bluuebunny/crossref_metadata_2025_split huggingface dataset:
Optimization of Well Placement in a Gulf of Mexico Waterflooding Project
Authors: Guyaguler Baris , Horne Roland N. , Rogers Leah , Rosenzweig Jacob J. 
Published: December 2007

Abstract
Determination of the location of new wells is a complex problem that depends on reservoir and fluid properties, well and surface equipment specifications, and economic criteria. Various approaches have been proposed for this problem. Among those, direct optimization using the simulator as the evaluation function, although accurate, is in most cases infeasible due to the number of simulations required.
In this study a hybrid optimization technique based on the genetic algorithm (GA), polytope algorithm, kriging algorithm and neural networks is proposed. Hybridization of the GA with these helper methods introduces hill-climbing into the stochastic search and also makes use of proxies created on the fly. Performance of the technique was investigated on a set of exhaustive simulations for the single well placement problem and it was observed that the number of simulations required was reduced significantly. This reduction in the number of simulations reduced the computation time, enabling the use of full-scale simulation for optimization even for this full-scale field problem. It was also seen that the optimization technique was able to avoid convergence to local maxima due to its stochastic nature.
Optimal placement of up to four water injection wells was studied for Pompano, an offshore field in the Gulf of Mexico. Injection rate was also optimized. The net present value of the waterflooding project was used as the objective function. Profits and costs during the time period of the project were taken into consideration.
Simulation Model Development for Bayu-Undan Field
Authors: Currie J. C. , Balke S. C. 
Published: December 2007

Abstract
A case study is presented showing how reservoir characterization with geostatistical modeling was used to develop the reservoir flow simulation model for Bayu-Undan Field. The modeling was tailored to both reservoir type and the selected development scenario.
Bayu-Undan Field is currently under development as a gas recycle project with future gas export. The reservoir is made up of both fluvial and marine sedimentary sequences. The need to predict fluid flow for both recycle and depletion scenarios in the presence of these reservoir types requires an understanding of reservoir heterogeneity and a method to preserve it in an upscaled flow simulation model.
The major control on reservoir character is facies type which controls grain size, sedimentary structure and degree of bioturbation. Facies were determined from log motif and core description. Different statistical techniques were chosen to build facies models for the continuous marine zones and the heterolithic marine/fluvial zones. Numerous facies realizations were constructed to evaluate the possible range of outcomes and uncertainties. Porosity was distributed either deterministically using a weighted average algorithm or statistically using variograms. Permeability was distributed using a porosity-based transform.
A number of permeability upscaling algorithms were evaluated to ensure reservoir heterogeneity was preserved when upscaling from the geocellular model to the flow simulation model. As a result, separate algorithms were chosen for horizontal permeability in marine and fluvial units, and for vertical permeability. Use of these upscaling techniques resulted in very good preservation of gas in place by permeability class, shown by comparing the geocellular model with the upscaled model. The modeling captured and preserved the reservoir flow characteristics critical to performance predictions for the gas recycle project.
State-of-the-Art Nonphosphate Design Revolutionizes Hydrocarbon-Based Completion Technologies
Authors: Thompson Joseph E. , DeVine Carolyn S. , Delorey John R. 
Published: December 2007

Abstract
Oil based fluids have been used since the inception of well completion technologies. Formation sensitivity to water has often been the primary consideration for the selection of oil based stimulation fluids. Historically, oil based fracturing designs required complicated procedures to successfully execute a fracturing operation. Rheological properties of fluid compositions used did not produce stimulation fluids with optimum viscosity or transport characteristics. The obvious hazards involved in accomplishing an operation using these types of fluids were also great due to the variability of the fluids caused by different base hydrocarbons.
The development of a unique system with rheological, transport, and process advantages, which have long been desired in hydrocarbon based stimulation fluids are discussed in this paper.
In addition, the chemical evolution of the oil based gel system will be discussed, and properties of the fluid including rheology, break, and conductivity testing will be presented. Characterization of the rock mineralogy for those formations which can be considered as candidates for stimulation with the hydrocarbon based system are presented. Detailed field case histories of the application of the new system are included. In general, stimulation with the new system provides a rapid clean-up and return to production.
A General String Design Method for Extended-Reach and High-Pressure Applications
Authors: Zheng Andrew S. 
Published: December 2007

