bluuebunny/crossref_metadata_2025_split huggingface dataset:
Correlation Between Filter Cake Structure and Filtration Properties of Model Drilling Fluids
Authors: Li Yidan , Rosenberg Elisabeth , Argillier J. F. , Durrieu Josianne , Montes José 
Published: December 2007

ABSTRACT
This study was undertaken in order to correlate the filtration behavior of water based muds with the structural properties of the cake. The structure of the cake is analysed by cryo scanning electron microscopy that enables the visualisation of a section of the frozen cake.
Static and dynamic filtration experiments were performed both through rock slices and paper filters. On rock slices it is possible to visualize the structure of the internal cakes that invade the pores of the rock and in particular to show a selective filtration of the polymer when using a formulation containing bentonite and a fluid loss reducer.
When compared to static filtration, dynamic filtration of a clay suspension gives higher filtrate volumes but leads to a cake texture characterized by a more regular network and smaller pore size. The augmentation of the filtrate volumes with shear rates is the result of both a decrease of the cake thickness and a diminution of connections between the clay sheets induced by shear rates. When polymer is added the structure of the pore walls seems less affected by shear rates, probably because of the high degree of dispersion already reached in the suspension by addition of the polymer and the ability of polymer to establish connections between particles.
An Approach for Simulation of Paraffin Deposition in Pipelines as a Function of Flow Characteristics With a Reference to Teesside Oil Pipeline
Authors: Hamouda A. A. , Davidsen S. 
Published: December 2007

Abstract
Paraffin deposition is experienced in pipelines during transportation of oil when the oil temperature is cooled below its paraffin deposition temperature. The formed paraffin crystals in the bulk flow is believed to be transported by molecular, brownian diffusion and shear dispersion(1,2,3). Gravity settling mechanism in previuos work in our laboratory has shown to contribute to the total paraffin deposition, however, to a lesser extent than the above mentioned mechanisms.
The work done here demonstrates that the paraffin deposition by molecular diffusion mechanism is a dominant one. This is in agreement with other previous studies done on the paraffin depoition(4,5). In this study, however, experimental designe was made to quantify this statement. The paraffin concentration gradient (dc/dr) is the driving force of the molecular diffusion mechanism (where r is the pipeline radius). In pipelines the cooling rate is one of many other factors that affect the paraffin deposition profile.
Equipment was designed to simulate the flow characteristics at pipeline pressure. A three dimentional model was developed for paraffin deposition rates at various flow regimes. The developed experimental approach and the designed equipment for simulating the pipeline conditions are presented in this paper.
Polarity Characterization of Crude Oils Predicts Treatment Trends in Field Development
Authors: Brüning I. M. R. de Andrade 
Published: December 2007

Abstract
A method for determinig crude oil polarity using inverse gas chromatography proved successful for classifying crudes as well as for assessing their ability to form stable emulsions with water.
Polarity determinations have been applied to the formation test crude oil samples collected in Albacora and Marlim deepwater fields of the Campos Basin, Rio de Janeiro, Brazil. The results have been compared with the polarities of the first produced crudes of the Basin and showed that the emulsion separation problems tend to increase.
Polarity results provided substantial data to help production field development decisions.
Molecular Modeling Gives Insight into Nonionic Surfactants
Authors: Gdanski Rick 
Published: December 2007

Abstract
This paper describes the study of a nonionic surfactant through the use of molecular modeling software. The surfactant was decyl alcohol capped with 8 moles of ethylene oxide. This nonionic surfactant is a strong water-wetting agent as well as a good aqueous foaming agent. Four molecular dynamics studies of a single surfactant molecule were conducted under the following conditions:
at a water surface at 80°F in bulk water at 260°F in bulk hexane at 80°F at a hexane/water interface at 80°F
The conformations of the surfactant were observed and compared to known solubility data. The results from molecular modeling dynamics calculations will provide new insights into the behavior of surfactant molecules at surfaces and interfaces. This methodology was also extended to aggregates of surfactants to promote understanding of wetting behavior and non-emulsification behavior. In this paper, two studies were performed involving aggregates: one in bulk water at 80°F and another in bulk water at 260°F.
Dynamic Phase Composition, Density, and Viscosity Measurements During CO2 Displacement of Reservoir Oil
Authors: Grigg Reid B. 
Published: December 2007

ABSTRACT
A continuous phase equilibrium (CPE) apparatus was used to obtain composition, density, and viscosity for a West Texas recombined crude oil during the injection of high-pressure carbon dioxide (CO2). CO2 was continuously injected at constant pressure and flow rate. The system is maintained at constant pressure during CO2 injection by controlling the production rate. Compositions, densities, and viscosities of the produced fluids were determined at system pressures and temperature, providing continuous monitoring of fluid properties produced at outlets at both the top and bottom of the CPE apparatus.
The tests were run using both pure and impure CO2 at 105°F and pressures ranging from below to well above the minimum miscibility pressure (MMP). The solubility of the injected CO2 in the oil-rich phase was found to have little dependence on pressure, while the solubility of hydrocarbons in the CO2-rich phase increased with increasing pressure. Impurities in the injected CO2 did not significantly affect trends in composition, density, and viscosity of each phase. This work reports density, viscosity, component condensation and vaporization, and equilibrium constants for systems of CO2 and a West Texas crude oil at various reservoir conditions. Information from this work is required to tune models that simulate dynamic phase behavior in CO2 displacement tests, for both laboratory and field applications.

