bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evaluation and Selection of Petroleum Engineering Software: A Case Study
Authors: Eldin O. Nasr , Hussein A. , Kumar S. , Ashry A. 
Published: December 2007

Abstract
Recent advances in computer technology and the proliferation of computers in the workplace have had a big impact on technical decision making and on the day to day work of engineers. In petroleum engineering, we are faced with a variety of complex software, with different functionalities, prices and features. It is quite a challenge to review the options available and to select one which will be the optimum for a significant length of time and provide the company with best tools at the lowest price.
This paper presents the philosophy and the methodology involved in the evaluation of software. The compulsions on the part of the suppliers as well as the demands of the customers are discussed. Practical criteria for evaluating software for petroleum engineering applications, evolved through the last decade of experience in several operating companies and with discussions with international suppliers and experts, are presented.
The process of evaluation and the criteria and process of selection are described through two real examples, one for reservoir simulation software and the other for well test analysis software, undertaken recently at our company. Detailed tables and check-lists are presented for these two cases which enabled the engineers as well as the management to quickly review the available packages and to decide which one would best meet their needs. A desirable outcome of the process was the fact that we were able to provide the suppliers with a lot of sensible suggestions to improve their products for our benefit.
This paper seeks to provide an understanding of the software process lifecycle, from design to sales to usage, in order to allow engineers the necessary insight for evaluating their own given software.
The software industry is in such turmoil that these skills are now necessary on a frequent basis for continuous quality improvements which require that engineers find the best solutions to their problems at lowest cost.
Vertical Capillary Continuity Between the Matrix Blocks in a Fractured Reservoir Significantly Improves the Oil Recovery by Water Displacement
Authors: Pratap Mahendra , Kleppe Jon , Uleberg Knut 
Published: December 2007

Abstract
Block to block processes in a vertical stack of matrix blocks in a fractured reservoir have been extensively studied for gas-oil systems. Similar investigations have, however, not been reported for the case of water-oil systems. This study details the block to block processes and the effect of capillary continuity between the matrix blocks on oil recovery by water displacement in a fractured reservoir. Fine grid simulation studies under water flooding have been carried out on Eclipse 100 for varying degrees of matrix to matrix contact to illustrate the dependence of oil recovery on the position and the extent of the areal contact between the matrix blocks. Our results show that for the simplified system of mixed wet matrix blocks, the phenomenon of oil re-drainage from the downdip blocks to the updip blocks takes place both with or without matrix contacts between them. Such a phenomenon is not observed in case of strong water wet rock. For strong water wet rock, capillary imbibition controls the oil recovery and the effect of capillary continuity is not significant. However, for reservoirs of mixed wettability, such as Ekofisk, the oil recovery is significantly enhanced even with a moderate areal contact between the matrix blocks. The additional oil recovery, which is substantial as compared to the isolated single matrix block oil recovery, is due to gravity forces and depends on the thickness of the payzone. The oil recovery and the recovery time are also dependent on the tortuosity of the capillary continuity.
The findings of the study have applications in the prediction of oil recovery by water displacement in a fractured reservoir.
Nuclear Logging-While-Drilling Measurement: An Assessment
Authors: Badruzzaman A. , Nguyen P. T. , Stonard S. W. , Logan J. P. 
Published: December 2007

Abstract
The state-of-the-art in nuclear logging-while-drilling measurements is discussed. Recent improvements in design and interpretation to address the difficulties encountered by these measurements in the dynamic borehole environment that exists are described. Examples of evaluation of the measurement from field data are given. Use of three-dimensional Monte Carlo modeling techniques to complement field measurements in assessing these measurements is illustrated.
Tertiary Miscible Flood in Phegly Unit, Washington County, Colorado
Authors: Connally C.A. 
Published: December 2007

This paper was prepared for the Improved Oil Recovery Symposium of the Society of Petroleum Engineers of AIME, to be held in Tulsa, Okla., April 16–19, 1972. 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 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 slug of LPG followed by slugs of natural gas alternated with water and finally driven by further water injection was used in a miscible displacement scheme for tertiary recovery in the Muddy D sand reservoir, Phegley Unit, Washington County, Colorado. The tertiary project was applied full-scale to the small (9.6 MM bbl PV) reservoir at a time when a successful waterflood was approaching completion. An additional bank of oil was produced but the oil rate declined rapidly with premature gas breakthrough. It was concluded that the volumetric sweep with the miscible fluid was relatively inefficient because of an unfavorable mobility ratio. Also, it was possible that a significant portion of the oil banked-up within the reservoir was bypassed after breakthrough of gas at the production wells.