Abstract
This paper presents a general string design methodology that optimizes coiled tubing (CT) string makeup for extended-reach and high-pressure applications. The string design methodology includes three components, namely tubing force, pressure limit, and wall-selection criteria. The wall-selection criteria qualify the use of a given wall thickness for the string based on the consideration of string ratings and extended-reach potential, which relies on a new parameter called "compression ratio (η)". Through the analysis of tubular lockup behavior, the compression ratio is found to govern the lockup depth of tubing string in wellbores. Integrating the calculations of tubing force and pressure limit with the compression ratio-based wall selection criteria optimizes string makeup by minimizing the overall tubing weight while satisfying the requirements of string ratings and extended-reach. Design examples for both extended-reach and high-pressure applications demonstrate the effectiveness of this method.
New Methods for Estimating of Formation Pressures and Fracture Gradients from Well Logs
Authors: Draou A. , Osisanya S. O. 
Published: December 2007

Abstract
The accurate prediction of pore pressures and fracture gradients has become almost essential to the drilling of deep wells with higher than normal pore pressures. Drilling costs and problems can be reduced substantially by the early recognition of abnormally high pore pressures.
Two new methods have been developed from well logs that can be applied universally to the determination of pore pressures and fracture gradient. The first method uses the principle of compaction concept where the porosity varies exponentially with vertical stress, and the second method uses the power-law relationship. Acoustic logs obtained from five wells in Ouargla and Garet El Bouib fields are used to validate the two methods.
The computed pressures matched the measured pressures obtained from repeated formation tests (RFT). The deviation between the first method and RFT varies from 3% to 6%, while, the deviation for the second method varies from 1% to 3%. The acoustic log predicts fluid pressure within an accuracy of 0.05 psi/ft. The standard deviations for the first method and the second method are 0.04 psi/ft and 0.02 psi/ft respectively. The analysis also shows that there are two overpressured zones in the well studied, which accurately matched the actual sequence of events while drilling the wells. The developed methodologies are illustrated and validated with several examples from the Hassi Messaoud field in Algeria.
A Real-Time Well Site Log Analysis Application Using MRI Logs
Authors: Aadireddy Prabhakar , Coates George 
Published: December 2007

Abstract
With any complex logging tool, there exists a need for a "qualitative and reasonable" analysis, run in real-time at the well site that both provides a preliminary interpretation of the data and also serves as a means for enhancing quality control. Such an application has been developed to provide a quicklook analysis of data from NUMAR’s MRIL® -Prime tool.
The application takes advantage of the Prime tool’s ability to simultaneously acquire data from multiple nuclear magnetic resonance (NMR) activations for purposes of fluid identification. The application is based on several well-established NMR fluid-characterization methods. These methods compute total porosity, effective porosity, bulk volume irreducible, flushed-zone fluid volume, and fluid type in a variety of reservoirs. The methods used in quick-look analyses include the Differential Spectral Method (DSM™), Time Domain Analysis (TDA™), Shifted Spectrum Method (SSM™), Enhanced Diffusion Method (EDM™), and the Total Porosity Method (TPM™).
Accomplishing these objectives, i.e., computation of total porosity, effective porosity, etc., in a real-time environment requires consideration of the wellsite engineer’s level of experience and responsibilities. In addition, the dynamics of the real-time wellsite analysis presents several competing and important challenges: acquiring quality measurements, working with limited data and information, and providing results in a timely and efficient manner. Thus, a real-time analysis should be robust and consistent with any additional analysis done in the post-acquisition environment.
A set of procedures has been developed to guide the process so that reasonable interpretations can be obtained over a broad range of operating conditions. To simplify the engineer’s tasks, the analysis procedure is automatically driven by the type of NMR data being obtained. Thus, meaningful results can be obtained without increasing the burden on the field engineer.
This paper briefly describes the techniques that have been developed and demonstrates their application through field examples.
Development of a Robust Gyroscopic Orientation Tool for MWD Operations
Authors: Estes R. A. , Epplin D. M. 
Published: December 2007

