bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Packer Design Offers Completion Flexibility in Thermal Completions, ESP, Downhole Monitoring Systems, and Annular Safety Systems: Case Histories
Authors: White P. M. , Restarick Henry , Setterberg J. R. 
Published: December 2007

ABSTRACT
The economic climate of the oil and gas industry has continued to decline over the last decade, increasing the need for operators to find newer operational strategies that will enhance efficiency, and subsequently, stimulate economic recovery. Production technology has responded to these needs by continually improving completion technology. This paper will present one of the new technological advances, a variable-bore packer, that supports current oil field needs by providing operators with a new concept in completion configuration flexibility.
Several case histories will be included in the paper and will outline applications using the new packer.
These case histories involve:
An electric submersible pump completion in which one bore was provided for production and one for electric cable penetration. Running dual production strings in a steam injection, enhanced-oil-recovery well. Use of packer as a single-bore production packer with three monitoring line ports for pressure and temperature surveys. Use of the packer as an annular safety valve packer in the North Sea.
The case history data will verify the operational simplicity, versatility, and reliability of the new packer and how its unique flexibility supports the current needs for greater operational efficiency.
Extended Reach, Horizontal, and Complex Design Wells: Challenges, Achievements and Cost-Benefits
Authors: Blikra Harald , Drevdal K. E. , Aarrestad T. V. 
Published: December 2007

ABSTRACT
The paper describes Statoils experiences in drilling extended reach (ERD) wells, to primarily serve remote parts of widespread reservoirs and experiences in drilling horizontal and complicated wells, specially designed for optimal drainage of complex reservoirs. Several world records in exteded reach drilling, conducted from the Statfjord "C" platform are summarized. The latest ERD well drilled has a horizontal reach of 7290 m.
Included are also the latest plans of implementing these technics in developing new fields.
A brief summary is given on the achievements within the industry regarding other special well types, such as dual lateral, snaky, multiple arm, etc.
Furthermore the paper describes technical challenges of drilling complex wells and how planning is done to cope with these challenges.
Some limitations to the drilling are highlighted and solutions to drilling problems related to torque, drag, buckling, hole cleaning and surveying are given.
Cost-Benefit considerations regarding ERD, horizontal and complex wells are discussed.
Reducing number of platforms and/or leave out subsea templates due to ERD wells are considerable cost reducing factors.
Reducing the total number of wells from a platform due to horizontal and/or complex well profiles is another major cost reducing factor.
Reservoir Simulation Using a General Processor and an Array Processor in Parallel
Authors: Johnson Olin G. 
Published: December 2007

Johnson, Olin G., IBM Scientific Center

Abstract
In this paper, we describe an array or vector processor that, with only one basic arithmetic operation, can be used in parallel with a central processor for numerical reservoir simulation. In doing so, we demonstrate a partitioning of the problem to balance the partitioning of the problem to balance the computational load between the processors under the constraints imposed by the instruction sets and the relative speeds. We also discuss certain mathematical aspects of the partitioning and the iterative algorithms. Finally, we present results from numerical experiments using present results from numerical experiments using the IBM 2938 Array Processor with an IBM 360/85, 75, 65 or 44.
Index Terms for IBM Subject Index
Array Processing Mathematics Reservoir Modeling Numerical Analysis ADI Computer Applications SOR IBM 2938

Introduction
Much has been written recently in the area of parallel computation. Some problems have been attacked by using several identical general purpose processing units sharing a common purpose processing units sharing a common memory bank. Other problems have motivated the design of some highly parallel, special purpose arithmetic units arranged in two-dimensional arrays, each with its own memory and each with the ability to communicate with some of its neighboring units.
In this paper, we consider a very elementary type of parallel computation that is a combination of these two types. The idea is to augment a general purpose computer with an auxiliary arithmetic unit of special type. The computational objective is to place a large part of the computational load arising out of problems such as numerical reservoir simulation in problems such as numerical reservoir simulation in the special unit. This objective dictates that the unit be floating point and operate at high speed on vectors and band matrices. The economic objectives are to create a system that is much less expensive than two general purpose central processing units and that is several times as fast as a stand-alone central processor. processor. In particular, we show that if the auxiliary arithmetic unit, which we will henceforth call the array processor, contains only one basic vector function, then we can construct a parallel algorithm for reservoir simulation. parallel algorithm for reservoir simulation. Further, we have implemented this algorithm on an IBM 360/44, 65, 75, 85 with an IBM 2938 array processor and we present numerical results from processor and we present numerical results from these programs. In Section 2, we give a functional description of the array processor. In Section 3, we identify the basic computation kernels in a standard reservoir model.
A Study of Water Coning in the Oil Creek Reservoir, North Antioch Field, Oklahoma
Authors: Cutler J.M. , Rees W.A. 
Published: December 2007

