bluuebunny/crossref_metadata_2025_split huggingface dataset:
Carbon Nanotube-Based High Temperature Vacuum Microelectronics for E&P Applications
Authors: Manohara H.. , Mojarradi M.. , Toda R.. , Lin R. H. 
Published: June 2012

Abstract
Field emission from carbon nanotube (CNT) bundles has been applied to develop new class of computational vacuum microelectronics for harsh environment applications. CNTs have demonstrated superior field emission performance because of their low emission threshold, high current density, and are conducive for monolithic integration with silicon structures to develop microelectronic/microsensor systems. In this paper we present high-temperature tolerant "digital" vacuum electronics using CNTs. This technology is applicable to in situ sensor electronics for down-hole applications where the operating environment is high temperature, high pressure, and has corrosive chemicals. The digital and analog electronic devices developed using CNT-vacuum microelectronic technology can be integrated with sensor systems to achieve prolonged stand-alone operation during E&P. NASA-JPL has developed high performance cold cathodes using arrays of carbon nanotube bundles that produce &gt; 15 A/cm2 at applied fields of 6 to 8 V/μm. They have exhibited robust operation in poor vacuums of 10‒7 to 10‒4 Torr-a typically achievable range inside hermetically sealed microcavities. By monolithically integrating CNT cathodes with micromachined Si multi-gate structures we have demonstrated a new class of programmable "vacuum" logic gates. We have achieved switching operation at temperatures up to 700° C. The initial design, operation, and the potential performance in an improved design will be presented in this paper along with vacuum packaging techniques to make stand alone devices for circuit board integration. CNT-vacuum microelectronics opens up a new regime of in situ electronics for novel sensor/electronics systems because of their inherent high-temperature tolerance, and corrosion resistance. Unlike traditional vacuum tubes, these are low power, miniature, and potentially as fast as their solid-state counterparts while exhibiting superior reverse bias or leakage current characteristics. These devices offer potential to significantly enhance E&P operation.
An Analysis of the Caprock Failure at Joslyn
Authors: Carlson M. R. 
Published: June 2012

Abstract
A significant caprock failure occurred on the Joslyn SAGD property in 2006, which has had a wide impact on the approval process for future SAGD projects. Two reports were released by the Alberta Government: "Total E&P Canada Ltd., Surface Steam Release of May 18, 2006, Joslyn Creek SAGD Thermal Operation, ERCB Staff Review and Analysis, February 11th, 2010" and "Summary of Investigations into the Joslyn May 18th, 2006 Steam Release, Total E&P Canada Ltd.". The latter report is very large. A number of potential mechanisms are postulated without definitive resolution. The most likely failure suggested involved transmission of fluids up a 50,000 mD chimney and a pancake shaped lens of high pressure steam that resulted in a shear failure of the caprock.
The author believes that this scenario is unlikely from a geological and heat transfer perspective. There are other anomalies. Peak stresses in most caprock coupled reservoir-geomechanical simulations normally peak between 3 to 7 years after start-up. However, the Joslyn failure occurred immediately after conversion from partial SAGD to full SAGD, in which the producing well was killed and a PCP pump was run.
There are other issues that should be considered that include: How hydraulic fractures are initiated and propagated. The literature shows us: computer design programs that predict fracture propagation and shape,analytical solutions that also show expected fracture morphology; and,physical examples which have been dug up or coredIn addition the geological record provides excellent analogue information on the morphology of high pressure intrusions. These various types of data will be compared to the observed morphology derived from the 3D seismic.
Earlier work by Edmunds and Good has shown that extremely transient conditions exist in SAGD wells that result in "geysering" or slugging within the producing well. The energy available from water and steam is enormous. The nuclear and power industry previously made these similar discoveries after a series of catastrophic failures of piping systems. Analytical and computer simulation tools from the nuclear industry will be used to show that extremely high pressure transients, many times over fracture initiation pressures, can be expected. This is the same mechanism that resulted in the catastrophic failure of MEG Energy’s Christina Lake main steam distribution line.
In summary, there is every reason to believe that when hot steam was injected into a cooled (water) condensate filled well; very large pressure transients can be expected from phase changes within the piping that should result in a frac to surface.
An Experimental Investigation of Polysilicon Nanoparticles’ Recovery Efficiencies through Changes in Interfacial Tension and Wettability Alteration
Authors: Roustaei Abbas , Moghadasi Jamshid , Iran Abadan , Bagherzadeh Hadi , Shahrabadi Abbas 
Published: June 2012