Abstract
The allure of a gyroscopic directional sensor for MWD (Measurement While Drilling) operations has spanned over two decades now. The authors first investigated potential sensors for MWD applications in 1982 and were disappointed to find technological limitations precluded such a device. Why is it so difficult to build a gyroscope into an MWD tool, and why don't we have one available for commercial use in the industry today? Also, what should oil companies expect from a service company who promises an "MWD Gyro Tool" in the next year or two?
Currently there are several service companies working on directional modules that incorporate some type of gyroscopic sensor and promise to provide an indication of "True North" direction in conjunction with MWD tools. This paper is intended to establish realistic expectations for the performance that might be delivered by these early gyroscopic tools in the harsh MWD environment.
The paper also describes the investigation, specification, design decisions, and testing done in the development of a tool to meet the most common application requirements for an MWD Gyro. Initial testing of the tool has proven it surprisingly accurate and at least as robust as existing conventional mag/accel sensors. Extensive qualification testing in both lab and field settings has proven the instrument capable of surviving the harsh MWD environment.
An Improved Empirical Approach for Prediction of Formation Water Saturation and Free Water Level for Uni-modal Pore Systems
Authors: Negahban Shahin , Gunter G. W. , Smart C. R. 
Published: December 2007

Abstract
Minimizing the uncertainty associated with the prediction of formation water saturation can be achieved through the integration of formation evaluation (log analysis), capillary pressure data, and pressure gradient information. To reduce the uncertainty, it is often necessary to determine porosity, permeability and water saturation using integrated methods. The magnitude of uncertainty reduction associated with predicted petrophysical parameters is a function of the inherent quality of the various data acquisition devices. Thus, reduced uncertainty in hydrocarbon pore volume can often be achieved by combining explicit probabilistic formation evaluation and a quantitative capillary pressure model.
An empirical quantitative capillary pressure-water saturation model has been developed that relates the capillary pressure and height above the free water level, FWL to the wetting phase saturation. This relationship generalizes the correlation for all existing rock types that exhibit uni-modal pore geometries. The model constants are expressed as continuous functions of the interval speed that is defined as the square root of core measured permeability divided by porosity (√k/ϕ) data. The water saturation is calculated continuously as a function of the height above the FWL using the log predicted permeability-porosity ratios. In the absence of a clear fluid contact, the new model provides an excellent tool for describing the fluid contacts by iterating on saturation. The FWL is adjusted until a good agreement exists between a base water saturation and the predicted water saturation from the empirical capillary pressure relationship.
This paper describes the new saturation model and its application for a siliclastic layered reservoir. The model parameters are tuned based on a statistically significant number of measured high-pressure mercury injection capillary pressure curves. Furthermore, the model parameters are calibrated to data from a key well. The results of the model are then used to predict formation water saturation in neighboring wells.
Density Measurements Of Cement Sheaths Provide Accurate Evaluation Of Oil Well Cementing Operations
Authors: Cocanower R.D. , Dillingham Mat E. , Reeves Chet 
Published: December 2007

Publication Rights Reserved
This paper was prepared for the 38th Annual Fall Meeting of the Society of Petroleum Engineers of AIME in New Orleans, La., on October 6–9, 1963, and is considered the property of the Society of Petroleum Engineers. Permission to published is hereby restricted to an abstract of not more than 300 words, with no Illustrations, unless the paper is specifically released to the press by the Editor of the Journal of Petroleum Technology or the Executive Secretary. Such abstract should contain conspicuous acknowledgement 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 providing proper credit is given that publication and the original presentation of the paper.
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
Laboratory and field results have proven the use of density measurements of the cement sheath to provide more information than other methods to evaluate oil well cementing in relation to the well program. Skips, channels, voids, and low density slurries are accurately detected from density measurements. This knowledge compared to the type of completion or rework program desired will assure the engineer of a successful program.
A flux of collimated gamma rays directed into pre-set weights of solids and solutions, adjacent to casing, has produced an adequate spread of points that is relative to the bulk density of these materials. The phenomenon of backscattering affected by compton scattering, photoelectric absorption and the mechanics of the sonde has made this possible. Test pit and field data revealed the required mechanics to narrow the zone of inspection to borehole dimensions only.
Since the amplitude of the recorder response is subject to bulk density changes of the mass adjacent to the casing, then the result will show the uniformity or the non-uniformity of the solids or solutions in this area. Contamination by a foreign material decreases the cohesiveness of the cement slurry, therefore it reduces the adhesiveness of the cement to casing and adherence of cement to formations.
Interpretation of the density curves is easily made by engineers or operators. Typical logs from various areas are shown to support the laboratory development data. The information obtained is a valuable aid lo interpreting neutron logs and chlorine logs as shown by case histories.
Evaluation of Risk in Appraisals of Large-Scale Development Projects for Financing Purposes
Authors: Miller Richard J. 
Published: December 2007

