bluuebunny/crossref_metadata_2025_split huggingface dataset:
Design, Performance, and Evaluation of the Uniflood Micellar-Polymer Process—Bell Creek Field
Authors: Holm L. W. 
Published: December 2007

ABSTRACT
Gary Energy Corporation conducted a DOE cost-shared 40-acre Demonstration Pilot project to determine whether or not micellar-polymer flooding is a feasible technique to enhance oil recovery from the Bell Creek Field, Montana. The regular line drive waterflood in Unit ‘A’ on 40-acre spacing was terminated in the pilot area in October 1976 when it reached its economic limit according to oil prices and operating costs in effect at that time. The 40-acre pilot 5-spot was developed by infill drilling four injection wells in 1977; thus, the 40-acre pilot is embedded in a 160-acre (9 producers) drainage area located in a waterflooded portion of the Unit ‘A’ reservoir. The reservoir is sandstone with an average net pay of 6.4 feet, air permeability of 1050 md, and water TDS of 3500 ppm.
Water injection into the new 40-acre 5-spot pilot pattern began in October 1977 and was to be followed immediately by the micellar-polymer process. However, the complex reservoir definition work extended this pilot 5-spot waterflood to fifteen months, through January 1979. The micellar-polymer (Uniflood) process commenced in February 1979 with preflush injection (16.4% PV); micellar slug injection (3.8% PV) began August 1979 and polymer injection (100% PV) began October 1979. The average remaining oil saturation in the 40-acre was estimated to be 30.5% at the start of chemical injection.
This paper includes a summary of the micellar-polymer process design, the micellar-polymer oil recovery results projected to project completion, an analysis of the geology and fluid chemistry within the pilot area, and an interpretation and evaluation of the overall performance of the project.
The oil recovery results for the 40-acre 5-spot pilot project are given below for two time frames, necessitated by the 15 month infill 5-spot waterflood. From the start of the micellar-polymer process injection, February 1979, through its projected completion in December 1983; Tertiary oil recovery is projected to be 33.6% of the oil in place as of February 1979.The chemical efficiency of the process is projected to be 11 pounds of sulfonate per barrel of oil recovered.From the start of the infill 5-spot waterflood injection, October 1977, to micellar-polymer process completion in December 1983; The total oil recovery from the 40-acre area is projected to be 45% of oil in place as of October 1977.
A high pH preflush and the use of a chelating agent in the micellar slug minimized the effects of the multivalent ions present in the reservoir. Also, adjustments in the components used in the soluble oil slug made it possible to regain a favorable phase relationship with the reservoir fluids despite the lower-than-design quality sulfonates.
Predicting Reserves And Performance Of A Peripheral Waterflood
Authors: Cowan Robert W. , Guerrero E.T. 
Published: December 2007

Publication Rights Reserved

Abstract
A method to predict the reserves and performance of a waterflood utilizing peripheral injection is developed. It is a modification of the method used by Prats, et al. to predict the reserves and performance of a five-spot waterflood system. Both theoretical and experimental work are involved in the procedures.
Experimental data obtained by Prats, et al. for the five-spot system and by Dyes, Caudle, and Erickson for a direct line drive system were modified for use in the peripheral system. Theoretical procedures are used to predict injectivity prior to fill-up. After water breakthrough, injectivity is predicted from experimental data. The method presented is believed to be more accurate for predicting reserves and performance of a peripheral waterflood than methods utilizing a constant injection rate or methods not considering the buildup of an oil bank ahead of the water front.

Introduction
Waterflooding by peripheral injection is becoming more common. This is due, in most cases, to allowable restrictions or to the practice of initiating water flooding in the early life of a field to maintain pressure at an optimum point. If a sufficient rate of water injection can be maintained through a peripheral system, it will usually be selected over a pattern type system because of the lower initial investment and operating expense. A review of material available, both analytical and empirical, to assist in the prediction of waterflood performance indicated that a wealth of information 3,4,5,6,7,8,9,10,11,12,13,14 had been published on the five-spot pattern waterflood but very little 15,16 was available on the peripheral system. It was decided to determine if some of the material available on the five-spot could be modified for use in the peripheral system.