INTRODUCTION
The phase behavior of CO2/crude-oil systems has been investigated extensively since the 1960's.1–10 This interest was at its peak in the late 70's and early 80's, at the onset of many CO2 miscible flooding projects and higher oil prices. Interest continues as new projects come on stream and earlier projects mature.11 Studies to understanding the development,12–18 determination,19–23 and prediction24–30 of the MMP for both pure and impure CO2 injection have been ongoing for over thirty years. The objective of this work is to continue to examine how pressure and injection gas composition (pure and impure CO2) affect the dynamic phase behavior of CO2 injected into a recombined crude oil. This work complements earlier CO2 injection studies: one studying several different crude oils10 and another using a stock tank oil.4
A Amphoteric Copolymer Profile Modification Agent
Authors: HongGuan Wang , LianCheng Yu , HongKun Tian 
Published: December 2007

ABSTRACT
This report provides a new gel profile modification agent prepared by a amphoteric copolymer (FT—213) and a nevol crosslinking agent (BY), and introduces the preparations of the amphoteric polymer, the crosslinking agent and the profile modification agent, the action mechanism, the conditions testing and the evaluations of the performances of the agent. The 45 well treatments in oilfields demonstrate that the agent can be prepared convienously, the agent has better compatibility and application performances, and the treatment life by using the agent is longer. 80000 tons increamental oil and 60000 m* decreasing water production have been achieved.
Fluid-Rock Interactions Between Xanthan-Chromium(lll) Gel Systems and Dolomite Core Material
Authors: McCool C. S. , Green D. W. , Willhite G. P. 
Published: December 2007

ABSTRACT
Gelation of chromium(III)-xanthan systems in dolomite core material was investigated. Compositional changes in the gelant caused by interactions with the dolomite core material resulted in low permeability reductions for gelants prepared with chromium chloride, chromium acetate and a chromium diamine salt. The primary cause of incomplete gelation in the dolomite material was the increase in gelant pH that resulted in precipitation of chromium.
An Objective Rapid Screening Tool for Surfactants Used in Foam-Like Dispersions of CO2 into Permian Basin Brines
Authors: Horton R. L. , Wicks J. P. , Prieditis John , Turbeville J. B. 
Published: December 2007

Abstract
Foam-like dispersions of CO2 into brines can reduce the mobility of drive fluids in CO2 floods. To evaluate the effectiveness of such foam-like dispersions, time-consuming laboratory coreflood tests are routinely used. Because of the costliness of such coreflood tests, simple qualitative tests have long been employed to screen potential surfactants. Then only a few of the better candidates are subsequently evaluated in coreflood tests. There are a number of disadvantages of such qualitative tests; therefore we developed, instead, a quantitative screening process. Our quantitative process is based on two simple, quick laboratory tests and a neural network interpretation of the test data. The neural network predicted CO2 mobility reduction values which correlated well with the mobility reductions seen in coreflood tests.
Research and Application of Amphoteric Polymers for Drilling Fluid
Authors: Yabin Niu , Darning Zhang , Pingya Luo , Jian Li , Tongtai Xu 
Published: December 2007

Abstract
As the inhibition ability is not strong enough and the tolefance ability of solid contamination is low for usual polymer drilling fluid, the amphoteric polymer drilling fluid is suggested to solve above problems after analyzing and researching interactive mechanism and components of polymer drilling fluid as well as structure character of polymer molecule. The inherent character of amphoteric polymer molecule makes it not only to have strong inhibition but also to improve rheological property of drilling fluid. The application in 15 oilfields (nearly 4000 wells) in China demonstrates that the amphoteric polymer drilling fluid has strong inhibition, can retard "mud-making" of shale formation, keeps low-solid content and wellbore stable. The amphoteric polymer drilling fluid has excellent rheological property to make full use of jet-bit drilling and achieve significant effectiveness of increasing drilling rate. The obvious results in protection of oil formation have been achieved.
A Compositional Reservoir Simulator on Distributed Memory Parallel Computers
Authors: Ramé Marcelo , Delshad Mojdeh 
Published: December 2007

