bluuebunny/crossref_metadata_2025_split huggingface dataset:
Correlation of Friction Factors for Viscoelastic Fluids in Tubes
Authors: Kilbane J.K. , Greenkorn R.A. 
Published: December 2007

This paper was prepared for the Society of Petroleum Engineers Symposium on Mechanics of Rheologically Complex Fluids, to be held in Houston, Tex., Dec. 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
This paper proposes a friction-factor correlation for turbulent flow of viscoelastic fluids in tubes. The correlation is a generalization of the Blasius form such that
........................................(1)
where f is the friction factor and K is a parameter for the particular fluid. N'Re is the Reynolds number generalized from the Oswald-deWaele model
........................................(2)
where D is tube diameter, V is bulk velocity, rho is density, K' and n' are the consistency variable and the flow behavior index, respectively. f" is the friction factor predicted from the correlation of Dodge and Metzner for a given value of n' and a modified Reynolds number [1 + NWs] N'Re where NW, is the Weissenberg number. The correlation fits existing viscoelastic data within an average of 8 per cent.

Introduction
There are many fluids which do not follow Newton's law of viscosity. These fluids are broadly classified as either purely viscous non-Newtonian or viscoelastic. Three approaches are used to develop predictive techniques for the flow of these complex fluids:
the phenomenological approach, where one correlates semi-empirical functions with experimental data; the molecular or structural approach, where one tries to relate bulk behavior with the detailed dynamics of the structural unit; and the continuum approach, where one tries to generate models by placing general restrictions on the form of the rheological equations as prescribed by the rules of tensor analysis.
Correlations have been tested for purely viscous non-Newtonian fluids against considerable data for smooth tubes. Three turbulent flow correlations exist for viscoelastic fluids; each correlation has been derived from an independent set of flow data. This paper presents a correlation for friction factors for fluids in turbulent, viscoelastic flow which fits the data as well as or better than the three above-cited correlations. The proposed correlation is a generalization of the Blasius correlation for the turbulent flow of Newtonian fluids.
Joint Industry/Government/University Programs of Research and Development
Authors: Bourgoyne A. T. 
Published: December 2007

ABSTRACT
The most serious short and long-term energy problem in the United States is the inadequate supply of domestic petroleum for transportation fuels. National energy problems stem from rapidly declining domestic petroleum resources, the manipulated world market for oil, and insufficient research and development.
Most petroleum research is currently funded by industry or government in their own laboratories. This approach has the following shortcomings: (1)competing oil companies are duplicating research efforts, (2) the technology transfer and end-user feedback essential to making research and development " effective does not occur in an efficient manner, and (3) funding of large projects is difficult and may prevent the undertaking of a number of desirable studies.
Joint industry/government/university programs are emerging as a viable alternative for directing, managing, and funding research. This format can help minimize nonproductive and redundant research efforts. It also greatly strengthens the academic programs that are needed to provide highly trained professionals for the energy industries. This is especially true for disciplines, such as Petroleum Engineering, which are closely tied to the oil and gas producing industry and its cyclical manpower needs.
Academic institutions were surveyed to compile a list of existing joint research ventures. The type of contractual arrangements and management structures used in the existing programs were determined. Comments are made on the strong points and problem areas experienced in various types of cooperative research programs.
CO2 Injection and Production Field Facilities Design Evaluation and Considerations
Authors: Linn L. R. 
Published: December 2007

Abstract
Many technical papers have been published on CO2 flooding from a reservoir standpoint; but, few have ever discussed design considerations of field CO2 production and injection facilities. This paper will present initial design and installation considerations, design criteria, and initial installation problems associated with Amoco's four West Texas CO2 projects (Slaughter Estate Unit, Central Mallet Unit, Frazier Unit, Wasson ODC Unit). Additionally, design and operational considerations, based on the experience gained from operating the four CO2 floods during the last two years, will be discussed for use in future CO2 facility designs.
Equipment problems which have been experienced during operation, modifications which have been made as a result of experience, and recommended changes for future designs will be discussed in this paper. Actual case histories of operations, equipment design, and equipment problems encountered will be presented. The specific areas to be discussed will include: The CO2 injection system material selection and layout, CO2 injection wellhead material selection and configuration, CO2 injection well downhole equipment, producing wellhead pressure and material requirements, flowline and fluid gathering systems, satellite and central tank battery layout and operation, and the gas collection system layout and material selections.
Special considerations will be given to design details and material' specifications that are often overlooked, or not considered. The resulting potential problems and failures of these oversights will be discussed.
Production Well Testing Utilizing a Mass Flow Meter
Authors: Flahive R. M. , Hickey P. J. 
Published: December 2007

