remains among the major operational risks when performing a CT well intervention. Stuck pipe incidents normally result in considerable production delays or—even worse—possible loss of the well. The mechanisms for stuck pipe are varied, and over the years, the industry has relied on tried and tested "rules of thumb" to address the risk under different operating scenarios.
Today, CT well intervention is more popular than ever. With service demand on the rise, the application envelope for this versatile technology continues to expand. Over the last decade, however, the profile of the wells where CT intervention is featured has also evolved. If anything, the operating environment for today’s intervention is more challenging, involving difficulties in wellbore trajectory and complexities in the completion, as well as an array of sophisticated tool assemblies requiring conveyance. During this period, the approach to stuck pipe avoidance or prevention has more or less remained steadfast.
A study performed on a decade’s worth of data (2001 to 2010) from sticking incidents for a leading CT service provider identified the changes and trends in the mechanisms for sticking as the operating environment has evolved. More importantly, recommendations for addressing the associated risks with the expanded application envelope are proposed.
Rheological Properties of Surfactant-Based and Polymeric Nano-Fluids
Authors: Fakoya M. F. , Shah S. N. 
Published: March 2013

Abstract
Nanotechnology is well established in several industries. However, the emergence of its application is recent in the oil and gas industry; a fact corroborated by the current surge of publication in literature. Interestingly, advancement in research has shown that nanotechnology can improve the rheological properties of surfactant-based fluids (SBF) and polymeric fluids.
To date, this application focuses more on polymeric fluids than on SBF. Furthermore, a few or none of the studies address the detrimental effect of nanotechnology on rheological properties of these fluids once certain limits are exceeded. Likewise, little or no information is available regarding the application of nanotechnology in SBF-polymeric fluid blends.
This paper presents an experimental investigation of nanotechnology on the rheological properties of SBF, polymeric fluids, and SBF-polymeric fluid blends. The surfactant-based and polymeric fluids are composed of 5% SBF in 4% KCl and 33 lb/Mgal guar in 4% KCl respectively. Blend A was prepared by adding 75% vol. of surfactant-based fluid to 25% vol. of polymeric fluid; while Blend B resulted from the addition of 25 and 75% vol. of these fluids. The 20 nm silica nanoparticles were added to achieve three nano-fluid concentrations (0.058%, 0.24%, and 0.4% wt.) for each clean fluid. Rheological data were gathered by conducting viscometry and frequency sweep tests using the Bohlin CS-50 rheometer within a temperature range of 75 to 175 °F. The results indicate that 20 nm silica nanoparticles are beneficial in terms of enhancing rheological properties in surfactant-based and polymeric nano-fluids up to particle concentration of 0.24% and 0.4% respectively. Blend A nano-fluids show similar results at 0.058%, and only at 0.4% at high shear rates. Similarly, Blend B displayed favorable results up to 0.24% and at high temperature applications only (125 to 175 °F). Finally, relative viscosity correlations are developed for predicting viscosity of nano-suspensions.
The application of nanotechnology on the rheological properties of SBF, polymeric fluids, and SBF-polymeric fluid blends delivers on great benefits, if nanoparticle concentrations are carefully selected. These nano-fluids will be applicable for oilfield operations such as hydraulic fracturing.
Fiber-Enhanced Proppant Plugs Ensure Zonal Isolation During Multistage Coiled Tubing Abrasive Perforation and Stimulation in Horizontal Sidetracks
Authors: Burdin K. V. , Oparin M. V. , Adil A. R. , Popov M. A. , Klimenko V. , Bravkov P. V. , Klyubin A. , Novikov M , Potryasov A. A. , Kovalev V. N. 
Published: March 2013

Abstract
Horizontal drilling and multistage fracturing completions are becoming widespread practices in the development of Western Siberia’s low-permeability oil fields. More than 100 wells have been completed to date—with success from both operational and production perspectives. The majority of applications were applied in newly drilled wells, where it is possible to install openhole packers and frac ports for isolating fracture stages. The concept of multistage fracturing was transferred to old areas of brownfields, where sidetracks drilling was the main method of increasing oil recovery. Traditional sidetracks were associated with risks of production underachievement in low-permeability environments - even after stimulation treatments.
The ability to drill sidetracks with a considerable horizontal section, and stimulating them with several fracturing stages would improve production significantly. However, slim wellbores of sidetracks significantly restrict completion option choice and abrasive perforating via coiled tubing (CT) becomes a universal enabler for multistage fracturing treatments. One of the greatest challenges in such a process is isolation between the stages. Fiber-enhanced proppant plugs were used for better proppant grains suspension, which sets the plug in the most efficient, homogeneous way.
The first well was recently completed with this method. Three stages of fracturing stimulation were performed with CT abrasive perforation; fiber-enhanced proppant plugs were placed at the tail-in of the first two fractures. In both of the fractures, reliable isolation was achieved at first attempt. After all three stages were placed, wellbore cleanout with CT was performed, followed by nitrogen kickoff. Oil production has exceeded expectation by 30%.
Multistage fracture (MSF) stimulation in the horizontal section of a sidetrack well completed with cemented liner with the utilization of abrasive perforating and fiber-enhanced proppant plugs has demonstrated unique value, as it is the only effective solution currently available for these conditions. The decision-making and candidate-selection processes, execution and lessons learnedare described.