ABSTRACT
This paper presents the application of distributed memory parallel computers to field scale reservoir simulations using a parallel version of UTCHEM, The University of Texas Chemical Flooding Simulator. The model is a general purpose highly vectorized chemical compositional simulator that can simulate a wide range of displacement processes at both field and laboratory scales. The original simulator was modified to run on both distributed memory parallel machines (Intel iPSC/960 and Delta, Connection Machine 5, Kendall Square 1 and 2, and CRAY T3D) and a cluster of workstations.
A domain decomposition approach has been taken towards parallelization of the code. A portion of the discrete reservoir model is assigned to each processor by a set-up routine that attempts a data layout as even as possible from the load-balance standpoint. Each of these subdomains is extended so that data can be shared between adjacent processors for stencil computation. The added routines that make parallel execution possible are written in a modular fashion that makes the porting to new parallel platforms straight forward.
Results of the distributed memory computing performance of Parallel simulator are presented for field scale applications such as tracer flood and polymer flood. A comparison of the wall-clock times for same problems on a vector supercomputer is also presented.
Surface Network and Well Tubinghead Pressure Constraints in Compositional Simulation
Authors: Litvak M. L. , Darlow B. L. 
Published: December 2007

ABSTRACT
A new procedure for the determination of well production rates from surface pipeline network and well tubinghead pressure constraints is presented.
The well production rates are calculated using simultaneous modeling of multiphase fluid flow in the reservoir, well perforations, well tubing strings, and surface pipeline network system.
The procedure is implemented in an industrial compositional reservoir simulator. It is applicable for both black-oil and compositional reservoir simulations.
A Renormalisation-Based Upscaling Technique for WAG Floods in Heterogeneous Reservoirs
Authors: Christie M. A. , Mansfield Mark , King P. R. , Barker J. W. , Culverwell I. D. 
Published: December 2007

Abstract
A novel and rapid upscaling procedure is described in which: 1) pseudo-functions are generated for each block in a coarse grid; 2) a renormalisation method is used to calculate the pseudo-functions; 3) an empirical viscous fingering model is used to allow for fluid instabilities in unfavourable mobility ratio displacements. Oil recovery predictions are shown to agree well with conventional simulations made on the fine (geological model) grid for unstable, first-contact miscible WAG floods with a range of permeability distributions. In all cases, the result is an improvement (usually a substantial one) over a conventional coarse grid model in which only the absolute permeability of each block is upscaled.
Interactive Reservoir Simulation
Authors: Regtien J. M. M. , Por G. J. A. , van Stiphout M. T. , van der Vlugt F. F. 
Published: December 2007

ABSTRACT
Shell's new Modular Reservoir Simulator (MoReS) has been equipped with a comprehensive and versatile user interface called FrontEnd. Apart from providing a user-friendly environment for interactive reservoir simulation, FrontEnd serves as a software platform for other dynamic simulation and reservoir-engineering applications. It offers to all supported applications a common user interface, enables the re-use of code and reduces overall maintenance and support costs associated with the embedded applications. Because of its features, FrontEnd facilitates the transfer of research results in the form of operational software to end users.
When coupled with MoReS, FrontEnd can be used for pre- and postprocessing and interactive simulation. The pre-processing options allow data to be inputted by means of various OSF/Motif widgets containing a spreadsheet, text editors, dialogues and graphical input. The display of the input data as well as the post-processing of all simulation results is made possible by a variety of user-defined plots of tabular (e.g. timestep summary) and array (simulation grid) data. During a simulation user-defined plots can be displayed and edited, allowing a close inspection of the results as they are being calculated. FrontEnd has been equipped with a powerful input command language, which gives the batch user as much flexibility and control over the input as the interactive user.
Geological Characterization and 3D Visualizations of The Gas Storage Reservoir at Hillsboro Field, Montgomery County, IL
Authors: Udegbunam E. O. , Huff B. G. 
Published: December 2007

ABSTRACT
Geological characterizations, modeling and 3-D computer-generated visualizations of the Ordovician St. Peter Sandstone at the Hillsboro Gas Storage field in Montgomery County, Illinois, are discussed. Petrophysical analyses reveal four distinct hydraulic flow units in six cored wells. Furthermore, four lithologies, identified by thin section petrography, are associated with the various hydraulic units. Fieldwide visualizations of 3-D distributions of petrophysically-derived attributes – reservoir quality index (RQI) and flow zone indicator (FZI) – show considerable vertical variability but lateral continuity. This finding explains why it is easier to expand the gas bubble laterally than vertically. Advantages of the 3-D reservoir description of Hillsboro Gas Storage field include 1) improved definition of the spatial porosity distribution which leads to better estimation of reservoir volumetries; 2) improved definition of reservoir hydraulic flow zones; and 3) development of realistic reservoir model(s) for the simulation and management of the gas storage field.
A New Multi-Phase Flow Model for Horizontal, Inclined, and Vertical Pipes
Authors: Bilgesu H. I. , Ternyik Joseph 
Published: December 2007