Abstract
New technologies are emerging oil industry to afford the need for increasing oil recovery from oilfields, one of which is Nanotechnology. This paper experimentally investigates a special type of Nanoparticles named Polysilicon ones which are very promising materials to be used in near future for enhanced oil recovery. There are three types of Polysilicon Nanoparticles which can be used according the reservoir wettability conditions. In this paper, hydrophobic and lipophilic polysilicon (HLP) and naturally wet polysilicon (NWP) are investigated as EOR agents in water-wet sandstone rocks. These two Nanoparticles recover additional oil through major mechanisms of interfacial tension reduction and wettability alteration. The impact of these two Nanoparticle types on water-oil interfacial tension and the contact angle developed between oil and the rock surface in presence of water phase were investigated. Then, several coreflood experiments were conducted to study their impacts directly on recoveries. Furthermore, optimum pore-volume injection of each Nano-fluid was determined according the pressure drop across the core samples.
The results show a change toward less water-wet condition and a drastic decrease in oil-water interfacial tension from 26.3 mN/m to 1.75 mN/m and 2.55 mN/m after application of HLP and NWP Nano-fluids respectively. As a result, oil recoveries increase by 32.2% and 28.57% when a 4 gr/lit concentration of HLP and NWP Nano fluids are injected into the core samples respectively. According the differential pressure data, two and three pore-volume injections of NWP and HLP Nano-fluids are the best injection volumes respectively. Finally, HLP and NWP Nanoparticles improve oil recovery without inducing any formation damage according the oil recovery and pressure drop data.
Stability and Mobility of Functionalized Silica Nanoparticles for Enhanced Oil Recovery Applications
Authors: Miranda Caetano Rodrigues , de Lara Lucas Stori , Tonetto Bruno Costa 
Published: June 2012

Abstract
For any possible application of hard nanoparticles as an improved oil recovery agent, it is necessary to have a stable wettability modifier with improved mobility properties under broader oil reservoir conditions. Typical oil reservoir conditions with high temperature, pH and electrolytes concentration modifies the way that nanoparticles interact with the solution. In this work, the wettability and fluid diffusivity at the molecular level were studied through Molecular Dynamics simulation. We have studied the stability and mobility of functionalized (hydroxylated, PEG and sulfonic acid) silica nanoparticles for enhanced oil recovery applications, particularly at high salt concentration and high temperature. In order to stabilize the interfacial energy in the nanoparticle-brine interface, ions tend to modify the transport properties of the nanoparticle itself. We have observed an increasing in the diffusion coefficients for nanoparticles with increasing salt concentration at 300K and 0.1 MPa pressure. Our calculations also indicate that adsorption properties and salt solutions greatly influence the interfacial tension in an order of CaCl2 &gt; NaCl. This effect was found to be due to the difference in distribution of ions in solution, which modifies the hydration and electrostatic potential of those ions near the nanoparticle. The brine/oil interfacial tension variation due to functionalized silica nanoparticles was also determined as a function of the terminal group hydrophobicity at 1% salt concentration (CaCl2 and NaCl), 300K and 0.1 MPa pressure.
Focused Magnetic Heating Utilizing Superparamagnetic Nanoparticles for Improved Oil Production Applications
Authors: Davidson Andrew , Huh Chun , Bryant Steven L. 
Published: June 2012

Abstract
A novel method of delivering thermal energy efficiently for flow assurance and for improved heavy oil production/transport is described. The method, an improved form of magnetic induction heating, uses superparamagnetic nanoparticles that generate heat locally when exposed to a high frequency magnetic field oscillation, via a process known as Neel relaxation. This concept is currently used in biomedicine to locally heat and burn cancerous tissues.
Dependence of the rate of heat generation by commercially available, single-domain Fe3O4 nanoparticles of ∼10 nm size, on the magnetic field strength and frequency was quantified. Experiments were conducted for nanoparticles dispersed in water, in hydrocarbon liquid, and embedded in a thin, solid film dubbed "nanopaint". For a stationary fluid heat generation increases linearly with loading of nanoparticles. The rate of heat transfer from the nanopaint to a flowing fluid was up to three times greater than the heat transfer rate to a static fluid.
Heating of nanopaint with external magnetic field application has immediate potential impact on oil and gas sector, because such coating could be applied to inner surfaces of pipelines and production facilities. A nanoparticle dispersion could also be injected into the reservoir zone or gravel pack near the production well, so that a thin, adsorbed layer of nanoparticles is created on pore walls. With localized inductive heating of those surfaces, hydrate formation or wax deposition could be prevented; and heavy oil production/transport could be improved by creating a ‘slippage layer’ on rock pore walls and inner surfaces of transport pipes.
Nanotechnology-Assisted EOR Techniques: New Solutions to Old Challenges
Authors: Ayatollahi Shahab , Zerafat Mohammad M. 
Published: June 2012

