bluuebunny/crossref_metadata_2025_split huggingface dataset:
Effects of treatment of reading skills in a child with borderline intellectual functioning
Authors: Di Blasi Francesco D. , Savelli Enrico , Zingale Marinella , Buono Serafino , Di Nuovo Santo F. 
Published: June 2013

AbstractBackground:People with borderline intellectual functioning (BIF) show difficulties in academic achievements. They often struggle to read fluently and display poor reading comprehension. However, they usually are not properly diagnosed with specific reading deficits and, consequently, no treatment program is prescribed. Thus, reading remediation for subjects with BIF remains largely unexplored. This work investigated the effectiveness of an intervention aimed at improving reading in a child with BIF.Methods:A computer reading program based on the dual-route model was used for a period of 3 months with the aim of automatizing word recognition and assembling of sub-lexical units (phonemes). Reading performance was measured before and after treatment.Results:The reliable change index of reading skills during pre-post treatment and at follow-up showed significant improvements in text, word, and nonword reading accuracy, rather than in reading speed.Discussion:Findings are discussed in terms of specific characteristics of the treatment and benefits that can be obtained in children with BIF.
Crystal structure of bis(1,10-phenanthroline-κ2N,N) (tetrafluorophthalato-κO)nickel (II)-tetrafluorophtalic acid (1:1), [Ni(C8F4O4)(C12H8N2)2](C8H2F4O4), C40H18F8N4NiO8
Authors: Liu Yuan-Ying , Guo Jin-Fu , Li Hui-Yun , Zhao Guo-Yan 
Published: June 2013

Abstract C40H18F8N4NiO8, triclinic, P1̅ (No. 2), a = 11.5061(2) Å, b = 11.8003(3) Å, c = 14.5181(3) Å, α = 111.888(2)°, β = 101.867(2)°, γ = 95.595(2)°, V = 1756.8 Å3, Z = 2, Rgt(F) = 0.0490, wRref(F2) = 0.1169, T = 296 K.
Mapping thermal resistance around vacancy defects in graphite
Authors: Oliveira Laura de Sousa , Greaney P. Alex 
Published: June 2013

ABSTRACTHigh purity bulk graphite is applicable in many capacities in the nuclear industry. The thermal conductivity of graphite has been found to vary as a function of how its morphology changes on the nanoscale, and the type and number of defects present. We compute thermal conductivities at the nanolevel using large scale classical molecular dynamics simulations and by employing the Green-Kubo method in a set of in silico experiments geared towards understanding the impact of defects in the thermal conductivity of graphite. We present the results obtained for systems with 1– 3 vacancies, and compile a summary of some of the methods applied and difficulties encountered.
Deciphering the Fundamental Controls of Flow in Carbonates Using Numerical Well-Testing, Production Optimisation, and 3D High-resolution Outcrop Analogues for Fractured Carbonate Reservoirs
Authors: Agada Simeon , Chen Fuzhen , Geiger Sebastian , Toigulova Gulnara , Agar Susan , Benson Greg , Shekhar Ravi , Hehmeyer Owen , Amour Fred , Mutti Maria , Christ Nicolas , Immenhauser Adrian 
Published: June 2013

Abstract
Carbonate reservoirs contain a significant portion of the world’s proven hydrocarbon reserves but are challenging to produce due to their complex lithologies, structural heterogeneities, and neutral to oil-wet nature. Increasing recovery requires a better understanding of how different recovery processes respond to the heterogeneities inherent to these reservoirs. This will contribute to the design of appropriate engineering solutions which extend the life of mature fields and develop green fields more effectively.
We use a high-resolution 3D outcrop model of a Jurassic carbonate ramp in order to perform a series of detailed and systematic flow simulations. The aim is to test the impact of small- and large-scale geological features on reservoir performance and oil recovery. The outcrop analogue model is of excellent quality comprising a wide range of diagenetic and structural features, including discontinuity surfaces, mud mounds, mollusc banks and fractures. Flow simulations are performed for numerical well-testing and secondary oil recovery. Numerical well-testing allows us to generate synthetic but systematic pressure responses for different geological features observed in the outcrops. This allows us to assess and rank the relative impact of specific geological features on reservoir performance. The outcome documents that, due to the high level of matrix heterogeneity, most diagenetic and structural features cannot be linked to a unique pressure signature. Instead, reservoir performance is controlled by sub-seismic faults and mollusc banks acting as thief zones. Numerical simulations of secondary recovery processes reveal strong channelling of fluid flow into high-permeability layers. This is the primary control for oil recovery. However, appropriate reservoir engineering solutions such as optimising well placement and injection fluid can reduce channelling and increase oil recovery.
Optimizing the Waterflooding Performance of a Carbonate Reservoir with Internal Control Valves
Authors: Carvajal G. A. , Wang F. , Lopez C. , Cullick A. S , Al-Jasmi A. , Goel H. K 
Published: June 2013

