bluuebunny/crossref_metadata_2025_split huggingface dataset:
Interpretation of Dynamic Oscillatory Measurements for Characterization of Well Completion Fluids
Authors: Knoll S. K. , Prud'homme R. K. 
Published: December 2007

Abstract
Dynamic oscillatory rheological measurements may be used as a diagnostic tool for the characterization of microstructure (e.g. crosslink density of a gel or degree of association for a dispersion). The petroleum industry has historically used steady shear viscosity measurements to characterize completion fluids because these measurements can be made to mimic shear flows believed to exist in the well bore and reservoir. However, steady shear measurements are limited in the information they provide because it is difficult to deduce information about fluid structure or the evolution of structure from steady shear data alone. An understanding of the contributions of viscosity from steady shear measurements and elasticity from dynamic oscillatory measurements is critical to:
predicting suspension capabilities of a fluid evaluating the effects of chemical modification in developing improved fluid systems and identifying those factors which are necessary for accurately predicting flow properties in the field.
This paper presents the interpretation of dynamic oscillatory shear data on well completion fluids, including water soluble polymers, crosslinked polymers, and gelled hydrocarbons to demonstrate the utility of these measurements in different applications. Data show that gel formation and degradation can be monitored by observing the frequency and strain dependence of the viscous and elastic components of stress Data also show that shear and temperature decrease crosslink density and as a result affect the fluids ability to transport particles. The effects of sample preparation, chemical modification, or the addition of chemical additives, such as crosslink delayers, on fluid structure will be discussed.
Production Techniques for Aquifer-Type Storage Fields
Authors: McMinn R.E. 
Published: December 2007

This paper was prepared for the Society of Petroleum Engineers Gas Technology Symposium to be held in Omaha, Nebr. Sept. 15–16, 1966. 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 requested 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 discussions 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 use of aquifers for storage of natural gas and peak shaving during temporary high demand periods has been practiced for 10 or 15 years. Most of the work in connection with production technology has been in the areas of well completion and reservoir characteristics.
This paper defines areas of surface production phases as wellhead, gathering system, and dehydration and reviews production equipment types used in these phases. Operating problems encountered are defined and design techniques used to overcome these problems are summarized. Economics of equipment costs., operations, and maintenance are presented where available.

Introduction
Development of natural gas markets in the heavily populated areas of the northern and eastern sections of the United States has resulted in extensive efforts of obtaining higher yearly load factors from existing pipelines. Work in this direction has been particularly intense in the past 10 years because of rapidly escalating costs of installing new pipelines. The basic problem facing pipelines supplying new markets is one of supply and demand. Systems are alternately lightly and heavily loaded during corresponding periods of low and high gas sales which are usually associated with climatic conditions. This situation is particularly aggravated during periods of peak demand which, although occurring at more or less infrequent intervals during the year and for relatively short periods of time, require deliverability rates in excess of the capabilities of the pipeline and its ancillary equipment.
One of several methods to upgrade pipeline load factors is the utilization of aquifers as a storage reservoir. Gas is injected during periods of relatively light demand. During periods of heavy demands the aquifer reservoir is used to feed into the pipeline and supplement deliverability.
In most if not all cases gas is delivered to the aquifer by way of compression from a pipeline, and as such has been dehydrated and sweetened.
The Effect of Pore Structure on Non-Darcy Gas Flow in Some Low-Permeability Reservoir Rocks
Authors: Noman R. , Archer J. S. 
Published: December 2007

ABSTRACT
The present work was carried out to investigate the effect of pore structure on non-Darcy gas flow to enable a better understanding of the relationship between the inertial coefficient and various rock properties. Measurements of porosity, permeability, inertial coefficient and capillary pressure were made on some 40 core samples, as well as visual observations under optical and scanning microscopes.
The results obtained using this integrated approach helped to explain the wide scatter observed in conventional inertial coefficient – permeability correlation plots. It is shown that the inertial effect is not only a function of porosity and permeability, but is also controlled by other factors such as aspect ratio, coordination number, heterogeneities, surface roughness etc.
Performance Comparison of Vertical and Horizontal Hydraulic Fractures and Horizontal Boreholes in Low Permeability Reservoirs: A Numerical Study
Authors: Sung W. , Ertekin T. 
Published: December 2007