Introduction
As with most successful waterfloods, the Phegley Unit operation was leaving more than half of the original oil in place as it approached the economic limit. Wells and production equipment were in generally good condition, there were no adverse problems with fluid injection, injection and production volumes were essentially equal and flooding performance had been good. The Unit appeared to be a favorable site for a trial of some technique for tertiary recovery.
A variety of methods were considered for improving recovery, including carbon dioxide injection and thermal techniques. A miscible displacement sequence involving a slug of LPG followed by slugs of natural gas alternated with water was chosen as having the best potential for success in this particular situation. The relatively small size of the reservoir allowed risking a reservoir-wide trial rather than a single pattern pilot test. The tertiary recovery operation was begun in September, 1964 and the following discussion describes the performance through July, 1971.

SITE CHARACTERISTICS AND PRIOR HISTORY
The Phegley Unit is located about 90 miles east of Denver in Washington County, Colorado. Production is from the Muddy "D" sandstone of Cretaceous age. The sand averages about 8 ft thickness and extends over an area of about 785 acres. Depth averages about 4900 ft.
Analytic Technique to Forecast Production for Non-Declining Oil Wells in Bounded Solution-Gas-Drive Reservoirs
Authors: Sonrexa Kartikay , Kumar P. Santhana , Al-Ajmi Hussain 
Published: December 2007

Abstract
A methodology has been developed to forecast the performance of an oil well which has not gone into the decline mode as yet i.e., which is exhibiting (a) increasing, (b) constant or (c) fluctuating production rates. This procedure has been adapted from the solution of the familiar "Diffusivity Equation" under conditions which give rise to the well-known "exponential decline" behavior. The technique has been illustrated with the help of both a synthetic case and an actual field example from a Middle Eastern reservoir. The analytically-derived predictions have been compared with the results from single well numerical simulation. There is good agreement between the two. The analytic technique gives conservative predictions.

Introduction
Historically, one of the most common tasks that a petroleum engineer is confronted with, while analyzing the performance of a single well, a reservoir or a field is the determination of :Future production rates;Producing life and,Remaining reserves before reaching its economic limit.
One may require the knowledge of these quantities both for a mature producing field as well as a newly-discovered one. These parameters have a large impact on important financial decisions. Numerical simulation provides a means to calculate them through modeling the well/reservoir/field. However, the process of modeling can be quite time-consuming and expensive. It is, therefore desirable to develop analytic means to furnish quick yet reliable answers.
The technique most often employed to derive the above quantities is the so-called "Decline Curve Analysis" which is applicable during the declining production phase. The procedure essentially consists of (i) plotting oil production rates versus time, (ii) establishing a trend through the past performance by fitting a suitable curve and (iii) extrapolating the curve to make forecasts. It has been recognized for a long time that the decline curves can be of three types :Exponential,Hyperbolic andHarmonic.
Originally it was believed that the curves were purely empirical in nature with the hyperbolic curve representing the most general type whereas exponential and harmonic curves were special cases when the "decline exponent" was equal to zero or one, respectively. In recent times, it has been demonstrated that the exponential type of decline does, indeed, have a sound theoretical basis. Constant-pressure solution of the radial Diffusivity Equation for a well in a bounded reservoir under the well-known standard or ideal conditions e.g., single phase fluid, laminar flow etc. proved to be an exponential decline during the pseudo-steady state regime.

Discussion
The topic of decline curves has been vigorously debated in the petroleum literature since J.J. Arps proposed his famous equations. P. 61^
Microbial Induced Corrosion Of Subsea Pipeline in the Gulf Of Suez
Authors: El-Raghy Saad M. , El-Leil Hussein M. Abou , Ghazal Hany H. 
Published: December 2007

Abstract
In mid May, 1996, a leak was developed in a 24" crude oil line which transfers the untreated crude oil from El-Morgan field at Gulf Of Suez to the onshore process facilities. The line was installed in April, 1993 from carbon steel, API-SL XS - 60, tubing with wall thickness 0.75 inch. A diving survey was carried out after oil spill using side scan sonar survey and an Remote Operating Vehicle (R.O.V) video inspection identified the leak to be due to internal corrosion in 8 joints located at depth 240 - 250 feet. After fixing the leaks, complete ultrasonic survey was performed using high resolution intelligent pig. The ultrasonic data with the sample analysis of the deposits accumulated a head of the pig confirmed the mode of corrosion as internal Microbial Influenced Corrosion (MIC) in 6 o'clock position. A comprehensive review of the corroded line history and the available corrosion monitoring data and the applied corrosion mitigation program refereed to the following:Corrosion monitoring using weight loss coupons, electrochemical devices, and / or chemical methods installed in the two ends of the subsea pipelines does not shows any sign of high corrosion rate (average 3 MPY).Absence of frequent pigging process in the pipeline resulted in accumulation of sludge that caused under deposits corrosion.Thermophilic SRB bacteria was not detected, however some non SRB's were detected.
This paper reviews in details the pipeline history, corrosion mechanism, inspection outlines, reservoir souring modeling and presents action plan to prevent this leak to happen again in future, with a brief introductory for mitigation options strategies and economics