Abstract
Intelligent digital oilfield (iDOF) operations include the transfer, monitoring, visualization, analysis, and interpretation of real-time data. Enabling this process requires a significant investment to upgrade surface, subsurface, and well instrumentation and also the installation of a sophisticated infrastructure for data transmission and visualization. Once upgraded, the system is then capable of transferring massive quantities of data, converting it into real information at the right time.
The transformation of raw data into information is achieved through intelligent, automated work processes, which are referred to here as "smart flows." Smart flows assist engineers in their daily well surveillance activities, helping make them more productive and improve decision making. A major oil and gas operator in the Middle East has invested in such an infrastructure and is developing a set of smart flows for key activities and workflows for its production operations, with the ultimate goal of improved asset performance.
In response to early water breakthrough, a study was commissioned to investigate whether smart completions that use down-hole internal control valves (ICVs) could provide a range of fluid-flow control options to enhance reservoir sweep efficiency, reduce produced water, and increase well life.
This paper describes the strategy and process to identify production and injection wells best suited for intelligent well completions in the Sabriyah field, Mauddud reservoir. The goal is to control zonal injection and production rates to reduce uneven water fronts, sweep and produce bypassed oil, postpone water breakthrough, and extend well life, thus boosting oil production while optimizing water handling at the surface. The study demonstrates excellent potential for down-hole control to significantly improve operations in the water injection areas.
Residual Oil Saturation Determination – Case Studies in Sandstone and Carbonate Reservoirs
Authors: Teklu Tadesse Weldu , Brown Jeffrey S. , Kazemi Hossein , Graves Ramona M. , AlSumaiti Ali M. 
Published: June 2013

Abstract
In petroleum reservoirs only a small fraction of the original oil-in-place is economically recovered by primary, secondary, and tertiary recovery mechanisms. A considerable amount of hydrocarbon ends up unrecovered or trapped due to microscopic phase trapping in porous media which results in an oil recovery factor typically less than 50%. Waterflooding is by far the most widely used method to increase oil recovery. The oil that remains in the porous media after waterflooding is called remaining oil saturation (ROS) which is larger than the relative permeability residual oil saturation (Sorw or simply Sor). This residual oil saturation varies depending on lithology, pore size distribution, permeability, wettability, fluid characteristics, recovery method, and production scheme. The Sor represents a statistical average over a wide range of pore scale residual saturations with in a representative elementary volume (REV). Determination of the residual oil saturation of a reservoir is a key parameter for reserve assessment and recovery estimates. Further, reliable Sor data is important for investigation of potential incremental recovery under Enhanced Oil Recovery (EOR) methods.
Various residual oil saturation measurement techniques are available both at laboratory and field scale. None of the techniques can be regarded as a single best method of determining Sor. Depending on the complexity of the reservoir under study, combinations of methods are always advisable for appropriate Sor determination. This paper catalogues a number of field case studies which use different techniques of determining Sor and ROS in sandstone and carbonate reservoirs.
Beyond Expected Value: Integrated Project Valuation for Decision Making Under Uncertainty
Authors: Xu Jingzhen 
Published: June 2013