METHOD OF PRATS, MATTHEWS, JEWETT and BAKER
Prats et al devised a comprehensive method of predicting the reserves and performance of five-spot waterfloods. Their method takes into consideration more variables than most other accepted methods and was therefore selected for modification to enable prediction of reserves and performance of a waterflood utilizing a peripheral injection system.
Prats et al. based their method on being able to accurately predict injection rates over the life of a waterflood. Both theoretical and experimental work were performed to develop a method for computing injection rate. This method not only assumes that injection rate into a layer is proportional to the permeability capacity, but also takes into account the effect of the water and oil banks and the fluid mobilities within each of the banks. It involves primarily the prediction with time of the rate of injection into and the type of production from each individual layer.
A Further Analysis of the Steam Stimulation of Heavy-Oil Wells and Reservoirs
Authors: van Lookeren J. 
Published: December 2007

ABSTRACT
The application of steam stimulation of wells in oil fields in Venezuela and in the U.S.A. has a history of more than 20 years. Some of the more critical aspects of production rate increase and increase of ultimate recovery of heavy oil have been reconsidered. The earliest large scale project in Venezuela has produced since 1964 with much additional oil and is still producing economically. Its performance analysis has shed some light on reservoir compaction and solution gas drive as drive mechanisms in heterogeneous sands. Applications of steam stimulation with different drive mechanisms such as steamdrive, waterdrive and gravity drainage, have been carried out. Parameters affecting production rates and the decline rates are now better defined and quantified. Obviously injection of steam in wells for production can stimulate both well PI's and oil producing mechanisms.
Approximate steam-soak well models taking into, account stimulation of reservoir mechanism are made and represented by simple mathematical expressions for use in practical planning systems and reservoir performance simulations.
Dynamics of Moving Interfaces in Porous Media: II. Pistonlike Displacement
Authors: Kale Dilip M. 
Published: December 2007

ABSTRACT
A fluid-fluid interface is formed when oil in porous media is displaced by another fluid, say water, in a pistonlike manner. This interface is in the shape of a closed curve surrounding the injection well. The exact manner in which the size and shape of this interface changes with time depends upon the well configuration, rates and the mobility ratio. A general method for tracing the time development of such an interface is presented in this paper.
A complex velocity potential for the flow at any instant is expressed by the superposition of the potentials due to the sources (injection wells), sinks (production wells) and the vortex sheet developed along the interface. Vorticity along the vortex sheet is obtained as a solution to an integral equation derived in the previous paper. From the complex velocity potential the velocity field in the flow region at that instant is known. Then by using Kelvin's relation for the motion of a surface in a moving fluid the progress of the interface for small time interval δt is traced. By repeating these steps the complete time development of an interface is traced.
An impervious no-flow boundary affects the flow and thus contributes to the velocity potential. Across this boundary the mobility ratio is infinite since the mobility in the exterior region is zero. The contribution to the complex velocity potential of such a boundary is accounted for by replacing it with the appropriate vortex sheet.
The working of the method is demonstrated by implementing the calculation scheme for some simple patterns such as two spots and five spots. The results obtained are in good agreement with the known analytical results for the case of unit mobility ratio and with experimental results for other mobility ratios.
Santa Rosa Tar Sands Project
Authors: Randall John S. 
Published: December 2007

Abstract
The Santa Rosa Tar Sands Project involves strip mining of a surface deposit of oil impregnated sandstone at Santa Rosa, New Mexico. The ore is delivered to an extraction plant where it is crushed and the oil extracted using solvent and hot water. A clean damp sand residue is to be returned for back filling the mine (apart from the flue gases involved in untility requirements).
The Use of Supercomputers in the Search for Oil
Authors: Yang Rosa L. 
Published: December 2007

