bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Study of the Post-Breakthrough Characteristics of Waterfloods
Authors: Lo K. K. , Warner H. R. , Johnson J. B. 
Published: December 2007

Abstract
This paper presents results that theoretically and numerically support the log(WOR) vs cumulative oil plot for waterflood analysis. This plotting technique has traditionally been used to estimate the ultimate oil recovery from waterflooding; the results derived in this paper give other practical uses for this plot such as evaluating the efficiency of current waterflooding operations, estimating the original oil in place (OOIP), or determining the in situ water-oil relative permeability characteristics of the reservoir. The study results, primarily utilizing the dependence of the slope of the log(WOR) vs cumulative oil plot on various reservoir parameters, are based on the one-dimensional Buckley-Leverett theory after water breakthrough and multi-dimensional numerical simulations. Also the effect on this slope caused by different reservoir layering, flood configurations, and operational changes are presented. This approach has been applied to estimate the original oil in place for two actual waterfloods and a comparison of these OOIP values is made to those calculated by volumetric methods.
A Laboratory Screening Method for a Pilot Caustic Steamflood
Authors: Okoye C. U. , Hayatdavoudi A. , Ping-Hu W. , Oungpasuk P. , Yousef M. 
Published: December 2007

Abstract
This paper presents the screening tests conducted to determine the feasibility of caustic steamflood at Schewing formation in Bayou Bleu Field Louisiana. The evaluation process and methods include a broad range of laboratory tests which can be applicable for screening any field trial of chemical steamflood or ordinary steamflood. The minerology, and rock properties such as porosity and permeability were determined by core analysis. The mineralogy test consists of petrographic study of thin sections, scanning electron microspy, EDAX and x-ray diffraction of formation rock samples before and after treatment with varying concentrations of caustic solutions. The reservoir fluid analysis involved the determination of oil: gravity, density and viscosity at varying temperatures and caustic concentrations. Also the PVT parameters and the acid number of the oil. were determined.
The criteria used for screening various concentrations of caustic solution for high temperature application include: the effect of temperature on caustic-oil and caustic-rock interaction, the reaction kinetics of caustic-oil and caustic-rock, caustic-oil relative permeabilities, caustic-oil interfacial tension and oil recovery performance. The most favorable designed caustic steamflood recovered 15% more of initial oil-in-place than the conventional steamflood.
Estimates of field performance ranged from 10% to 25 of more additional oil recovery by caustic steamflood than by conventional steamflood. Based on these screening test a field trial of cyclic caustic steam injection was carried out as a prelude to a proposed 5-spot caustic steamflood pilot project.
A New Method for Stabilizing Fines and Controlling Dissolution During Sandstone Acidizing
Authors: Kalfayan L. J. , Watkins D. R. 
Published: December 2007

ABSTRACT
A new fines stabilizing method which prevents migration of clay and non-clay siliceous fines, and controls formation dissolution during sandstone acidizing, has been developed.
The method employs an organosilane compound which can be added directly to acid mixtures, such as hydrochloric (HC1) and hydrochloric-hydrofluoric (HC1-HF) acid. The organosilane additive reacts in situ to stabilize potentially mobile siliceous fines, and as an additive to HC1-HF acid mixtures, reduces the potentially damaging effects of excessive mineral dissolution by HF.
This paper describes the use of and the mechanism by which the organosilane acid additive stabilizes fines, and reduces dissolution of sandstone by HF acid.
Results of laboratory core flow tests which show the beneficial effects of employing both a proper HF acid concentration and the organosilane fines-fixing agent are presented. Results of a field test are also presented.
The Evaluation of Temperature Logging in Thermal Application
Authors: Fialka B. N. , Pyszka M. H. , Chhina H. S. 
Published: December 2007