Society of Petroleum Engineers 6200 North Central Expressway Dallas, Texas 75206
THIS PAPER IS SUBJECT TO CORRECTION
American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
Large scale projects for the development of new oil and gas fields, whether in the U.S. or foreign, are often financed by commercial bank lending. Particularly when such financing is Particularly when such financing is done on a "project" basis on appraisal of the property to be developed is required for a lender to determine the future value and debt repayment ability of the property. Such appraisals are often performed prior to development with data from a few exploratory wells. These appraisals can have results that vary greatly depending on the methods of data application.
This paper presents a system of engineering appraisal which combines statistical methods of data application with commonly used reservoir engineering procedures. Data distributions on procedures. Data distributions on such componants of the reservoir and production appraisal as porosity, production appraisal as porosity, permeability, and gas-oil ratio are permeability, and gas-oil ratio are used to identify ranges of potential appraisal results. Statistical methods of frequency distribution and standard deviation are used to obtain a distribution of final appraisal results. The system then uses a variation of expected value theory to impose a risk factor on the appraisal results to determine the expected value of future reserves and revenues from the project. This appraisal procedure allows the lender to assess risk exposure and to structure the project financing accordingly.

Introduction
Over the past 30 years oil and gas exploration and development has moved continuously from the relatively inexpensive and safe continental areas to more remote and challenging areas. A very rapid expansion of large scale development has occurred offshore and in previously undeveloped areas. The primary example is the North Sea but offshore California, Alaska, Arctic Canada and the Amazon Basin are also very active. In the North Sea alone more than 20 new fields have been discovered and are in various stages of development. The cost of development of these new areas is enormous. The large number of extremely high cost projects undertaken by all companies has resulted in massive bank debt financing.
Coping With Another Embargo: Evaluating the Effects and the Economics of Reducing the Impact
Authors: Dutton Granville 
Published: December 2007

Society of Petroleum Engineers 6200 North Central Expressway Dallas, Texas 75206
THIS PAPER IS SUBJECT TO CORRECTION
American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
The Arab Embargo of 1973–74 reduced U.S. liquid petroleum supplies by less than 10%, yet — coupled with panic legislation and regulations — panic legislation and regulations — resulted in severe supply dislocations, great inconvenience to most Americans and actual hardships for others. Today, an effective OPEC embargo could reduce liquid supplies by 40% and would disrupt a substantial segment of the American economy as well as seriously curtail the individuals' freedom to travel and drastically reduce the nation's standard of living.
This paper details the geographical areas and industries that would be most adversely affected by another embargo. The effects on the standard of living, as measured by the Gross National Product and the reduction in the number of jobs, are calculated. It is concluded that the results of such an embargo would be unacceptable to the American people.
Alternatives to military action are presented in the form of an analysis of available domestic energy resources, the state of the technology utilized in converting these resources to usable fuels, the time necessary to bring on additional supplies in meaningful quantities, the required capital investment and the prices necessary to generate such investments. Finding that the alternative, although subject to an appreciable time lag, is technically and economically feasible, the restraints hindering the timely development of adequate domestic energy sources are investigated.
These restraints are found to be primarily economic and environmental, primarily economic and environmental, including restricted access to public lands. Although they arise from actions of the public, environmental zealots, alleged consumer advocates, regulatory agencies and the judiciary, their efficacy stems from legislation and their elimination and/or reduction is shown to be dependent upon the legislative process. A method whereby those with expertise and interest in solving our energy process can effectively influence this process is presented.