Abstract
Over the last decade, there have been significant advances made in the geophysical processing and reservoir simulation techniques. With these advances comes a rapidly increasing computing power requirement -- especially in the areas of 3-dimensional seismic processing and reservoir simulation model studies. In response to this need for high computing power is the development and application of supercomputers for the energy problem solution. The use of supercomputers is now required in both the exploration for and the exploitation of oil and gas worldwide.
Enhanced Oil Recovery Data Base Analysis by Simplified Predictive Models
Authors: Ray R. M. , Wesson T. C. 
Published: December 2007

Abstract
The U.S. Department of Energy, Bartlesville Energy Technology Center (BETC), has been developing computerized data bases and simplified predictive models to be used to predict enhanced oil recovery (EOR) potential in the U.S. The development phase of this work is nearing completion whereupon the models and data bases will be made available to the public.
This paper describes the overall development phase for the models and data bases with analyses of selected EOR projects using the predictive models. Examples of model outputs are discussed and brief descriptions of the predictive algorithms are given.
Prospects for Gas Imports in the U.S. Energy Market
Authors: Burns David H. 
Published: December 2007

Abstract
In addition to domestic considerations, future levels of gas imports into the U.S. market will be shaped to an important extent by the policies of gas exporters. Exporters must understand that the U.S. will remain one of the world's major gas producers for the foreseeable future and that U.S. import needs will be modest in relative terms compared to those of other industrialized countries. The history of U.S. gas imports from Canada and Algeria makes clear that imported gas must be competitively priced with other available energy sources and that market forces will be a central element in determining the level of imported gas.
Comparative Analysis of Coverage for Oil and Gas Loans
Authors: Castle G. R. 
Published: December 2007

Abstract
One very important task in connection with any oil and gas loan is to determine a loan value and structure the terms in such a way that the property supporting the loan provides an adequate coverage to assure a payout for the lender. After the lender has completed the analysis or appraisal of the reserves and prepared a revised projection based on the lender's own assumptions, most banks use that revised projection as a basis for computing various coverage ratios and tests in order to determine whether the property is adequate collateral for the loan. This paper shall examine on an anonymous basis a sample of 15 oil and gas loans that have been made within the last two years in an attempt to provide insite into what the current standards are for this type of loan.
For the purposes of this analysis eight different commonly used ratios and other tests have been computed for each of these 15 sample loans and the results of these computations have been summarized on Tables I and II. All of the loans chosen for this sample have been syndicated among a banking group, and in each loan the banks have assumed the project or reserve risk. In the computation of these ratios, no attempt has been made to revise the projections that have been furnished by the borrower (in the Information Memorandum) for each of these loans except that all interest computations and present values have been determined at a rate of 14% per annum. As a result, the comparisons shown on Tables I and II may be distorted to some extent by any variation in the assumptions that have been made in the preparation of the economic projections for each of these 15 sample loans. However, later in the conclusion section of this paper there is a discussion of the sample loans in order to point out any assumptions that differ in a significant way from the normal criteria that most banks require in connection with this type of loan.
In the next section there is a definition of the way that each of these ratios has been computed.
Econometric and Resource Modeling Methodology for Projections of Cost of Development of U.S. Natural Gas Potential
Authors: Gangwar Anshumali , Kent H. C. , Schuenemeyer J. H. , Guzman Jaime , Snow Stuart 
Published: December 2007