Abstract
In reservoirs with bottom-water drives, water coning has historically been a producing problem. Prior to the use of high-speed problem. Prior to the use of high-speed computers, the coning problem practically defied solution. This paper discusses a study of water coning in the Oil Creek reservoir of the North Antioch field, which was made utilizing an r-z, two-phase compressible coning model. The model matches water-cut history and predicts future performance. The study points up the importance performance. The study points up the importance of variation in vertical permeability on the coning phenomenon. More particularly, it shows the effects of a continuous 4-ft zone of low permeability which occurs in the reservoir. permeability which occurs in the reservoir. Coning characteristics of wells in which the original oil-water contact was located above the zone are compared with those in which the original contact was below the zone. The study indicated that the reservoir could safely be produced at rates that would greatly increase produced at rates that would greatly increase the present worth value of the reserves without materially affecting the ultimate recovery.
Introduction
The North Antioch field is located in the northwest part of Garvin County, Okla. The field was discovered in May, 1965, with the drilling of Coastal States' J. R. Winchester No. 1. As the field developed, it became obvious that the oil reserves in the Oil Creek reservoir were of substantial proportions. Development was essentially complete by Oct., 1966. Because of a rather unusual combination of reservoir and fluid characteristics and the obvious possibilities for increasing recoverable reserves, possibilities for increasing recoverable reserves, reducing costs and increasing present worth value through proper operation, the decision was made to utilize some advanced forms of reservoir modeling to predict the results of various possible methods of operation of the field. This paper presents the results obtained from modeling and recommendations for future operations in the field.
RESERVOIR CHARACTERISTICS
The Oil Creek reservoir of the North Antioch field is made up of approximately 108 ft of fairly uniform and clean Ordovician sandstone found at a depth of approximately 6,500 ft subsea or 7,500 ft subsurface. Through coring and analysis of logs, it was determined that the average porosity and permeability of the sand are 17.32 percent and 350 md, respectively. Fig. 1 is a portion of a typical electric log of the Oil Creek sand in the field. Table 1 shows the results of core analysis on two cores taken from the Oil Creek reservoir. The most striking of the characteristics of the sand is its uniformity as indicated by the SP portion of the log and the core analysis. There is one noticeable exception to the uniformity and that is the portion marked "barrier" on Fig. 1. portion marked "barrier" on Fig. 1.
S.S. Manhattan's Northwest Passage Voyage
Authors: Fuson T.J. 
Published: December 2007

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
This paper begins with the discovery and prior knowledge of oil on the North Slope of prior knowledge of oil on the North Slope of Alaska. A discussion of the hostile environment and the problems it generates is included.
The need for transporting the oil to the U.S. East Coast market is emphasized. A number of alternative transportation routes are mentioned before arriving at the three basic alternatives:Pipeline across Alaska — tankers to the Puget Sound area — and then by U.S. Transcontinental pipeline to the East Coast,Pipeline from the North Slope directly across Canada to the Eastern part of the U.S., andIcebreaking tankers eastward through the Northwest Passage.
The first two of the above are discussed briefly prior to going into the heart of the paper the full scale icebreaking tanker paper the full scale icebreaking tanker test by the S.S. MANHATTAN.
The discussion of the MANHATTAN begins with a brief history of the research which went into the decision to try a full scale test. The objectives of the test and the ship modifications are explained. Emphasis is on the collection of scientific test data to facilitate the design and to determine the economic feasibility of icebreaking tankers.
The presentation is concluded with a 12-minute film taken in the Northwest Passage.

