bluuebunny/crossref_metadata_2025_split huggingface dataset:
Improved Model for Predicting Multiple Hydraulic Fracture Propagation from a Horizontal Well
Authors: Siriwardane H. J. , Layne A. W. 
Published: December 2007

ABSTRACT
The goal of this research effort was to develop and evaluate the applicability of a simplified multicrack, hydraulic fracture model for predicting multiple fracture propagation during stimulation of a horizontal wellbore in a naturally fracture formation. This model is based on the assumption that individual fracture propagation is governed by the theory presented by Geerstma and DeKlerk2 for single vertical fractures of a constant height. In this model, the fluid flow in the wellbore is coupled with the flow in, and propagation of, multiple fractures. The fluid volumetric flow rates and pressure compatibility is maintained between the wellbore and the fracture network with a systematic iterative, numerical scheme. Prior to analysis of available field data, the model was evaluated by predicting how variations of hydraulic fracture treatment parameters Influence the propagation of a multiple fracture system. Based on these evaluations, it was concluded that both turbulent and laminar conditions of flow exist in different segments of the wellbore. It was also concluded that fracture inclination to the well-bore and entry losses into the natural fractures from the wellbore have a significant influence on the propagation of a multiple fracture system. Following this initial evaluation, data gathered from a recently completed horizontal wellbore field test were then used to evaluate the predictive capability of the multicrack hydraulic fracture model. In this field test, radioactive-tracer with spectral gamma ray logging was used to determine the locations of fractures accepting fluids and the volumes of fluids entering natural fractures. The predicted and log-derived fluid flow rates into each natural fracture were in good agreement. To date, the model has been modified to predict hydraulic fracture propagation with proppant laden fluids. Predictions from this enhanced model are being compared against available field data to evaluate the modified multicrack model. As more field data are gathered, and the multiple fracture model is modified and improved, additional comparisons can be made. The multicrack model provides further insight into the factors that govern multiple fracture propagation in horizontal wells.
Determinants Of The Potential Supply Of Natural Gas
Authors: Beebe B.W. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the Regional Gas Technology Symposium of the Society of Petroleum Engineers of AIME, to be held in Omaha, Neb., Sept. 12–13, 1968. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
A number of predictions of need for a substantial increase in the supply of natural gas by 1980 inevitably lead to consideration of the basic determinants of available future supply. The Potential Gas Committee considers broad economic and technologic determinants in its definition of potential supply. Its estimate is based on a fair but reasonable price and normal improvements in technology. The ability of natural gas to compete with other forms of energy at the market place is therefore one of the ultimate determinants of the potential supply of natural gas. Another is the producers' willingness to enter into the producers' willingness to enter into the hazardous search for and development of sufficient gas supply at prevailing costs and wellhead prices. Hence the estimate is elastic and subject to revision as determinants change. Other factors, although exerting influence on the potential supply, are more important potential supply, are more important in determining rate at which new supply is made available.
According to the Potential Gas Committee's estimates, the potential supply of natural gas should not cause concern from 1968–80. The Committee makes no predictions in regard to the rate at which the potential supply will be developed and produced, perhaps the most important factor. The annual average rate of additions to new supply has been only 19.7 Tcf for the past 12 years. There seems to be no compelling reason for its increase. An increase to an average of at least 23 Tcf per year is necessary simply to supply forecasted need for at least 300 Tcf during the period. And this quantity only meets increasing requirements. If a reserve life index of 15 years is to be maintained, the rate must be considerably higher.
Slick Trajectory Predictions for the Arabian Sea
Authors: Kurup P. G. 
Published: December 2007

ABSTRACT
The environmental damage caused by slicks at sea and the subsequentdeposition of tar on shores is wellknown. Contingent planning forsuccessful deployment of men and material for slick combatment programmes requires knowledgeof calculated positions of the slick at anyinstant oftime after the spill has occurred. The paper presents slick drift vectors for the Arabian Sea for every 2° lat. x 2° long, grids, calculated from monthly wind andcurrent data obtainedfrom the KNMIAtlas. Monthly charts have been produced to givethe resultant drift trajectories of slicks from 61 hypothetical spills occurring in the vicinity of the shores of the Arabian Sea on thefirst day of every month. The location of possible slick deposition on the shore and the duration available for weathering have been predicted. Of 732 hypothetical spills studied, 135 may pollute the Indian coast with varying intensity.The period May-September provides more chances of severe oil deposition on the west coast of India while the period October-February may be critical for the western shoresof the Arabian Sea. The drift velocities have highest magnitudes during July. Slicks from the farthermost spill considered (370 kmoffshore) takes only 14 days to reach the Indian shore during July. Spills occurringduring December in the western Arabian Sea will affect the shores of Africa and Arabia severely.
Occupational Stress and Accidents Offshore
Authors: Sutherland V. J. 
Published: December 2007