AbstractEnhanced Oil Recovery techniques are gaining more attention worldwide as the proved oil reserves are declining and the oil price is hiking. Although many giant oil reservoirs in the world were already screened for EOR processes, the main challenges such as low sweep efficiency, costly techniques, possible formation damages, transportation of huge amounts of EOR agents to the fields especially for offshore cases, analyzing micro-scale multi-phase flow in the rock to the large scale tests and the lack of analyzing tools in traditional experimental works, hinder the proposed EOR processes.Our past experiences on using nanotechnology to the upstream cases, especially EOR processes, revealed solutions to some of the challenges associated with old EOR techniques. This method that utilizes particles in the order of 1 to100nm brings specific thermal, optical, electrical, rheological and interfacial properties which are directly useful to release the trapped oil from the pore spaces in the order of 5 to 50 microns of tight oil formations.Laboratory tests using nanoparticles as the EOR agent, developing nano computational models to explore the surface properties and utilizing nano-scale analyzing tools such as atomic force microscopy (AFM), scanning electron microscopy (SEM) and X-ray photoelectron spectroscopy (XPS) mostly for nanoparticles distribution in the pore spaces and on the surfaces for wettability alteration studies are the main parts of this investigation.This paper summarizes new findings from several different theoretical, analytical and experimental works which shows the effectiveness of traditional methods when assisted by this new technology. Ultimately, based on the past experiences, a roadmap will be proposed to avoid the ongoing trial and error practice in this area.
Magnetic Characterization of Nanoparticles Designed for Use As Contrast Agents for Downhole Measurements
Authors: Avendano Carolina , Lee Seung Soo , Escalera Gabriela , Colvin Vicki 
Published: June 2012

Abstract
Nanotechnology has already contributed significantly to advances in several industries, e.g. electronics, biomedical, aerospace, and more recently the energy industries. In particular, nanotechnology has the potential to pioneer changes in several areas of the oil and gas industry, such as exploration, drilling, production, enhanced-oil-recovery (EOR), and refining. For example, superparamagnetic nanoparticles that could act as contrast agents could be used to accurately determine the oil saturation distribution in a reservoir and help determine bypassed oils. Moreover, by correctly functionalizing the surface of the magnetic nanoparticles, colloidal suspensions of these nanoparticles that are stable at high temperatures and high salinities (oil-well conditions) can be prepared and could be co-injected with sweep and/or fracture fluids and their location determined and tracked over time by electromagnetic measurements. With this in mind, a study of the magnetic properties of ferrite nanoparticles with varying compositions (MFe2O4; M = Fe, Al) has been conducted to determine the magnetic responses of the various particles in order to evaluate the likelihood of using them as magnetic contrast agents in the oil and gas industry.
Water Injection Patterns Optimization Approach on High-Viscous Oil in Russkoye Field
Authors: Zakirov I. , Shayhutdinov I. , Svarovskaya M. , Gaviria W. , Shmidt S. , Shakirova A. 
Published: June 2012

Abstract
Russkoye field, discovered in 1968, is a giant high-viscous oil field located above the Polar Circle in Russia. The commercial development of the field has been a tremendous challenge due to several factors such as a very complex heterogeneous shallow reservoir with a large gas cap, an active bottom aquifer, unconsolidated sands, low temperature, and permafrost zone. At this stage, the development of the field is still on the pilot testing stage in order to understand and evaluate different possible development strategies that assure the maximum recoverable reserves for this kind of field.
As part of the development strategy, eight water injection pattern schemes including horizontal and vertical wells, and different well spacings were simulated to find the optimal waterflooding patterns, and to evaluate different well trajectories, and different injection bottomhole pressures, for the next pilot area.
The water injection pattern schemes evaluated were horizontal wells line drive, 7-spot, 7-spot inverted, 9-spot, 9-spot inverted, 5 spot, combined line drive with horizontal producers and two deviated injectors, and combined line drive with horizontal producers and three deviated injectors.
The complete analysis was carried out on the basis of the technical results and the economical evaluation. Several parameters were studied to compare performance and efficiency of different water injection patterns, such as voidage replacement ratio, cumulative oil, water and gas, production profiles, sweep efficiency, injected pore volume, and reservoir pressure behavior. The optimization of the four well spacings between 100 m and 400 m and the injection bottomhole pressure range was performed using an analytical approximation. The economical evaluation for each water injection pattern analyzed was executed by means of the economical standard analysis: net present value, internal rate of return, profitability index, lifting cost, and payback period.
Paradigm Shift in Polycrystalline Diamond Bit Design for Canadian Heavy Oil Sands
Authors: Maw Jason , Knull Craig , Clegg John 
Published: June 2012