ABSTRACT
A single/two-phase, multi-dimensional, finite-difference numerical reservoir simulator, which had been validated through history matches against field data, was used to investigate and compare the production performances of horizontal wells and hydraulically stimulated vertical wells. In the case of vertical wells performance characteristics of vertically and horizontally fractured systems were studied.
In the mathematical formulation of the transport problem a multi-mechanistic flow mechanism which is obtained by superposition of the Darcian and Fickian flow components is implemented to describe the flow of gas in tight porous media. The non-linear system of equations resulting from the finite-difference approximation are solved by using fully implicit generalized Newton-Raphson procedure.
In order to verify the accuracy of the hydraulically stimulated vertical well formulations, the results generated by the numerical model were compared against the existing analytical solutions in the literature. These comparisons exhibited excellent agreements between the numerical and analytical solutions.
Low permeability, single-phase and two-phase (gas-water) natural gas reservoirs have been selected as the target of this study. A series of numerical exercises in a systematic manner were conducted by sifting through the parameters associated with the reservoir characteristics and stimulation strategies in order to understand those which most significantly affect the production from low permeability gas reservoirs. These parameters are reservoir thickness, permeability, isotropicity of the formation, penetration lengths of horizontal boreholes and hydraulic fractures.
The Influence of Reservoir Properties and Geologic Setting on Coalbed Fracturing and Production: A Preliminary Evaluation of the TEAM Project
Authors: Reeves S. R. , Wallace J. A. , Beavers W. M. 
Published: December 2007

ABSTRACT
The Energen Corporation initiated the TEAM coalbed methane production project in the Black Warrior Basin in 1986. Thirty wells in the Oak Grove Degasification Field were drilled, completed and stimulated in the Mary Lee/Blue Creek coal seams. An agressive technology development plan was implemented which included detailed geologic studies, reservoir characterization, fracture treatment design evaluation and early post-fracture production analysis. The results of these investigations are presented in this paper.
Depositional Setting and Production Characteristics of Low Permeability Sandstones, Upper Cretaceous Olmos Formation, South Texas
Authors: Tyler N. 
Published: December 2007

ABSTRACT
The upper Cretaceous Olmos Formation has produced 157 million barrels of oil equivalent from deltaic and shore-zone sandstones in South Texas. Much of the production (2.8 million barrels of oil and condensate and 200 billion cubic feet of gas) is from low-permeability delta-front, shoreface, and shelf sandstones that compose two immature exploration plays. Recent improvements in well stimulation technologies have resulted in production increases 2.5 times to an order of magnitude greater than prestimulation yields.
Real-Time Hydraulic Fracturing Simulation Using a Portable Microcomputer
Authors: Buharali A. M. , Wright T. B. , Willis R. M. 
Published: December 2007

Abstract
A rugged, very compact microcomputer, with a co-processor, has been developed for real-time, high-speed monitoring and simulation of field operations. The development of the computer was funded by the Gas Research Institute for supervision of hydraulic fracturing of gas and oil wells. The system handles data acquisition, data basing, running of process simulator codes, and extensive operator Interface.
The computer is a fully compatible PC clone and uses a passive backplane architecture for easy repair and maintenance. Two Independent processors are used: a 4.77-MHz Intel 8088- and a 25-MHz Motorola 68020 32-bit Microprocessor. This reliable low cost, high performance system brings the power of large minicomputers such as a VAX 11/780 into the field.
Data acquisition is performed by a built-in board which enables sampling 16 (expandable to 256) channels of analog data directly from standard field Instrumentation. Alternatively, connection can be made to most service company vans, with isolation filters preventing intrusion into their electronics. Serial data can also be transferred from an independent data acquisition computer. Acquired data is stored in the data base where it is accessible to process simulation codes during the current Job and for comparison on future jobs.
The Integrated 3-Dimensional Fracture Models running on the system are the most comprehensive simulations developed for real-time operation. Rapid, repeated running of the process models during the early stages of the job permits best estimates of uncertain reservoir parameters to be obtained. This real-time "history matching" is facilitated by extensive on-line help facilities, a totally menu-driven user interface, and high-resolution, high-speed dynamic graphics capabilities. These features also improve operator awareness of current Job status and add significantly to the quality control.
The system has been tested on dozens of field operations. It has been selected for use by a major oil company and is under consideration by several other majors.
A Microcomputer Model for Cutting Transport in Air Drilling
Authors: Sharma M. P. 
Published: December 2007

Abstract
A microcomputer program has been developed for determining the pressure drop caused by the pneumatic transport of drilled cuttings in air drilling operations. The program helps in estimating the volume requirement of air for such operations. The results of the microcomputer program are compared with other calculation methods, experimental data and field data. The comparison establishes the validity and usefulness of this model.
A Numerical Solution to Two-Parameter Representation of Production Decline Curve Analysis
Authors: Agbi B. , Ng M. C. 
Published: December 2007