Abstract
Stress, personality and accident involvement were assessed in one-year study of offshore personnel. Results indicate response to stress relates to occupational status, installation type, location and size. Accident involvement has an adverse impact on the longterm wellbeing of the individual. Personality mediates in the stress-accident process. Certain styles of behaviour are associated with increased accident involvement and poor wellbeing. It is recommended that more attention is paid to human-factors assessment offshore.
Review of the Geological Environment for Horizontal Wells
Authors: West C. C. , Bodnar D. H. 
Published: December 2007

ABSTRACT
The geological aspects of drilling horizontal wells in various geologic environments worldwide are reviewed. Predominantly development wells, they are often drilled in locations where a conventional well would not achieve the same geological and subsequently economic, objectives. This paper summarizes recent activity and demonstrates that geologic conditions play a large part in determining the success or failure of a horizontal drilling project. The examples cited in this paper are all taken from previously published literature and include horizontal drilling projects in the USA, United Kingdom, Norway, Italy, The Netherlands and Denmark.
This paper concludes that a large range of geological conditions have been tested by horizontal drilling with varying degrees of success, the results of which might prove helpful in assessing future prospects for horizontal wells.
Dynamic Etching Tests And Their Use In Planning Acid Treatments
Authors: Broaddus G.C. , Knox J.A. , Fredrickson S.E. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for Oklahoma Regional Meeting of the Society of Petroleum Engineers of AIME, to be held in Stillwater, Okla., Oct. 25, 1968. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made. provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
The satisfactory stimulation of oil and gas producing wells by "Fracture Acidizing" is dependent upon development of adequate flow capacity in naturally occurring or induced fractures of sufficient areal extent.
The flow capacity is either obtained or improved through the action of the acid on the exposed fracture faces. The type and quantity of acid used in a treatment greatly influences the pattern and degree of etching. Consequently, the type of etch affects the fracture flow capacity.
Dynamic acid etching tests can be used to determine the feasibility of an acid treatment, and the type acid and the contact time necessary to produce a conductive fracture. produce a conductive fracture

Introduction
The first wells stimulated with hydrochloric acid were treated by dumping small quantities of acid down the well. These treatments were interstitial and improved the natural permeability near the well bore only. Later, when acid inhibitors were developed and pumping equipment was improved, acid was pumping equipment was improved, acid was injected at higher rates and pressures, and consequently larger volumes were used. At this time, acid reaction time, fluid efficiency and pump rate were used in designing acid stimulation treatments. For years, these factors were used, and are still being used, to calculate the surface area of created fractures. It was assumed that a conductive fracture would be created by hydrochloric acid in limestone and dolomite formations. Of course, this is not always true.
Fracture Identification and Quantification Using Borehole Images: Maracaibo Basin, Venezuela
Authors: Lambertini R. 
Published: December 2007

Abstract
Borehole images obtained with the Formation MicrScanner Tool (FMS) have added a new dimension to reservoir description and characterization. As confidence in fracture detection and analysis grows in the petroleum industry, more emphasis is been placed on the modeling of fracture distribution within the reservoir.
The FMS logs that have been run in several wells in the Maracaibo Basin (Tretiary and Cretaceous Formations) have been used with cores, open hole logs and conventional dipmeter in an integrated approach to reservoir description.
To assist in the interpretation and quantification of fractures, especialized image analysis have been developed. Borehole imagery records fracture orientation and allows natural or induced fractures to be distinguished. Quantitative analysis of fracture revealed with the FMS images has been greatly advenced with the development of the FRACVIEW software.
During FRACVIEW analysis, different kinds of fractures are grouped into statistical or geological sets using the Image Examiner Workstation (FLIP) according to fracture density, lenght, width and porosity.
Such information is proving to be a valuable guide to the positioning, testing and completion of new wells.
Conduction Calorimetry Technique in Cement Hydration for Oil Wells
Authors: Santos F. P. , Campos W. 
Published: December 2007

Abstract
Conduction calorimetry technique makes possible to follow the kinetic of cement hydration through the rate of heat evolution. This work presents experimental results using the following types of cement: oilwell Class G, Class A, Pozzolanic and Blast Furnace. The effects of cement aeration (carbonating and/or humidifying), temperature and use of additives on the hydration rate of Class G cement slurries were analysed. In addition, the characterization of the different cement types was performed. The tests were run in a JAF Conduction Calorimeter which working principles were described in the work. A computer program was developed to calculate the heat liberation rate and the cumulative heat of hydration generated along the process.
A New Method to Estimate Compressibility Factors for CO2 Hydrocarbon Mixtures
Authors: Rojas G. , Requena O. 
Published: December 2007