TEXT
I'm very happy to be here today to discuss with you the voyage of the S.S. MANHATTAN through the Northwest Passage and why we did it.
The "why" of it all, of course, is the discovery of oil on the North Slope of Alaska. Conservative estimates indicate there are five to ten billion barrels of oil there potentially the biggest discovery on the North American continent. Like so many other oil discoveries, it lies in a region where it is expensive, inconvenient, and difficult to operate.
The Use of Hot Gas Injection for the Recovery of Sulfur from Thin Deposits
Authors: Barnes A.L. 
Published: December 2007

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
An analysis of the use of hot inert gas for the exploitation of thin sulfur deposits was made. This analysis included theoretical heat transfer and economic investigations. The heat transfer study involved the numerical solution of equations written in cylindrical coordinates describing convection-conduction heat transfer in the zone of gas flow and conduction heat transfer in the bounding media. Of particular interest in this work was the volume of rock swept by the 250 degrees F and 350 degrees F isotherms. This is because sulfur becomes liquid at 250 degrees F but loses its mobility again at 350 degrees F.
Results showed there is probably sufficient time for sulfur movement before arrival of the 350 degrees F isotherm. The volume of rock traversed by the 250 degrees F isotherm was found to be almost porportional to the heat-injection rate. It was porportional to the heat-injection rate. It was found that injection temperatures would have to be in the 1000 to 1500 degrees F range for economic heat transfer by gas.
An economic study indicates that a hot gas drive process for sulfur production could be economical providing that a recovery efficiency greater than 50 percent could be achieved in a bed containing 25 percent sulfur. Pilot testing would be required to develop appropriate production techniques. A combination inert production techniques. A combination inert gas-water-steam process might prove superior to straight gas.

Introduction
The Frasch process has been used since the turn of the century for the insitu recovery of elementary sulfur. Favorable economics for the Frasch process depend on shallow thick deposits because it involves water injection and water and sulfur production through the same well. Therefore, the exploited zone for each well is of limited areal extent. The Frasch process also needs large quantities of water requiring a minimum amount of chemical treatment. The process, therefore, cannot be used economically to exploit many relatively thin deposits (less than 100 feet thick) especially in areas where large quantities of water are not available or require prohibitive water treatment. prohibitive water treatment. No other methods have been developed to economically exploit thin sulfur zones where operating costs are high because of the water costs. At least two processes or combinations thereof might be considered to recover elementary sulfur from thin beds. These are the injection of either (1) hot inert gas or (2) steam into certain wells and production of either inert gas and sulfur or water and sulfur from others.
A Mechanistic Model for Cuttings Transport
Authors: Clark R. K. , Bickham K. L. 
Published: December 2007

ABSTRACT
A cutting generated at the bit may be transported to the surface by several different mechanisms as it moves along the wellbore. The specific mechanism depends on the wellbore angle. For high angles, where a stationary cuttings bed can form, transport is via a rolling mechanism. In intermediate angles, where a churning, moving cuttings bed can form, transport is via a lifting mechanism. At near-vertical angles, particle settling determines transport. The model described below combines fluid mechanical treatments of these mechanisms into a format for easy analysis of cuttings transport in wells of any configuration.
The Development of a Fracture-Resistant PDC Cutting Element
Authors: Cooley C. H. , Meany Nigel 
Published: December 2007

ABSTRACT
The incorporation of buttressed edge geometry has led to the development of a new cutting element that has significantly improved the performance and economics of PDC drill bits. These improvements result because of enhanced cutter durability and the resulting consistency in drilling performance in applications where cutting elements are subjected to high impact loads i.e. hard formations, dynamically unstable drilling, highly interbedded formations, etc.
This paper describes the development of a durable polycrystalline diamond cutting element. The durability of the new cutter is a direct result of its unique frustoconical shape, which is engineered to reinforce the diamond table against impacts occurring parallel to the primary motion of the cutter.
Similar cutter geometry modification has previously been employed in the machine tool sector, but until now, has found no application in the petroleum drilling industry. This paper demonstrates how the same techniques have been applied to petroleum drill bits to clearly improve the life of PDC cutting elements.
Finite element analysis (FEA) and laboratory and field experimental tests are explained and results presented to illustrate the superior strength and durability of the buttressed geometry when compared to standard cutters of right circular cylinder geometry. FEA results demonstrate a 50% reduction of damaging tensile stresses in the diamond table and supporting tungsten carbide.
Laboratory test results demonstrate that buttressed cutters survive loadings that consistently destroy conventional cutters and that penetration rate is not reduced provided the cutter backrake is properly selected. Also, these experiments show the conventionally held practice of increasing backrake in harder rock drilling actually weakens the cutter unless buttressing is incorporated.
Field test results from the Denver-Julesberg Basin of Colorado, South Texas, and Colombia are presented and discussed to demonstrate how the new cutter is significantly improving bit life while maintaining the penetration rates of conventional cutters.
Issues and Techniques of Plugging and Abandonment of Oil and Gas Wells
Authors: Calvert D. G. , Smith Dwight K. 
Published: December 2007