ABSTRACT
When evaluating the technical success of thermal operations, one of the most important factors to be determined is how efficiently the heat is distributed within the reservoir. Temperature logging is the standard diagnostic technique for monitoring the vertical heat distribution in the near wellbore region of a well subjected to thermal operations. This paper deals specifically with the use of the log-inject-log temperature logging procedure in a cyclic steam application. In particular, the limitations of the procedure and the value of the information obtained is established using field examples from an experimental cyclic steam pilot project in the Cold Lake region of Alberta, Canada.
Presently, there are conflicting opinions regarding the suitability of various operating procedures for thermal logging and the analysis of the data. This uncertainty was addressed by mathematically modelling certain aspects of the log-inject-log temperature logging procedure. Numerous factors were found to influence the measured wellbore temperature: the treatment of the wellbore prior to logging, the accuracy of the logging tool, influx of reservoir fluids into the wellbore and the bottomhole pressure. The effect of each of these factors on the temperature logs taken was investigated which contributed to the development of a recommended temperature logging procedure.
X-Ray Scanning in Petroleum Engineering Laboratory Research
Authors: Castanier L. M. , Pettit P. A. 
Published: December 2007

Abstract
This paper summarizes applications of Computerized Axial Tomography to a variety of experimental problems in reservoir engineering and Enhanced Oil Recovery research.
Stanford University acquired a used medical Cat scanner in 1987. The system has been modified for determination of heterogeneities and measurement of In-Situ saturations in multiphase flow experiments. The poster presentation will include a description of the equipment, a poster presentation will include a description of the equipment, a discussion of the various types of softwares used for interpretation and display of the results and several examples of applications. Among those emphasis will be placed on the following:
- Verification of homogeneity in sandpacks – Foam flow (Determination of liquid and gas saturations in two phase systems) – Three dimensional steam injection model – Studies of flow through fractured media – relative permeability studies
Discussions of our answers to specific problems as well as example pictures of scans of cores and fluids will be presented. Cat Scanning is now used as a powerful tool to complement existing laboratory measurement, it can be used in a broad range of experiments including high pressure and high temperature thermal recovery corefloods.
A Method for the Determination of Relative Permeability Ratios Using Visual Columns
Authors: Alcocer C. F. 
Published: December 2007

Abstract
A laboratory research was conducted to generate an analytical method to determine relative permeability ratios from experimental data obtained during immiscible displacements of hydrocarbons in unconsolidated reservoir using visual cylindrical model. This paper presents: a) the design, construction and uses of visual columns of immiscible displacements; b) the mathematical description and application of a new technique to generate relative permeability ratios as a function of the permeability ratios as a function of the displacement fluid saturation; and c) a study of the advance of the displacement front. The displacement of the front is an Irregular 3-D surface that was treated as 2-D problem by using intersections of the front problem by using intersections of the front surface with the boundary of the visual cylindrical model. This treatment of the data allowed us to formulate empirical equations for wall-effects in laboratory reservoir models and develop a method to determine relative permeability rating. Twelve flooding tests were run in the laboratory using water as displacing fluid and hydrocarbon displaced fluid. The rate of displacement varied from 0.345 cc/sec. to 9.77 cc/sec. Reservoir models were made of resistant transparent plastic columns with 100 cm length, 9 cm internal diameter and 0.5 cm thickness. The porous media was unconsolidated 140-200 mesh sand pack with 33.9% and porosity and permeability of 945 ml the first column and 34.96% porosity and 835 ml of permeability the second one.
The main and secondary objectives of this research were accomplished. The analytical method generated similar relative permeability ratio curves to those produced permeability ratio curves to those produced by conventional multi-phase flow tests in the laboratory. This new method proved very useful to save time during enhanced oil recovery tests in the laboratory there relative permeability ratios are needed data. The efficiency of the water flooding displacements and results of wall-effect equations generated in this work are in reasonable agreement with previous investigators.
P. 601
A Unique Method for Installing Slimline Fiberglass Liners in a CO2 Miscible Flood
Authors: Lacy R. D. , Talley C. L. 
Published: December 2007