ABSTRACT
A method to numerically solve the two-parameter non-linear hyperbolic decline curve equation utilized in petroleum engineering is presented. The method only requires the initial production rate and cumulative production at two points in the decline trend to calculate the decline curve exponent 'n' and the initial decline rate Di. The proposed method eliminates the need for a trial and error estimation of 'n' or the need for type-curve or graphical analysis to determine the value of 'n'. This paper demonstrates that the decline curve exponent 'n' lies between negative infinity and positive infinity and includes the exponential (n=0) and harmonic (n=1) decline cases. The results of the application of the method to both published and field data, and a comparison of the results is presented.
As an adjunct to this work and for comparison, a two-dimensional, non-linear least squares regression analysis was used to calculate the two parameters, 'n' and Di. The regression analysis was based on a GAUSS-NEWTON type iterative technique which is capable of generating its own initial values. The results of using this regression analysis approach to the determination of 'n' and are in excellent agreement with the new numerical solution.
Use of Microcomputers for Data Acquisition During Displacement Experiments
Authors: Home R. N. , Bouett L. W. , Gilardi J. , Johns R. A. , Barua J. 
Published: December 2007

ABSTRACT
This paper describes the use of microcomputers for the acquisition and analysis of data in an experimental laboratory. Stanford University Petroleum Engineering Department uses several microcomputers in the laboratory for the collection of measurements during core displacement and flow model experiments. Since 1984 we have accumulated experience in the use of several data-acquisition systems including an 8-bit system and several different 12-bit systems.
The paper describes the way in which these systems have been used, and the way in which they performed. There was little difference in ease of application between the data acquisition boards, the principle differences lay in the technical capability of each system.
Two principle considerations in data acquisition are accuracy and frequency of measurement. It was impossible to obtain sufficient accuracy with the 8-bit board, and we have always used 12-bit boards ever since. Although the analog/digital converters are capable of very high frequencies of sampling, in practise the measurement rate is governed more by the CPU work involved in processing the data during the measurement process. Using programs in BASIC, we were able to achieve data rates of about 100 voltage measurement per second, including the time required to convert the voltage, write it to RAM-disk and graph the answers on the display. The data still required post-processing after the experiment. This post-processing and the subsequent analysis were all performed using the same microcomputer that acquired the data.
Tax and Financial Aspects of Oil and Gas Production Payments
Authors: Sandison Robert W. 
Published: December 2007

This paper was prepared for the California Regional Meeting of the Society of Petroleum Engineers of AIME, to be held in Santa Barbara, Calif., Nov. 17–18, 1966. 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 requested 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 discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Production payments have become increasingly important within the oil and gas industry. Acquisitions of producing companies, acquisition of developed properties, development of existing properties or generation of cash income to a company can all entail the use of production payment financing. The author presents a nontechnical discussion of the tax and financial problem areas and industry practice relating to the use of oil and gas production payments.

Introduction
Most petroleum engineers at one time or other are asked to prepare an engineering report to be used as the basis of a production payment transaction. While most engineers can describe a production payment, not all understand its important position in the financial community in buying, selling or developing oil or other mineral properties.
Production payments since the end of World War II have become increasingly more important within the oil and gas industry. Acquisitions of production companies, purchases of producing oil or gas properties, development of existing properties or accelerating cash income to an existing company can all entail the use of production payment financing.
In fact, it is interesting to speculate that the acceptance of the ABC oil payment transaction by the Internal Revenue Service, as well as the banks and insurance companies, has been largely responsible for the sell-out and demise of many small, medium and even large production companies.
With our high income tax structure and high costs of finding new oil, many oil operators have found it to their advantage to sell producing properties at capital gain rates rather than produce them over a period of time and pay taxes at regular rates as well as high operating and overhead costs. Conversely, certain other companies have found it more economical to purchase proven reserves than explore and developed new reserves by the rare conventional methods. Production payment financing has created the happy solution whereby both the seller and buyer receive maximum tax and financial advantage.
Drilling Considerations on Spray Ice Island Structures: A Case History, OCS-Y-0302 Well No.1, Beaufort Sea, Alaska
Authors: Bowles H. T. , Boykin G. F. , Mamerow B. S. , Summers M. A. 
Published: December 2007