Abstract
PDC drill bits have grown from niche to mainstream products by gradual, subtle evolutions in design and materials technology. Occasionally, there have been more dramatic step changes in design or materials that have launched PDC bits into new applications. This paper will talk about such a step change: the design, manufacture and application of a contiguous blade of polycrystalline diamond. Rather than blades made up from individual cutters, as with a conventional PDC bit design, this bit has full-length, contiguous polycrystalline diamond coverage, without gaps between cutters on each blade. The advantages of this arrangement are many. Most obvious is the ability to drill erosive and/or abrasive formations without erosion. Often PDC bits, especially lighter set bits, can lose steel or matrix body material between the cutters due to erosion or abrasion, and this can be life-limiting. With no gaps between the cutters, this ceases to be a problem. Other possibilities include: bits for more conventional formations where a contiguous blade can be used instead of backup cutters, enhancing ROP and stability. The paper describes how various challenges were overcome: bit design; materials selection; polycrystalline diamond blade manufacture. It will also discuss applications of this technology in bits specially designed for the oil sands in northern Alberta, Canada, focusing on: Dull condition enhancement as a result of avoiding cross-blade erosion and abrasionPolycrystalline diamond blade durabilityThe effect of a smaller number of contiguous blades on ROP and PDC bit economics.
This represents a step change in bit design with the potential to redefine bit design across the applications spectrum.
Upscaling Study of Vapour Extraction Process through Numerical Simulation
Authors: Xu Suxin , Zeng Fanhua , Gu Yongan , Knorr Kelvin D. 
Published: June 2012

Abstract
Vapour Extraction (VAPEX), a process to recover heavy oil by injecting vapourized solvent into a reservoir, has been extensively studied through small-scale 1-D and 2-D laboratory tests. Recently, a series of large-scale 3-D tests have been conducted by Saskatchewan Research Council (SRC). In this study, 2-D tests were conducted under the same conditions as those for the 3-D tests; then, numerical simulation models were investigated to reduce the uncertainty in upscaling the results from 2-D tests to 3-D tests. This helps to better understand the uncertainty in predicting the field-scale VAPEX performance.
Plover Lake heavy oil was used in the tests, and the sandpack permeability was about 4.4 Darcy. In each test, the initial waterflooding was conducted prior to the subsequent solvent injection. Then, a numerical model was established to simulate the 2-D test. History match of the 2-D test was conducted by tuning the uncertainties such as the relative permeability, capillary pressure, solubility, and the wall effect in sand-packing. Afterwards the tuned parameters were applied to predict the 3-D test performance. Through comparison of the predicted and experimental results in the 3-D test, the capability of predicting up-scaled VAPEX processes through numerical simulation was examined, and the differences between physical and numerical modeling were identified.
The results show that the waterflooding performance can be successfully predicted, whereas the uncertainty in upscaling the VAPEX process is large. In the waterflooding period, the predicted oil recovery factor was 25.78% compared with 23.4% in the 3-D test. In the VAPEX process, the difference between the predicted and measured oil recovery factors was in the range of 0.75–25.14%, depending on the different combination of uncertain parameters. This fact indicates that different scales of physical modeling are required in order to reduce the uncertainties in predicting the field-scale VAPEX performance.
Estimation of Heavy Crude and Tar Sand Oils Viscosity in the Presence of Diluent
Authors: Bahadori Alireza 
Published: June 2012

Abstract
Heavy oil resources are assuming greater importance because of the increasing energy needs of the world. Compared to conventional oil, heavy oil is much more viscous and hence it presents many technical challenges at all stages of oil recovery and processing. In this work, a simple correlation, is presented here for prediction of heavy crude and tar sand oils viscosity as a function of kerosene volume fraction and temperature. The heavy crude and tar sand oils viscosity is calculated for temperatures in the range of 5 to 90°C and kerosene volume fraction up to 0.45. The proposed method is superior owing to its accuracy and clear numerical background, wherein the relevant coefficients can be retuned quickly if more data becomes available in the future. Estimations are found to be in excellent agreement with the reliable data in the literature with average absolute deviation being around 2%.
Duplex and Super Duplex Stainless Steels, and Their Applications in Steam Assisted Gravity Drainage (SAGD)
Authors: Schulz Zach , Reno Tyler 
Published: June 2012

Abstract
As oil reserves decrease, the level of difficulty to extract oil increases. With this increased difficulty, the service conditions involved in Steam Assisted Gravity Drainage (SAGD) are increasingly more aggressive. In an effort to maintain low raw material prices without sacrificing performance, duplex and superduplex stainless steels have been used for many applications to resist corrosion from chlorides, withstand extremely high pressure and still stay cost competitive. This summary of case histories shows where duplex stainless steels have been successfully utilized in the Alberta Oil Sands as well as across the globe. Duplex stainless steels have replaced leaner austenitic stainless steels and low alloy steels because of their increased corrosion resistance. In other cases, duplex and superduplex stainless steels have replaced higher nickel- chromium-molybdenum grades because of their lower cost and similar performance. For example, super duplex stainless steel has already been used as an alternate to six percent molybdenum grades in brine concentrators throughout Alberta, Canada.