Abstract
Many decisions in petroleum exploration and development have to be made with significant uncertainties. Stochastic simulations are frequently used to capture the consequences of a decision in relation to the uncertain variables within reservoirs, infrastructures and economics. The results of stochastic simulations are often used in the following risk management process to optimize decisions. A big challenge in this process is to frame the outputs of stochastic simulations in a manner which makes sense to the decision-maker and provides him with clear judgemental insights into the problem and its related uncertainties. Traditional decision-tree analysis provides a good way of formulating and structuring decision problems, but one of its disadvantages is that only the expected value is used at a decision node. Most of the decision issues involve both continuous and discrete uncertainties, which can only be fully evaluated using distribution functions. By combining the decision-tree approach with stochastic simulation the term of expected value can be extended to a distribution function. Distribution functions can provide more details than expected values for understanding the influence of relevant uncertainties in the context of a full risk spectrum. Depending on the decision-maker’s risk preference, decisions can be made based on not only the expected value but also upside or downside. A simple example on Value of Information is used to demonstrate the combination of decision-tree approach and stochastic simulation, where the value of information realized by a decision is quantified by a distribution function through Monte Carlo simulation rather than an expected value. A real decision situation concerning infill drilling in a North Sea field is presented to show the procedure of stochastic modeling of a decision tree in the framework of integrated project valuation. Important decisions along the time horizon include scheduling of drilling campaign, pilot or side-track drilling of adjacent prospects, and installing of a new template.
Geology and Geohistory Contribute to Flow Assurance, Part II: Asphaltene Risk Evaluation Incorporating Geological Heterogeneity and Covering All Operating Temperature
Authors: Yonebayashi Hideharu , Tosic Slavko 
Published: June 2013

Abstract
In the Kashagan field, a super giant offshore carbonate field, located in the North Caspian Sea, asphaltene risks have been continuously under evaluation. The previous work done by Yonebayashi et al. (2012)1 included asphaltene risk evaluation incorporating geology and geohistory. Work showed good correlation between fluid sampling location and experimental asphaltene onset pressure (AOP) detection at reservoir temperature. However, a boundary condition of asphaltene precipitation/no-precipitation had some range of uncertainty. The previous work focused at the reservoir temperature condition only.
This paper will present more detailed discussion of asphaltene risk by updating new AOP results, and it will capture range of temperature conditions (i.e. from reservoir temperature to surface operating temperature). For integrating these updates into the Risk-Matrix-Chart proposed in the previous work, geological heterogeneity of fluid sampling location will be taken into account. A study of numerical modeling, applying Redich-Kwong-Soave (RKS) cubic equation of state, treated the geological heterogeneity as variation of asphaltene content, and reproduced asphaltene precipitation envelopes (APE) which were well matched to overall trend of experimental AOP detection. To conclude, this work achieved to reduce uncertainty of asphaltene precipitation boundary at reservoir temperature, and showed a consistent shifting of asphaltene precipitation boundary by temperature range.
Pressure Transients in a Fractal-Cluster Model of Porous Media
Authors: de Swaan A. 
Published: June 2013

Abstract
The reservoir is described as a "supercritical cluster"; that is, an aggregate of condutive elements that comprises a "backbone" of connected pores or fractures that span the zone of interest, and also a collection of "sub-critical clusters" or "dangling ends" joined to the backbone to a limited extent. The scheme resembles the usual fracture and matrix-blocks setting but both backbone and sub-clusters are of the same material and share similar petrophysical properties. Whereas the backbone is a homogeneous porous medium, the sub-critical clusters behave as fractal porous media. The backbone-cluster type of flow has been observed in laboratory experiments.
The sub-critical clusters were approximated as linear fractal media characterized by static and dynamic fractal exponents and also by porosity and permeability of the compound medium. One of the ends of the linear clusters is closed and the other is joined to the backbone, where the mainstream occurs. A new solution was developed for that problem. The Laplace transform in time and space was used in the mathematical scheme.
The theory developed was applied to field cases of interference between wells in aquifers. The matches of computed and observed dynamic pressures show fair fits.
A Review of the Status of Foam Applications in Enhanced Oil Recovery
Authors: Farzaneh Seyed Amir , Sohrabi Mehran 
Published: June 2013