Abstract
This work shows experimental values of compressibility factors for CO2 – hydrocarbon mixtures in different proportions. The measurements were done in a Ruska supercompressibility cell varying the pressure (200 – 2500 psia), the temperature (100 – 200°F) and the molar percentage of CO2 (85 – 100%). With the experimental data, generalized Z (CO2 – Hydrocarbons) were plotted as a function of Psr (pseudo reduced pressure) and Tsr (pseudo reduced temperature).
The equation state of Peng-Robinson (EOS-PR), Starling (EOS-S) and Redlich - Kwong - Soave (EOS-RKS) were tested to simulate the experimental data, and it was found that the EOS-S and EOS-PR are the ones that predict the mixtures compressibility factors studied with greater precision.
Resistance of Module Structures to Blast and Fire Loading
Authors: Snell R. O. , Corr R. B. 
Published: December 2007

Abstract
During the course of a blast incident a module structure and plant will be required to withstand blast overpressure, drag loading, and possibly projectile impact. A fire may subsequently occur adding load to a potentially blast damaged structure.
In response to the Cullen Enquiry into the Piper Alpha incident in the North sea the authors developed a structural design philosophy for application to new designs and the assessment of existing platforms. Although primarily developed for offshore structures it is also applicable to onshore plant.
This paper outlines a design philosophy for blast overpressure, drag and fire loading. Potential projectile impact energy design criteria and the results of some impact tests on typical materials are described.
Layered Reservoir Evaluation Using Pressure and Flow Rate Transient Analysis
Authors: Cabrera J. , Silva R. , Ramones M. , Mendoza L. , Prat G. Da 
Published: December 2007

Abstract
In this work mathematical concepts and fundamentals of a model for well testing evaluation of layered reservoirs are presented. The model, based on that developed by Eligh-Economides et al1 considers the production to the well as coming from several layers. These layers may be different, regarding lithology and fluid properties. The solutions allow the calculation of the flowing pressure, average pressure, skin and flow rate for each individual layer. This is important for pressure transient analysis since the conventional methods only provide the global pressure for all the layers. Crossflow is included in the model. The solutions with model proposed are compared with those given by a numerical simulator in order to check the validity and are in excellent agreement with the numerical simulator. Several field examples are presented to show model applications.
Individual layer evaluation can be obtained when testing a well completed in several layers by the model presented. Also, production decline monitoring is possible for each layer.
An Efficient Finite Volume Approach for Modelling Miscible Displacement
Authors: Santos R. L. A. , Pedrosa O. A. , Correa A. C. F. 
Published: December 2007

ABSTRACT
Miscible displacement in two-dimensional reservoirs is simulated using a finite-volume approach that includes a nine-point discretization scheme based on the flux interpolation technique. The approach also incorporates a locally one-dimensional exponential scheme to discretize the convection-diffusion terms. The numerical results showed the effectiveness of the proposed technique in reducing numerical dispersion and grid orientation effect for adverse mobility ratios.
Automatic Fitting of Equations of State for Phase Behavior Matching
Authors: da Silva M. B. , Rodríguez F. 
Published: December 2007

ABSTRACT
Phase behavior modeling of a reservoir hydrocarbon mixture through an equation-of-state, EOS, is preceded by the adjustment of some of the parameters in the equation so as to reproduce measured PVT data of the mixture. In this paper we propose a methodology for the automatic fitting of EOS parameters for phase behavior matching.
Critical properties of the heaviest, C+, fraction are obtained from available correlations and fitting of EOS parameters, Ωa0 and Ωb0, for CH4 and C+ as well as of the binary interaction coefficient, δCH4−C+, are performed according to the following procedure: First, keeping the theoretical values of Ωa0 and Ωb0, we calculate the interaction coefficient δCH4−C+ that matches the saturation pressure of the mixture. In a second step, the parameters Ωa0 and Ωb0 for the CH4 and C+ fractions are fitted through a non-linear least squares regression technique to match PVT experimental data in the one-phase region. Peculiarities of the system of equations produced by the fitting algorithm are discussed; proper solution techniques are discussed as well.
The above procedure was used to adjust the Peng-Robinson EOS to four reservoir hydrocarbon fluid samples, which include gas condensate. Phase behavior in the two-phase region predicted with the EOS was verified to match PVT laboratory data obtained under flash and differential liberation processes. It was verified that the interaction coefficient, δCH4−C+ is the relevant parameter for saturation pressure matching. Analysis of regressed parameters indicate, in all four applications, that relevant parameters in the non-linear regression fitting are Ωa0 and Ωb0 of the CH4, fraction.
In Situ Combustion with Metallic Additives
Authors: Castanier L. M. , Baena C. J. , Holt R. J. , Brigham W. E. , Tavares C. 
Published: December 2007