ABSTRACT
Periodic estimates of the quantity and geographic location of the potential natural gas resources remaining to be discovered, developed and produced in the United States have been made by the Potential Gas Committee, These estimates, however, cover a wide range of geographic conditions, depth subdivisions and variations in the cost of exploration and drilling. The principal objective of this study, sponsored by the Gas Research Institute and the Electric Power Research Institute, is to develop an econometric and resource modeling methodology to evaluate the relative costs of development of the natural gas resource potential which has been estimated by the Potential Gas Committee, and to present these relative cost data in such a way that meaningful comparisons can be made between alternate resources of natural gas. The economic investigations in this study have been concentrated upon two main components: a drilling cost model and a discovery process model. A modification to a previously developed model has been prepared to estimate the discovery rates of natural gas based upon the Potential Gas Committee estimate of ultimate natural gas resource and the previous exploration history (actual or analog) of a geological province. The econometric model will be calibrated by comparisons with the subjective estimation of resource distribution by Potential Gas Committee members, and a consensus discovery rate would be derived. The drilling cost model will be used to translate the exploratory and development efforts into present constant dollars.
Forecasting Supplies of Oil and Gas from America's Offshore Frontier Areas
Authors: Janney Asa M. 
Published: December 2007

Abstract
The Frontiers Model was developed by ICF Incorporated1 to forecast oil, natural gas, and natural gas liquids production from federal offshore areas in Alaska and along the Atlantic and Pacific Coasts. The Frontiers Model forecast does not include future discoveries of proved reserves in the Gulf of Mexico because many other forecasts for that more mature offshore area are available. However, just as production of hydrocarbons, particularly natural gas, from the Gulf of Mexico have become a significant fraction of total national production, the vast, relatively unexplored offshore frontier areas could become an important source of the country's future energy needs.
Problems in the Natural Gas Industry—Causes and Responses
Authors: May H. S. , Mathews C. D. 
Published: December 2007

Abstract
There is general agreement that the natural gas industry currently faces serious problems. Historically, this is not surprising. Natural gas has long been the subject of regulatory and legislative adjusting, fixing and tinkering. The current public debate over natural gas, however, is distinguished by much disagreement as to just what problems the industry faces and, not surprisingly, what the appropriate remedies might be.
This paper will attempt to identify and describe the problems currently confronting the natural gas industry. The paper will comment on the legal and policy implications of these proposed remedies. Finally, it will outline regulatory and legislative solutions now being considered by Congress.
Operator/Contractor Relationships—The Consultant's Role
Authors: Beall J. E. 
Published: December 2007

Abstract
For about $10 anyone can become a drilling consultant. That's how much it costs to print a name and the word "consultant" on a business card. If one has a telephone and a few idle friends he might have the card printed with the words "Drilling Consulting Company". There are at least 110 companies registered in oil industry directories in the Gulf Coast area alone offering drilling consulting services.
How does one qualify to become a drilling consultant? There is no formal examination, no licensing procedure, no code of ethics nor any standards for professional practice. Not a single drilling consulting company is a member of ACME, the Association for Consulting Managing Engineers.
Without any professional society or other mechanism for policing itself, the drilling consulting industry has earned a widespread reputation for greed and incompetence. The drilling boom of 1976–1981 attracted many people into consulting whose only qualification was their willingness to endure isolation at the well site for long periods. Many of these people lacked the tools to manage, engineer or supervise a safe, cost effective drilling operation. Many misrepresented their capabilities when selling their services. A few compounded this dishonesty with kickbacks and thievery.
The Minimum Area Rig Concept—A Unique Bootstrap Drilling Rig
Authors: Kerry C. W. , Lynch S. C. , Armstrong J. E. 
Published: December 2007

Abstract
The Minimum Area Rig Concept (MARC) is a cost-effective alternative to the typical self-contained platform rig. The MARC rig has been developed to provide a 16,000-ft rated drilling rig which can rig up in a limited area of approximately 75% of the original platform drill deck. The rig can also be moved without a derrick barge. The MARC rig was designed by an engineering consultant and is being built to drill and workover wells for ARCO Oil and Gas Company (ARCO) in the Gulf of Mexico, starting in the South Pass Block 61 field.
Long-Range Planning Assures Success of Bering Sea Drilling
Authors: Lewis S. K. 
Published: December 2007