Introduction
The Gulf Of Suez Petroleum Company (GUPCO) was founded in 1965 as a joined venture company between the Egyptian General Petroleum Corporation, EGPC, and the standard oil company, AMOCO, For oil exploration and production in Egypt. The production reaches its prehigh in early 1985 with total 600,00 bbls oil per day. However, production started to go down due to normal reservoir depletion and limited new discovers.
P. 301^
A New Conventional Method of Analysis for Well Tests in Hydraulically Fractured Wells Using Downhole Pressures and Sandface Rates
Authors: Osman Mohammed E. , Almehaideb R. A. , Abou-Kassem J. H. 
Published: December 2007

Abstract
Analysis of variable flow rate tests has been given special attention recently because, in many cases, it is impractical to keep a flow rate constant long enough to perform a drawdown test. Also, in many other drawdown and buildup tests, the early data are influenced by wellbore storage effects, and the duration of these effects can be quite long for low-permeability reservoirs. For hydraulically fractured wells, the early-time period represents linear flow. Current methods of analysis of multirate tests, in fractured wells, use both conventional and rate-normalized type-curve matching for the pseudoradial flow period; and only rate-normalized type-curve analysis for the linear flow period. None of the current methods use a direct approach to analyze the linear flow data.
This paper presents a mathematical model which describes drawdown and buildup tests in hydraulically fractured wells. A new conventional and simple method of analysis based on this model is presented for drawdown and buildup tests in oil and gas wells. This new method uses a direct approach to analyze the linear flow data and combines it with the conventional analysis for pseudoradial flow data. It does not require a priori knowledge of the fracture type (uniform-flux or infinite-conductivity); in fact it predicts the fracture type.
This method is useful for the analysis of simultaneously measured downhole pressure and sandface rate data.
Data of three well tests reported in the literature were analyzed by the new method and the results including the comparison with those obtained by other methods are presented and discussed.
Tying Training to Business Needs (Case Study)
Authors: Wadoud H.A. , Khalaf Fouad 
Published: December 2007

Abstract
The new training process is centered around "tying training to business needs" as defined in the Company's mission, vision and values. A performance management form is used to identify training requirements related to Company business. The new process adds the following features:–Introducing the concept of having a training coordinator, fully assigned to this task if necessary, in every major department to help supervisors identify training requirements for employees–Having a short- and long-term evaluation process, used for the first time in Egypt, to scorecard training benefits for verifying that training costs have their yields on the actual business–Having a central training team to coordinate efforts for a final plan, to optimize the process, manage cost, and propose improvements in the new process–Establishing a comprehensive training database–Clarifying process and roles for defining needs, getting approvals, and evaluating the business returns from training.
This paper presents Gupco's efforts to improve training and to tie it to business needs; shows the components of the new training process and the implementation problems; and finally highlights future directions and developments in order to enhance tying training to Gupco needs for improving business practices.
Gupco's efforts in the training field can help external customers (training institutions and universities) define their products in order to address Gupco training requirements and will help achieve win-win deals between the Gupco and its business partners in the "training industry." The efforts achieved in Gupco address an international concern about strengthening co-operation between partners in training: industries, universities and training firms.

Introduction
Improving employees' skills and competencies and preparing them for future careers is basic for progress of any organization. Organizations need to create an environment that encourages learning. Professional organizations which want to be leaders in the industry should be "learning organizations," willing to address current and future training needs. Only by doing this, organizations shall develop the power and the human resources to survive and thrive the turmoil of the future and be able to successfully make the transition to the 21 century. Today's professionals are expected to have adequate knowledge of everything that is related to their core business: they need to learn business management, system thinking, mind mapping, how to read fast and to improve communication skills, how to re-educate self and how to absorb information.
P. 459^
Inert Gas Injection as Secondary and Tertiary Recovery Method in the Martha Field in Kentucky
Authors: Vadgama Usman N. , Hinkle Bill B. 
Published: December 2007

Abstract
To study the economic feasibility of an inert gas injection process in the low-permeability portion of Martha field, a pilot project was portion of Martha field, a pilot project was initiated in Dec., 1966. During 3 years of operation - from 1967 to 1969–77 MMscf, or 20.6 PV, of inert gas have been injected into the formation. PV, of inert gas have been injected into the formation. As of this date, approximately 12,000 bbl of additional oil have been recovered. Another 5,000 bbl of "inert gas oil" are expected before the production declines back to its initial rate. Calculated additional oil recovery is about 33 bbl/acre-ft. Inert gas injection per barrel of oil production amounts to approximately 4.5 Mscf. Before going to a full-scale injection program, a second pilot was initiated to study the effectiveness of this process, in combination with cross flooding, in process, in combination with cross flooding, in a watered-out low-permeability area where waterflooding was ineffective. First results obtained are encouraging. The cost for generation and compression of inert gas is estimated to be 120/Mscf.