Abstract
Foam has been used for controlling gas mobility during injection processes in order to mitigate the adverse effects of low gas viscosity, reservoir heterogeneity and gravity override. In addition, foam has also been employed in near-wellbore production, matrix acidizing stimulation, hydraulic fracturing, gas shut-off and water shut-off. The optimization of these operations requires a good understanding of the physical characteristics of foam and its behavior under reservoir conditions. Despite numerous experimental and theoretical studies on foam and some field applications reported in the literature, there is no comprehensive literature survey detailing the knowledge and experience gained through the application of foam. The aim of this paper is to present a critical review of the literature available on the use of foam injection for enhanced oil recovery. An extensive appraisal of the current status of foam application in EOR methods is a useful way of presenting advantages, shortcomings and limitations of the process as well as supplementary advances. Special attention has been given to the review of new research topics, such as the use of foam as a mobility control agent. Advances in more efficient foaming agents, additives and boosters are discussed. Moreover, in depth analysis of field applications of foam in EOR projects show that the main problems encountered during field-scale foam applications are related to foam stability, foam compatibility, as well as adsorption of the injected chemicals onto the rock surface. To address this, we discuss the evolution of the pilot field application and the reasons for inconsistency between laboratory results and field scale performance.
Effect of Thermally Induced Deformation of Shale on Wellbore and Caprock Integrity
Authors: Li Biao , Wong Ron 
Published: June 2013

Abstract
During thermal enhanced oil recovery processes such as Cyclic Steam Stimulation (CSS) and Steam Assisted Gravity Drainage (SAGD), heat is transferred from the wellbore and reservoir to the surrounding formation. The thermally induced deformation in shale can pose an impact on casing and caprock integrity. In this research, thermally induced deformation in argillaceous shale was studied by applying an anisotropic thermal-strain model. Shale's intrinsic fabric anisotropy is considered in this new model. Thermally induced strain in shale is contributed by the strain of the solid particle and the strain in clay mineral's microspace such as Stern layer (bound water) and Diffusion Double Layer (DDL). The proposed anisotropic thermal-strain model was used to study on thermally induced deformation behaviors of argillaceous shale in Western Canada Sedimentary Basin (WCSB). The modeled volumetric strain indicates that shale could contract or dilate depending on the clay content and temperature. The resultant behavior represents the combined effect from the thermal expansion of the solid particle and the bound water as well as thermal contraction of the DDL in clay mineral. Due to the oriented fabric in shale, the thermal-strains along the vertical and the horizontal directions are different. Thermally induced contraction could cause loss in confinement provided by the formation and lead to fracturing. Numerical simulations were conducted to investigate temperature distributions around a thermal well for CSS and the reservoir-caprock interface for a SAGD project. The possibility of thermally induced contraction in shale and its impact on borehole and caprock integrity were evaluated.
Numerical Assessment of Caprock Integrity in SAGD Operations
Authors: Rahmati Ehsan , Rahmati Hossein , Nouri Alireza 
Published: June 2013

Abstract
This paper focuses on investigating the impact of Steam Assisted Gravity Drainage (SAGD) operations on caprock stresses. Steam injection, in SAGD operations, results in significant pore pressure, temperature, stress and volumetric changes in the reservoir. One outcome is the deformation and stress variations of the overburden strata that could lead to the containment breach of the caprock through shear or tensile failure.
We developed a model based on the nucleus-of-strain method to assess the reservoir volume changes caused by the combination of reservoir shear dilation, thermal expansion, and increased pore pressure during the SAGD operations. We then developed a forward geomechanical model and used the reservoir volume changes as input data. The nucleus-of-strain model was verified by comparing the measured surface heave data with the same from the forward model.
The geomechanical model was used along with the Mohr-Coulomb failure criterion to assess the stresses and failure potential of the overburden strata. The model was applied to a SAGD reservoir for which surface heave data were available. The outcome indicates the potential for caprock integrity problems due to tensile fracturing. A parametric study was also performed to investigate the sensitivity of the predictions to various significant parameters including the Young's modulus, Poisson's ratio, in situ stress gradient, and reservoir depth, among others. The outcome of the parametric studies will be discussed in this paper.
Modeling Three-Phase Flow During Steam Chamber Rise-Impact of Water Drainage on Oil Production Rate
Authors: He Zhongxue , Murtaza Muhammad , Dehghanpour Hassan 
Published: June 2013