ABSTRACT
To successfully drill in remote and harsh environment areas, a wide variety of specialized equipment, material and personnel must be mobilized in an orderly manner. Long-range planning consisting of environmental assessment, engineering studies, logistical analysis, equipment selection, and operations scheduling must be accomplished prior to operations. ARCO Alaska, Inc., utilized long-range planning methods in preparation for a three-well Bering Sea drilling program.
Blowouts—A Computer Simulation Study
Authors: Thomas D. C. , Lea J. F. 
Published: December 2007

ABSTRACT
A computer simulation study of blowouts was made using a program written earlier. This study shows the predicted effects of various sized kicks on a given wellbore configuration and studies the major variables affecting kick severity in both water- and oil-based muds. The variables include reservoir variations (pressure, permeability, porosity, temperature) and pumping rate at the surface.
Results are shown for the effects of each of these variables on an uncontrolled kick. The present program does not include control procedures but does include some examples of flow through a choke. It was intended to show what might happen if no control procedures were initiated and to study the lower limits of kick detectability. Practices are suggested that should make earlier detection of a kick possible so that conventional kill procedures will be more effective. Blowout simulations suggest that pit gain is the most reliable indicator of a kick. It is recommended that pit level measurement systems, capable of detecting a pit gain of less than 5.0 barrels in the entire active mud system, be developed and be used where high pressure kicks are common.
Calculation of NMDC Length Required for Various Latitudes Developed From Field Measurements of Drill String Magnetisation
Authors: Grindrod S. J. , Wolff J. M. 
Published: December 2007

ABSTRACT
One possible source of error in magnetic surveys is ill based charts used for selecting the required length of non-magnetic drill collar (NMDC). Based on theoretical considerations and measurements of pole- strength values in the field, well-defined charts can be constructed for the selection of the minimum required NMDC length for a specific bottom hole assembly and acceptable azimuth error.
Design and Application of Softer Formation Tungsten Carbide Rock Bits
Authors: Newman E. F. 
Published: December 2007

ABSTRACT
Life of the tungsten carbide tooth rock bit was greatly increased by the introduction to the industry of the O-ring sealed journal bearing design in 1969. With this development greater emphasis was then placed on cutting structure development. Innovative tooth shape designs and metallurgical improvements have allowed the application of carbide tooth rock bits to be extended into softer and softer formations.
Continued bearing development has resulted in more consistent bit performance and a greater tolerance for higher rotary speed. This and the introduction of softer carbide tooth cutting structures have provided the impetus for the industry conversion from steel tooth to carbide tooth rock bits. J22 class bits (IADC Code 5-1-7) have proved to be economical in a wide range of soft formations. Performance from the new J11 class bits (IADC Code 4-3-7) also shows promise of improving the economics of drilling even softer formations. Drilling rates in excess of 100 feet per hour have been obtained in some applications. The design, development, and application of these new products will be discussed in this paper.
Cleanup of Oilfield Wastes in an Environmentally Acceptable Manner
Authors: Wentz C. A. , Shiver C. M. 
Published: December 2007

Abstract
Treatment and disposal of drilling muds and hazardous wastes has become a growing concern in the oil and gas industry. Present disposal methods are either environmentally ineffective or increasingly expensive to use. Society's environmental protection opinions as well as rising trucking costs indicate a need for more effective and economical methods. Newpark waste treatment systems has developed an innovative technology which through field testing has proven to be both cost effective and environmentally acceptable.
Optimizing Motor Drilling System
Authors: Emery M. M. 
Published: December 2007

Abstract
A systems approach to downhole motor drilling is a key concept in optimizing motor performance in extended interval drilling applications. Understanding the interplay of system variables, including bits, motor, stabilization and hydraulics, is the springboard to planning and implementing a motor drilling system for optimum results. Computer programs have recently been developed to facilitate more comprehensive analysis of system hydraulics, to pinpoint possible problem areas and to access motor performance.