ABSTRACT
A major obstacle to the successful implementation of an enhanced oil recovery project is the proper completion of the injection wells to prevent fluid loss. The injectants are often expensive and highly corrosive. Further, economics dictate in many cases that the wells to be completed and used as the input wells for the injectant be existing wells; the economics simply do not allow for the drilling of new injection wells. These wells were originally designed without this purpose in mind and are very often old, at least thirty years. Most of these wells suffer from poor casing integrity and small casing sizes. Again, economics do not allow for the use of corrosion resistant high nickel chrome alloy liners.
To solve these problems, a unique completion method was designed using fiberglass casing and a drillable permanent packer as the liner hanger. The permanent packer was also used as the injection packer. This system allows the use of corrosion resistant fiberglass for control of the corrosive injection fluids and imparts the ability to drill out the permanent packer and the fiberglass liner to prevent the loss of the well bore in the future, if mechanical problems do arise.
This paper will describe in detail the development of the injection system, and the remedial procedures required. Case histories from an operator in southeastern New Mexico will demonstrate the successful recompletion of existing well bores into injection wells, supported by injection profite data that demonstrates injected fluid control. Economics demonstrating cost effectiveness of the unique completion design are also presented.
Well Performance Visualization and Analysis
Authors: McCoy J. N. , Podio A. L. 
Published: December 2007

Abstract
A system has been developed based on a powerful portable microcomputer and an integrated data acquisition instrumentation package which allows real-time visualization of pumping well performance.The system integrates all the necessary elements to obtain a complete analysis of the performance of the pumping system which includes the pumping unit (beam or submersible), the wellbore, and the reservoir.
The data acquisition package consists of the necessary analog and digital input channels to process data from standard transducers such as pressure, temperature, rod load, displacement, etc. so that detailed surface unit performance curves such as dynamometer, speed, acceleration, power etc. can be obtained and analyzed. When the instrument is used in conjunction with an acoustic pulse generator and receiver, it digitizes and records the reflected acoustic signals which are digitally filtered and automatically processed to determine the liquid level. This is undertaken under program control so that a recording of fluid level vs, time is obtained concurrently with the pumping performance parameters. Fluid level data is processed by the software to calculate bottom-hole pressure as well as flow into and out of the well bore. Changing the well from flowing to shut in conditions allows recording of pressure buildup data which is then interpreted in terms of reservoir parameters. Alternatively, pump start-up after shutting in the well in for stabilization, provides draw-down testing capability. The analog/digital electronics system contains outputs of a 12 volts relay driver and also normally open/closed contacts for external control of gas-gun valves, motors, variable speed drives, casing vent valves, etc. These outputs are computer controlled and can be actuated depending upon input data, operator keyboard entry and/or time.
Graphic display of the various diagnostic parameters allows complete visualization of the performance of the whole pumping system including the reservoir, wellbore and pumping unit. The system can be used as a diagnostic tool to optimize pumping well performance on a periodic basis. The present performance of the well is compared to the performance recorded previously and in the case where significant changes are noted a more detailed analysis is undertaken. In critical well applications, the system can function as a stand-alone dedicated controller.
High Fracture Conductivity Yields Attractive Results
Authors: Kolb R. J. 
Published: December 2007

ABSTRACT
Field tests suggest propped hydraulic fractures designed with high fracture conductivities are cost effective treatments with attractive economic results. With careful consideration to detail, accurate predictions of production response to fracture treatments can also be made. Treatments performed on the Grayburg-San Andres formation in the McElroy Field near Crane, Texas have been evaluated to demonstrate these points.
Inverse VSP—A New Technology for Imaging and Monitoring Reservoirs
Authors: Hardage Bob A. 
Published: December 2007