ABSTRACT
Metering equipment has been developed which can accurately measure the percent watercut in addition to the total flow rate of an emulsion stream. This makes possible the use of two-phase (liquid and vapor) vessels for accurate production well testing purposes. This alleviates the need to use more costly and less operationally efficient three-phase vessels.
Correlation of Capillary Entrance Pressure Drops with Normal Stress Data
Authors: LaNieve H.L. , Bogue D.C. 
Published: December 2007

Abstract
The pressure loss at the entrance of a capillary tube was studied as a means of characterizing viscoelastic fluids. Measurements were made for four polymer solutions and correlated with an equation of the form
where D is the shear rate and where Hch and lambda ch are a characteristic stress and a characteristic time, respectively, determined independently from viscosity and normal stress measurements. Various theoretical analyses of capillary entrance flow are also compared.
Introduction
The most fundamental experiments to measure stress behavior in viscoelastic fluids are those in which the fluid elements have undergone constant shear rate histories for a very long tine. These important viscometric flows are found in the basic viscometric geometries: capillary tube, rotational cylinder, cone and plate, etc. On the other hand, many industrially important flows are accelerative [non-viscometric] and must be analyzed mathematically using a constitutive equation or correlated empirically. The flow at the entrance of a capillary is this kind of flow. It is a particularly important one because of the wealth of data and experience from the capillary viscometer.
The measured pressure drop in a capillary viscometer is an over-all one from the upstream reservoir to the downstream reservoir or from the upstream reservoir to a free jet. The frictional losses [viscous dissipation include a loss upstream of the tube and inside the tube due to the developing flow, a loss during developed flow in the tube, and a loss at the exit. There is also a kinetic energy [Bernoulli] effect if either reservoir is not large compared with the tube. These various effects plus possible elastic effects may be summarized in terms of a mechanical energy balance as follows:
........................................(1)
where F indicates irreversible dissipation and indicates differences between the two reservoirs. The quantity E is the elastic energy per unit mass and, in terns of the classical balance is part of the internal energy of the fluid.
For inelastic fluids [where PE/P = 0), analyses are available for the dissipation in each of the sections indicated in Eq. 1. For viscoelastic fluids, no rigorous analysis exists but if one assumes that the elastic effects may be added to the viscous effects [by no means certain], the elastic effects can be identified by difference and correlated experimentally. The analyses and procedures for the various terms will now be discussed in turn.
KINETIC ENERGY AND VISCOUS DISSIPATION EFFECTS
Kinetic Energy Effects
In a flow through a capillary from one stagnant reservoir to another, the net change in kinetic energy is zero.
Research on Jet Pumps for Single and Multiphase Pumping of Crudes
Authors: Corteville J. C. , Ferschneider G. , Hoffmann F. C. , Valentin E. P. 
Published: December 2007

ABSTRACT
The hydraulic characteristics of an industrial jet pump were determined in single and two-phase flow, and a prototype was studied to determine geometric shapes well suited for two-phase flows. Jet pumps were then compared to other downhole pumps from the technical and economic standpoint.
New Logging Concept Defines Clay Invasion While Drilling
Authors: Boone D. E. 
Published: December 2007

ABSTRACT
A computerized system has been developed that logs porosity and percentage gas saturation of reservoir rock in one foot increments. Interpretive procedures have been developed that provide a positive definition of hydrocarbon reservoirs with porosity, pore pressure, gas saturation, reserves and permeability. Examples show that permeability to drilling fluid is a function of porosity raised to the power 2.21. Clay and drill solids penetrate porous sands to such depth that current wireline porosity tools read low.
Foamed Cement Achieves Predictable Annular Fill in Appalachian Devonian Shale Wells
Authors: Colavecchio G. P. , Adamiak R. 
Published: December 2007