Introduction
Eastern Kentucky is one of the old oil-producing areas of the U.S. The first known well to produce petroleum was drilled in 1830 in Knox County. Fig. 1 shows geographic locations and geological formations of main oil- and gas-producing areas of Kentucky.
The Martha oil field is located just northeast of the junction of Johnson, Lawrence and Morgan Counties, and is shown with an arrow in Fig. 1. The field was discovered in 1919 and covers approximately 4,500 acres. Since then, the Martha oil field has produced roughly 19 million bbl of oil primarily by gas-in-solution type reservoir energy. As the reservoir energy declined, a waterflood project on the east side of the field was started in 1955. As of this date, approximately 2,300 acres in the main area of Martha field has been developed for and is presently maintained under active water injection. Over 6 million bbl of secondary oil has been recovered during the last 15 years. The expansion of waterflood to an additional Ashland-owned 1,100 acres was limited because of low injectivity. This low-permeability portion of the Martha field has produced 4.7 million bbl of primary oil, which represents roughly 127 bbl/ acre-ft, or 15 percent of initial oil in place. In other words, over 30 million bbl of oil remains unrecovered in the ground. This huge amount of oil is a big challenge to us and offers an opportunity to test the field-wide application of one of the improved oil recovery techniques.
A Study of the West Cement Medrano Unit - Caddo County, Oklahoma
Authors: Hall Alvin E. 
Published: December 2007

Abstract
This paper presents a study of the operation of the West Cement Medrano Unit in Caddo County, Okla. Included are essential data on reservoir characteristics, history of development, and reservoir performance, under both competitive and unitized gas injection operations.

Introduction
The West Cement Medrano Pool produced from a gas cap above an oil reservoir for 6–1/2 years before oil was discovered. It was then produced for 4 1/2 years as a combination pool with both gas and oil wells producing on a competitive basis. The gas wells were voiding several times as much reservoir space as were the oil wells, and it was recognized that should this situation continue, the gas wells would soon deplete the reservoir pressure and only a part of the oil reserve could be produced. The pool was unitized on Dec. 1, 1947, and all gas wells and high ratio oil wells were immediately shut in. Selective production operations continued until a gas compression plant was completed in July, 1949, and first gas was returned to the reservoir. Since this date, the pool has been operated under pressure maintenance with all produced gas and water returned to the reservoir.

History of Development
The West Cement Medrano Unit is located in Townships 5N and 6N, Ranges 9W and 10W, Caddo County, Okla., 70 miles southwest of Oklahoma City and 10 miles directly south of the city of Anadarko on State Highway No. 8. Geologically, the field is located near the trough of the Anadarko Basin, and deep wells drilled in the area indicate the presence of sedimentary beds and possible oil production to depths of over 20,000 ft. The Medrano Sandstone is one of some 25 or more formations which produce oil and gas in the Cement Area.
The Medrano Sand was first found productive in a well drilled by Magnolia Petroleum Co. in the SE NE SW of Section 36-6N-10W. This well, Magnolia's Medrano No. 6, found 67 ft of gas saturated sand and was completed at a plugged-back total depth of 4,950 ft for an open flow potential of 78.1 million cu ft/D. At the time the well was completed, there were several dry gas reservoirs producing in the Cement Area, and it was believed that the newly discovered Medrano Reservoir was also a dry gas reservoir. Additional wells were drilled to the Medrano on wide spacing, and for the first 6–1/2 years, the reservoir was developed and produced as a gas reservoir.
Disposal of Dirty Liquids Using Slurry Fracture Injection
Authors: Dusseault Maurice B. , Bilak Roman A. , Rodwell L. Gene 
Published: December 2007

Abstract
An automated waste liquid injection system for dirty liquids was designed and implemented in an unconsolidated sandstone formation in southeastern Alberta. This development was based on previous waste sand injection in central Alberta. Waste liquids consisting of contaminated water, heavy oil, and fine-grained particulate matter are being diluted and injected under formation fracture pressures. Monitoring for environmental security and process control includes precision tiltmetres and comprehensive pressure analysis. Injectivity, transmissivity, reservoir pressure evolution, and fracture closure pressure calculations based on pressure fall-off and step-rate tests allow the formation state to be continuously re-evaluated. The reservoir is not being impaired by the continued injection of dirty liquids.
This article first describes Slurry Fracture Injection (SFI) history and principles, the site geology, and recompletion strategy. Then, data from the trial period and the summer operations are presented and analyzed. The use of SFI in this new application seems to be highly successful, and the nature of the process and controllable factors are discussed in the context of preserving target formation injectivity.