Abstract
During the past decade, the oil and gas industry has recorded a large number of vertical seismic profiles (VSPs) in order to acquire improved structural, stratigraphic and seismic calibration information in the immediate vicinity of selected study wells. As is the progressive nature of the technology that the oil/gas industry uses in its exploration and development efforts, those companies who actively use VSP data are continually striving to find techniques whereby an increased volume of VSP data can be recorded in a study well at minimal additional cost. The inverse VSP concept has been developed to satisfy this objective.
Significant progress is currently being made in inverse VSP technology, so it is essential that a description of the equipment, field procedures and potential applications involved in this new type of borehole seismic measurement be available to the industry. This documentation is particularly important for those people who are responsible for evaluating reservoirs for purposes of calculating reserves in place, compiling data for unitization arbitration, or planning secondary recovery processes. Hopefully this paper will be a step in helping to disseminate this information throughout the industry.
In forward VSP, a geophone is positioned at various depths in a well in order to record the transmitted and reflected wavefields created by a seismic energy source located on the surface of the earth. In inverse VSP, the spatial positions of the source and receiver are reversed, with the source being manipulated at various depths in a well and the receiver(s) located on the surface of the earth. In concept, the raypaths between source and receivers, and consequently the travel times, are identical in these two recording geometries, as shown in Figure 1. In addition, the subsurface coordinates of the reflection points created by either measurement method coincide if the radiation patterns created by the surface and borehole sources are reasonably equivalent.
The Fluid Flow Simulation Equations
Authors: Breitenbach E.A. , Thurnau D.H. , van Poolen H.K. 
Published: December 2007

American Institute of Mining, Metallurgical and Petroleum Engineers Inc.

Abstract
A fundamental flow equation can be derived for each of the oil, water, and gas phases by combining the law of conservation of mass, a law of force, and thermodynamic relationships that describe the pressure-volume-temperature behavior of the fluids. The law of conservation of mass states that the sum of mass flow into a cell equals the change of mass within a cell. The law of force describing flow through porousmedia is Darcy's law, which assumes that flow is within the laminar flow regime described by the law. The thermodynamic relationships used to describe the fluid behavior must (because of the lack of accurate analytical expressions) be those found experimentally in a "PVT" study. The first part of this report shows how these laws can be combined to give equations describing fluid flow through porous media.
The next step in the development is the cabining of these equations with auxiliary equations so that the number of dependent variables is reduced. The result is an equation that can be assumed to be in terms of oil pressure only, so that it may be solved implicitly pressure only, so that it may be solved implicitly for pressures at the new time level. Separate from this pressure equation are the equations that are solved explicitly for saturations, using the newly computed pressures. Hence, there are three equations developed in final, finite difference form in this paper. 1) a pressure equation, 2) an oil saturation equation, pressure equation, 2) an oil saturation equation, and 3) a water saturation equation.
The logic used in the computation of all pertinent terms is given in the final section pertinent terms is given in the final section of this report.

Introduction
The general aspects of numerical fluid flow simulation has been given elsewhere (1). The present paper gives the derivation of the fluid present paper gives the derivation of the fluid flow simulation equations. The numerical solution of these equations is given in (2).

FUNDAMENTAL FLOW EQUATIONS
Fig. 1 shows a differential element of porous media. Pounds of oil (w o) are flowing porous media. Pounds of oil (w o) are flowing into or out of two faces, with a well (w op)in the center of the elements.
Weight rates of flow, rather than mass rates, are used here to simplify the final algebra; of course, this necessitates the assumption of constant acceleration of gravity. The rate of depletion (ROD) of oil from this element can then be defined as:
..........................................(1)
where ROD is the rate of oil removal from the element in lb/day at reservoir conditions.
Steam-Foam Pilot Project at Dome-Tumbador, Midway Sunset Field: Part 2
Authors: Mohammadi S. S. , Tenzer J. R. 
Published: December 2007