Abstract
In-situ combustion is the most energy efficient of the thermal recovery methods. In light oil reservoirs, too little fuel may be deposited thus making combustion impossible while in heavy oil reservoirs too much fuel may be deposited thus ruining the economics of the process. A research program has been initiated to try to solve these problems. Water soluble metallic additives were tested to attempt to modify the fuel deposition reactions.
In a previous paper1, results were reported from kinetics experiments run on Huntington Beach, California and Hamaca, Venezuela crude oils in the presence of aqueous solutions of metallic salts. While the presence of copper, nickel and cadmium had little or no effect; iron, tin, zinc and aluminium increased fuel laydown for Huntington Beach oil. The results were similar for the heavier Hamaca oil.
This paper describes thirteen combustion tube runs using four different crudes. In addition to the above two crude oils, a 12° API and a 34° API Californian oil were tested. The metallic additives iron, tin and zinc improved the combustion efficiency in all cases. Fluctuations in the produced gases were observed in all control runs but disappeared with the iron and tin additives. The front velocities were increased by the metallic additives. Changes were also observed in H/C ratio of the fuel, heat of combustion, air requirements and density of the crude produced. The amount of fuel deposited varied between the oils. For Huntington Beach oil, the amount of fuel increased in the order: zinc, control, tin and iron while for the Hamaca crude the order was: control, iron and tin. The most interesting result occured with the light California oil. The control run showed that we were unable to propagate a combustion front while with iron additive a good combustion was achieved.
To date we have not been able to find a suitable additive to reduce fuel deposition. Iron and tin salts seem suitable agents to increase fuel when that is needed.
Steam Foam Studies in the Presence of Residual Oil
Authors: Hutchinson D. A. , Demiral B. D. M. , Castanier L. 
Published: December 2007

Abstract
This paper reports ongoing work at Stanford University aiming at better understanding of steam-foam flow behavior with oil present. Steam foam systems were studied in a one dimensional sandpack at residual oil saturation (about 12 %). The strength of the in-situ generated foam, indicated by pressure gradients, is significantly affected by injection procedure, slug size, steam quality and non condensible gas (nitrogen). In the range studied, surfactant concentration has a minor effect.
In the presence of residual oil, simultaneous injection of steam and surfactant fails to generate foam in the model, while the same procedure generates a strong foam without oil. When surfactant is injected as a liquid slug ahead of the steam, foam is generated, albeit at a lower strength than when no oil is present. The minimum slug size required to generate foam by this procedure is about 5 % of the pore volume at 1.0 % weight concentration. Above this minimum, increases in slug size or in concentration had little effect. The quality of the steam when it is increased, improves the foam strength. One implication of these results is that savings in the amount of surfactant needed for a steam-foam project may be possible by using a large slug of dilute solution. That is, if the slug volume is above some minimum, a dilute concentration may give acceptable foam generation. The reverse procedure, a small slug of high concentration surfactant gives poor foam generation and should probably be avoided in the field. Steam quality effects are consistent with the existing literature.
Steam Distillation and Oil Quality Change During Thermal Oil Recovery
Authors: Lim K. T. , Ramey H. J. , Brigham W. E. 
Published: December 2007

Abstract
A general method has been developed to compute steam distillation yield and to quantify oil quality changes during steam injection. It was found that steam distillation data from the literature can be correlated with the steam distillation yield obtained from the DOE crude oil assays. The common basis for comparison was the equivalent normal boiling point. Blending of distilled components with the initial oil results in API gravity changes similar to those observed in several laboratory and field operations.
A Stochastic Role for Engineering Input to Reservoir History Matching
Authors: Watkins A. J. , Parish R. G. , Modine A. D. 
Published: December 2007

Abstract
This paper is concerned with the role of engineering input to, and interaction with, algorithms used in reservoir history matching. The underlying iterative cycle common to all techniques allows considerable scope for such input; however, for maximum benefit to result, it is important that the information accurately reflects engineering experience, and can be suitably quantified for use in algorithms.
The discussion is illustrated with some salient points of examples based on one technique which uses a stochastic framework to accommodate explicitly the uncertainty in such essentially deterministic problems.