ABSTRACT
Multiphase flow conditions occur in a wide range of engineering applications in the petroleum, chemical, and nuclear industries. The design of production systems involving different fluids requires an accurate prediction of the pressure loss. Existing methods rely on the prediction of flow patterns based on observed field and experimental data. However the patterns are not applicable to all conditions and the predicted pressure drops deviate from actual observations.
This paper describes the new model developed to predict pressure drop for vertical, inclined, and horizontal pipes and wellbores. The model is composed of fluid property correlation, flow pattern prediction, and pressure drop determinations.
The model performance is evaluated using published data, The model predictions are also compared with a commercially available model. The overall performance of the model is in good agreement with data. In comparison with the published data, the model predictions resulted in the least average error.
Spatial Delineation of Natural Fractures and Relation to Gas Production
Authors: Caramanica F. P. , Hill D. G. 
Published: December 2007

ABSTRACT
In a Gas Research Institute sponsored study, enhanced formation image analysis was performed on twelve wells in the Antrim Shale, Michigan Basin. The analysis revealed that the abundance of open and partially open fractures as well as their degree of interconnection are controlling factors in gas production. Borehole maps show the interconnection with reference to the borehole.
A fracture factor (Zf) was derived and plotted against gas flow rates for nine wells. Six wells treated with a singlestage stimulation show a linear relationship between (Zf) and Q. Two were stimulated with a two-stage treatment and produced more gas than single-stage wells with comparable values of Zf. The methods of fracture analysis derived for the Antrim Shale should have immediate practical application to other unconventional and tight reservoir rocks.
Using a Mixed Integer Linear Programming Technique to Optimize a Fracture Treatment Design
Authors: Rueda J. I. , Rahim Zillur , Hoiditch S. A. 
Published: December 2007

Abstract
IN1RODUCTION
Well stimulation procedures are designed to reduce the restrictions to flow from the reservoir into the wellbore and increase productivity.1 Hydraulic fracturing in low permeability reservoirs is an important and successful stimulation methodology widely used by the petroleum industry.
The design of the optimum fracture treatment has three basic steps. The first step involves calculating fracture dimensions and conductivity for various fracture fluid pumping schedules. The second step is determining the oil and gas production rates and recoveries using the values of propped fracture length obtained from the fracture treatment design. The third step requires one to determine the optimum fracture treatment design by maximizing the economic benefit of the treatment. Since a fracture treatment design involves selection of fracturing fluids, additives, proppant materials, injection rate, pump schedule, and fracture dimensions, the determination of the optimum combination of all variables can be quite complicated. In this research, we have developed two methods to investigate reasonable combinations of design and treatment parameters to determine the most profitable fracture treatment design. Depending upon the post-fracture treatment production rates, the related expenses, and the economic constraints, the optimum treatment can be easily determined.
The first optimization method is based on a mathematical technique called Mixed Integer Linear Programming (MILP).2 This method can be used to minimize or maximize a desired objective function subject to certain constraints. For this work, we have chosen the objective function to be the discounted net present value due to a fracture treatment. The constraints are related to the fracture dimensions and other items necessary to linearize the fracture design problem.3
Adsorption of Pure Methane, Nitrogen, and Carbon Dioxide and Their Binary Mixtures on Wet Fruitland Coal
Authors: Hall F. E. , Zhou Chunhe , Gasem K. A. M. , Robinson R. L. , Yee Dan 
Published: December 2007

ABSTRACT
A detailed experimental study has been made of the adsorption of methane, nitrtheir binary mixtures, on a wet Fruitland coal at 115°F. Mixture measurements were typically made at nominal gas-phase compositions of 20, 40, 60, and 80 mole percent and pressures to approximately 1,800 psia. These data elucidate clearly the competitive adsorption behavior of the individual components in these mixtures.
The experimental information was used to test predictive methods for describing the adsorption behavior of the pure and mixed gases. Models included various two-dimensional equations of state, as well as more traditional methods, such as the Langmuir and loading ratio correlations and the ideal adsorbed solution (IAS) model. The relative merits of the various models are described. In general, all models perform well for pure-gas adsorption; however, results are less satisfactory for mixtures. The errors in mixture predictions increase as the individual components become more dissimilar in their adsorption behaviors. Greatest (percentage) errors occur for the less-adsorbed component and, in the worst case (nitrogen + carbon dioxide), the predictions for nitrogen show errors of more than 100% at some conditions. Overall, the two-dimensional equation-of-state and IAS models perform comparably, and they are more accurate than the Langmuir model.
The data and modeling results should be of interest in coalbed methane production and, especially, in evaluating potential enhanced recovery operations based on nitrogen and/or carbon dioxide injection into coalbeds.