ABSTRACT
A steam-foam pilot project was conducted in the Dome-Tumbador leases, Midway Sunset field. The pilot consisted of four inverted five-spot patterns with a confined producer covering 5.2 acres [2.1 ha]. The injection phase lasted 3.7 years. During this period, steam-foam was generated by continuous injection of steam with NaCl, alpha olefin sodium sulfonate (AOS) and nitrogen. Incremental oil due to foam was 6.0% 00IP. The AOS use was approximately 5.3 lbs [2.4 kg] active matter per barrel of incremental oil. A heat distribution analysis using neutron and temperature logs from two observation wells showed that foam had improved areal and vertical sweeps. Finally, a comparison between in situ foam volumes in Midway Sunset and a similar project conducted by Shell in two Kern River pilots showed that the rate of foam propagation in Midway Sunset is about 4.5 times faster than in Kern River.
The Development of a Probabilistic Physical Model for Foam Generation by Snapoff in Regular Square Grid Network Systems
Authors: Armitage P. , Dawe R. A. 
Published: December 2007

ABSTRACT
This paper assesses the degree of influence snap-off, leading to either a bubble flowing or pore blocking mechanism, has on the pressure profiles and sweep efficiencies generated as a result of bubble production and foam propagation through regular square grid networks. A visual single pore model in which bubbles of known size can be generated leading to either of the two mechanisms was developed. New 2-D visual square grid networks have been developed in which different numbers (0,39,185) of these single pore bubble germination sites are incorporated as a fraction of the total number of sites available (800). In effect what has been created is a series of pre-determined, probablistic physical models for bubble generation by snap-off. These models have been used in a series of systematic drainage displacements.
These experiments have yielded quantitative information on how bubble production and the subsequent flowing bubbles or pore blocking can affect a foam's ability to control the mobility of the gas phase. These studies allow for a more competent evaluation of the importance of both of these mechanisms in improving the sweep efficiency.
Design of a Novel Flooding System for an Oil-Wet Central Texas Carbonate Reservoir
Authors: Olsen D. K. , Hicks M. D. , Hurd B. G. , Sinnokrot A. A. , Sweigart C. N. 
Published: December 2007

ABSTRACT
Alkaline-surfactant-polymer flooding (ASP) as a method for oil recovery has traditionally been applied to sandstone reservoirs. This paper describes the first application of ASP technology with wettability alteration in a carbonate reservoir and compares laboratory performance of alternate chemical flooding processes. The oil-wet Cretaceous Upper Edwards reservoir, located in Central Texas, has characteristics generally favorable for chemical flooding. The reservoir has low brine salinity, low temperature, moderate oil viscosity, high residual oil saturation, and a diverse carbonate lithology without anhydrite or gypsum. This reservoir targeted for EOR, is currently produced by a strong, natural water drive from wells on a 2-acre spacing. Extensive reservoir characterization has been performed to establish the extent of the resource.
A laboratory study was conducted to compare alternative EOR processes for individual geologic zones identified by describing and subdividing the reservoir. Coreflood experiments using fresh Upper Edwards reservoir core, have given post-waterflood oil recoveries of 45.3%, 10.0%, and 11.6% from small, low-concentration slugs of alkaline-surfactant-polymer, alkaline-polymer, and polymer formulations, respectively. These laboratory evaluations have shown that ASP formulations of sodium tripolyphosphate and sodium carbonate along with a low concentration of petroleum sulfonate maintain interfacial activity upon extensive dilution with reservoir brine and give significantly better oil recovery than alkaline-polymer or polymer formulations. The results indicate that a cost effective alkaline-surfactant-polymer process can be designed for application in a carbonate reservoir.
Co-Deployment of Surfactant/Polymer and Miscible Gas Enhanced Oil Recovery Processes: A Simulation Study
Authors: Barker J. W. 
Published: December 2007

Abstract
A reservoir simulator capable of modelling both surfactant/polymer flooding and gas displacement processes (immiscible or miscible) is described. Novel extensions to existing phase behaviour and relative permeability models are used to represent interactions between the two processes. Results are presented quantifying the possibilities for combined chemical and miscible EOR.