Abstract
The existing models for steam chamber rise rate ignore the effect of water drainage that can result in three-phase flow near the finger/chamber edge. We hypothesize that a steam finger can be divided into three different regions with different pore scale displacement mechanisms. We develop the flux equations for the three regions by assuming 1) negligible oil flow inside the finger, 2) three-phase flow in the transition zone, and 3) single-phase oil flow beyond the transition zone. We further assume that oil flow is coupled to water flow in the transition zone where the dominanat pore-scale mechanisms are double displacement, coalescence, and film drainage. The model results suggest that fast drainage of water in the transition region enhances the oil displacement rate due to the flow coupling. However, increase of the transition zone thickness, due to slow water drainage, decreases the chamber rise rate because of the decrease in the rate of heat conduction to the cold bitumen.
Determination of Thermal Conductivity of Carbonate Cores
Authors: Chen Joyce , Donald James , Huang Haibo , MacDonald Jeff , Jiang Qi , Rabin Mark , Yuan Jian-Yang 
Published: June 2013

Abstract
The difficulties of accurately measuring thermal properties, such as thermal conductivity of fractured and/or vuggy rocks are well known. Many commercially available methods are suitable only for liquids or re-packed sands. Others either require samples to be fairly uniform or are potentially destructive due to sample size limitations. In-situ measurements are possible, but can be costly. It can also be affected by in-situ distributions of fluids in the fractures and vugs, such as water, oil and possibly gas. In order to adapt the highly non-uniform nature of the carbonate cores without having to create further destruction of these cores, we developed a non-destructive method for measuring thermal conductivity of highly vuggy and moderately fractured carbonate cores in their whole diameter. In this paper, we report the theoretical background of this methodology; laboratory observations of thermal behaviours; data analysis and resulting thermal conductivity values of carbonates cores. Using this method, we measured 20 cleaned carbonate cores (88 mm in diameter) from Grosmont C and D Formation in Saleski area. Measured thermal conductivity values ranged from 1.00 to 2.87 W/m•K in Grosmont C, and 0.82 to 3.16 W/m•K in Grosmont D. These values were determined to be a strong function of porosity rather than mineralogy, as the Grosmont Formation typically consists of greater than 95% dolomite. These measurements are also shown to be in good agreement with prior studies on non-fractured dolomite reservoirs. A correlation for thermal conductivity was derived which can be used for numerical simulation models.
Experimental and Numerical Study of VAPEX at Elevated Temperatures
Authors: Haghighat Parnian , Maini Brij , Abedi Jalal 
Published: June 2013

Abstract
Incorporating some heat injection along with the solvent injection appears to be the most viable option for improving the drainage rate of VAPEX in extra-heavy oil formations. The obvious question then concerns the magnitude of temperature increase needed to make the drainage rate economical. The objective of this work was to examine the effect of temperature on VAPEX performance.
VAPEX experiments under different operating conditions were conducted in a high-pressure physical model. Physical model was packed with 250 Darcy sand and saturated with Athabasca bitumen (Mackay River oil). Injecting propane at 0.817 MPa, temperatures from 40 to 60ºC were tested to investigate possible improvement to oil production rates. Experimental results were numerically simulated with a commercial compositional simulator, Computer Modelling Group's (CMG) GEM. CMG's WinProp module, along with available experimental data, was employed to model the phase behavior and properties of the propane / Athabasca bitumen system.
By history matching the experimental production data, results were extended to wider ranges of temperature and VAPEX performance at elevated temperatures was investigated. According to the results, substantial improvement in the performance of VAPEX in reservoirs containing this type of oil would require increasing the reservoir temperature above 60ºC.