Abstract
In the oil industry today there are over 600,000 producing wells, all of which will be plugged at some time in the future. Annually, approximately one-third of all oil and gas wells drilled are dry and require plugging in the abandonment process. Unless required by law, most abandonment plugs are not checked for their location and are assumed to have been properly placed. Thirty-four of the 50 states in the US have plugging rules governing the techniques for plugging and abandonment of various wells. Written over a long period of time and by varying regulatory agencies, wide variations exist in these rules. Outside the oil and gas industry, wells are drilled for industrial, disposal, and seismic purposes, freshwater production, and solution mining. All of these wells may have differing or nonexistent abandonment rules. Some states require strict procedures for abandonment of oil and gas wells, but have few or no regulations or requirements for other wells, even though these wells encounter the same freshwater formations.
This paper reviews the latest recognized techniques for plugging and abandonment, and highlights the states having the most desirable rules for plugging to preserve freshwater horizons. The paper highlights poor techniques and practices used for plugging holes, and discusses troublesome areas such as wells that are not properly plugged and abandoned. The paper presents the issues of plugging and abandonment of wells including materials, techniques, plug testing, and regulatory requirements.
A Methodological Approach for Reservoir Heterogeneity Characterization Using Artificial Neural Networks
Authors: Mohaghegh Shahab , Arefi Reza , Ameri Samuel , Hefner M. H. 
Published: December 2007

ABSTRACT
For the past few years Artificial Neural Networks (ANN) have made a strong comeback to the scientific community. They are used in a variety of tasks where adaptive computing can enhance process performance. There has been a handful of papers suggesting the use of artificial neural networks in the petroleum industry1-3. These papers can be classified into two major categories. First category includes papers that recommend the use of ANN in classification of lithologies from well logs. Second category includes papers that employ ANN to pick the proper reservoir model for well testing purposes.
This paper introduces a new implementation of the neuro-computing technology in petroleum engineering. It is shown in this study that artificial neural networks possess numerous capabilities, and can be much more useful to petroleum engineers than previously thought. An implementation of artificial neural networks in characterization of reservoir heterogeneity is presented in this paper. A methodology is introduced through which different rock properties in highly heterogeneous reservoirs can be predicted with good accuracy using information deduced from geophysical well logs. Examples of such networks are presented using field data for verification.
The underlying reasons (theories) that make achievement of such complex tasks possible are discussed. The notion that artificial intelligence and neural networks in particular have immense potentials in solving complex engineering and scientific problems are addressed. The innovation now lies on the creativity of the researchers to recognize and define petroleum engineering problems that can be addressed by artificial intelligence technology.
Field Performance Of New Technique For Control Of Water Production Or Injection In Oil Recovery
Authors: Koch Ronney R. , McLaughlin Homer Charles 
Published: December 2007

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
Many successful field treatments to change injection profiles in waterflood injection wells have been performed. A new treating technique, which in most cases does not require zone isolation, has been developed and utilized in a large number of the treatments presented in this paper. Results of presented in this paper. Results of treatments performed indicate that inexpensive, inorganic gel forming materials can produce satisfactory results if they are injected so that deep formation penetration is achieved.
Field results have also shown that the same inorganic gel forming materials can be applied, with slight modification of the new treating technique, to help eliminate or substantially reduce water production in primary depletion wells for a considerable primary depletion wells for a considerable length of time. Such results indicate that the materials and techniques may be applied to control water breakthrough problems in waterflood producing wells.
Gel times of the materials are flexible, providing placement times from a few minutes to providing placement times from a few minutes to several hours. Slurries of the materials can be made for use as a tail-in material where fractures and vugs exist.
Use of the materials and techniques developed in these treatments provides a low cost method for altering injectivity profiles in waterflood injection wells as well as an economical method for controlling water production in primary depletion wells. production in primary depletion wells

Introduction
Directing the injected water in waterflood injection wells so that the floodwater is distributed in the zones containing most of the remaining oil in place has long been a challenging problem in waterflood operations.
At various intervals in the life of a flood program, it may be most economical and desirable to redistribute the floodwater to enter other zones. Controlling the fluid allotment into each formation strata may pose a costly operation if a rig or expensive downhole equipment is used. Furthermore desired results may never be seen in the producing wells. Usually, the zones of highest producing wells. Usually, the zones of highest permeability accept the floodwater first. permeability accept the floodwater first. When breakthrough occurs in such cases, much oil in place is bypassed in zones of lesser permeability. permeability.