ABSTRACT
This paper discusses the planning considerations and field experience gained from drilling on the Amoco Mars Spray Ice Island. The physical environment, design and construction of the island, well program plan, logistics, environmental impact, and economics are addressed. Spray ice characteristics and the techniques which were implemented to distribute rig loads, maintain rig stability, and protect the ice material from rig associated heat sources are described. These considerations for the spray ice material impacted drilling operations throughout all phases of the project.
Encouragement for the future application of spray ice islands for exploratory drilling was gained during this operation. A substantial exploratory cost reduction compared to gravel islands or a self-contained mobile drilling unit can be achieved using spray ice islands for single well projects in appropriate ice pack and water depth environments.
Toxicity of Drilling Fluids Using Photobacteria and Mysid Shrimp Bioassays
Authors: Bland R. G. , Chang C. Y. , Bettge G. W. 
Published: December 2007

ABSTRACT
The EPA's discharge permit for the Gulf of Mexico caused shortages of shrimp, long turn around times and increased bioassay costs ($1000/test). The Microtox Toxicity Analyzer uses a luminescent marine bacteria to measure toxicity in hours for a fraction of the cost. Including % Oil improved the correlation coefficient to 0.6 690 for all of the samples (n=38) tested.
Some Economic Aspects Of Increased Saleable Liquid Recovery From Natural Gas With Packaged Process Systems
Authors: Coggins R.W. 
Published: December 2007

The individual operating and economic characteristics of the various types of major equipment available for field processing of natural gas-condensate production need to be well known by all concerned. Within the last few years, the USERS AND SUPPLIERS have pooled their knowledge to make available BUILDING BLOCKS OF PACKAGED PROCESS UNITS designed with the single thought in mind of providing economical and efficient installations that provide QUICK RETURNS ON INVESTMENTS AND MORE TOTAL PROFIT DOLLARS over the life of the operation.
The proper utilization of each of these flexible profit-making packages and the selection and up-dating of the proper combinations of these packages…to produce the maximum return on the investment…is a problem that must be JOINTLY SOLVED BY THE SUPPLIER AND USER.
It is the purpose of this paper to describe the possible combinations available and some of the economic aspects of these packages, thus to aid both the supplier and user in the evaluation and selection of the BEST POSSIBLE PACKAGE for a particular application or the BEST COMBINATION OF PACKAGES to solve a general overall problem. Pictures.. flow diagrams… brief descriptions of the processes. background information necessary to intelligently evaluate each problem…and studies of three different randomly selected streams as applicable to each piece of equipment…are included in this paper.
This presentation deals with no detailed computation of payouts on any particular piece of equipment. There are far too many variables involved in these computations. It is felt that if inappropriate assumptions were to be made to arrive at payouts, in some cases this could discourage application of equipment that might actually provide an attractive payout.
The packages discussed on the subsequent pages are presented in the form of BUILDING BLOCKS. It is hoped that some of the information presented in this paper will discourage OVERBUYING OR OVERSELLING of equipment. Either one of these policies on the part of either the user or supplier can and does detract from the overall progress of the industry. USERS AND SUPPLIERS WORKING AS A TEAM must continue to make progress in the future as they have in the past in their efforts to utilize economically the valuable hydrocarbons that exist in the gaseous streams before the gas itself is consumed. Day-by-day as the demand for hydrocarbons accelerates, THE PRESSURE WILL INCREASE TO SEPARATE MORE EFFICIENTLY AND CONSERVE these valuable components that are becoming so VITAL IN THE PETROCHEMICAL, AVIATION, REFINERY, GAS TRANSMISSION, AND OTHER INDUSTRIES.
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Effect of Complex Fluid Phase Behavior on CO2 Flood Simulation
Authors: Fanchi J. R. 
Published: December 2007

ABSTRACT
Evidence of complex phase behavior has been observed in many CO2-hydrocarbon systems at relatively low temperatures (about 100°F). The phase behavior includes two hydrocarbon liquid phases and a vapor phase. In some cases a hydrocarbon solid phase (a precipitate) is observed. Combining these four phases with an aqueous phase suggests that accurate modeling of a CO2 flood should account for five phases. From a practical perspective, the input data and computer requirements of such a simulator would be extensive, and could be excessive.
An attempt to evaluate the expected effect of an additional hydrocarbon phase on CO2 miscible simulation was made using a four-phase (no solid phase) simulator. Three CO2-hydrocarbon systems were evaluated. It was found in the cases studied that the presence of two hydrocarbon liquid phases, under optimum conditions, changed the recovery factor by only a few percent.