ABSTRACT
Foamed cement systems, consisting of 35% to 45% nitrogen by volume, have been pumped during the past several years in a number of different applications throughout the continental United States including the Appalachian Basin. Candidates for foamed cement include wells that have low breakdown pressures (lost circulation), those that require a stage tool to obtain required fillup and air-drilled holes where high viscosity slurries in narrow annulus create excessive pressures that contribute to weak zones thieving cement.1
The Devonian Shale exhibits all the above criteria in areas of West Virginia, so was selected as a field study for purposes of developing technology while improving the percentage of "successful" cement jobs in the field. The exact definition of success may vary from area to area, operator to operator, so for purposes of this paper it will be defined as obtaining consistent cement fillup in the annulus and subsequently fracture stimulating through the cement sheath with no operational or production problems due to high break down pressures. Other evaluation criteria of successful cement jobs such as economics and bond logs must be analyzed on operator/field basis and not a regional basis.
Operationally, significant strides have been made in mixing, pumping and maintaining a stable foamed cement in the field. Early jobs may have failed due to nitrogen bubbles becoming too large by interconnecting and migrating through the base cement slurry. Those jobs resulted in, at best, inconsistent slurry density throughout the column and at worst nitrogen returning to surface in the annulus causing complete job failures resulting in remedial squeeze work.
Recent improvements in maintaining foam stability have allowed foamed slurry samples to be retained at the surface during pumping operations. Precise job monitoring of rates, pressures, temperatures and slurry densities have established quality control assurances at the surface so that downhole variables can be better determined.
The state of the art of foamed cement systems pumped in the Appalachian Basin today is vastly superior to that of the past. What was once a good idea in theory is now an even better idea in practice.
Economic Optimization of Bailing Operations in the Appalachian Area
Authors: Suhy T. E. , Yu J. P. , Zhuang Z. 
Published: December 2007

Abstract
The gas industry in the Appalachian Basin is experiencing falling gas prices. The result is reduced revenues and fewer dollars available for exploration and development of new reserves. This has forced innovative companies to examine methods to increase production from existing wells. It has been observed that optimizing a fluid removal program can result in profitable production increases.
The majority of accumulated fluids in the wellbore are formation salt brines. The hydrostatic pressure created by this fluid column can restrict or kill production from these typically low pressured reservoirs. The most common procedure used to remove the production reducing brines is periodic bailing.
The non-linear least square curve-fitting techniques are being applied to fit the production decline of each well. The overall production is curve-fitted as hyperbolic or harmonic decline and each bailing cycle is curve-fitted as an exponential decline. The bailing cost and other economic overhead are used as the economic limit for bailing cycle scheduling. Other criteria such as rate of return on investment, lease contracts, current gas prices, geographic location, weather conditions and farming activities will be optimized into a working priority list for the bailing operation of each well. The ultimate goal is to create a complete management package on a microcomputer that can be used to continuously evaluate the update the entire bailing and production maintenance program. In this package, artificial intelligence will be included to optimize the decision-making rules. This new approach will create an economic benefit for oil and gas production in the Appalachian Basin. This paper describes the development and work completed towards this objective.
Infill Drilling in the Clinton: Monte Carlo Techniques Applied to the Material Balance Equation
Authors: Murtha J. A. 
Published: December 2007

ABSTRACT
Material balance methods can be used to estimate oil-in-place and then drainage area for oil wells, when only production data is available. Reservoir pressure, both initial and current, must be available. In addition, gas and oil gravities must be known. Ranges for other factors, such as solution gas-oil-ratios and formation volume factors can be derived. Monte Carlo simulation provides the final step.
Some Rheological Considerations Concerning Rock Behavior
Authors: Rana Mahmood H. 
Published: December 2007

Abstract
It is well known that rocks behave in a viscoelastic manner. Therefore, the theory of elasticity does not provide valid answers to problems of rock behavior. Various rheological models have been developed conforming to rock deformation. Most important of these is the Kelvin solid model. The model involves a coefficient of solid viscosity, which appears to have the makings of a future criterion for rock fracture.
The paper describes the evaluation of the Kelvin model and presents a few analytical developments concerning rock's viscosity from measurement in the mine stopes and the structural volume flow of rocks. Some experiments, results obtained in the laboratory are presented. These results indicate the advisability of using a Kelvin model and give an idea of the types of failure mechanisms operating in the rocks.
In light of these and other development's, the directional properties of rocks are discussed. The possibilities of exploitation of these properties in drilling in preferential directions, reorientation of mine workings, and oil well fracturing are briefly mentioned.
Introduction
It is well known that rocks behave in a viscoelastic manner. Among rheological models applicable to rock behavior, the most import is that of the Kelvin solid, although the Maxwell and Burger models are also applicable to some extent. One of the two constituents of a Kelvin solid deals with time-dependent behavior of rocks and involves the coefficient of structural viscosity. This solid-viscous parameter appears to be a future potential criterion for structural design involving rocks and rock-like materials. The parameter has been experimentally determined in the laboratory, using a number of independent techniques. This paper is a step further in this direction and consists of theoretical development for determination of structural viscosity from mine stope measurements. Some data obtained in the laboratory are used to calculate some values of the coefficient of solid structural viscosity. The above are then used in formulating the comments concerning exploitation of the directional properties of rocks in drilling reorientation of mine workings and oil well fracturing.
ANALYTICAL CONSIDERATIONS
In analytical development presented here, it is assumed that the rocks behave like a Kelvin solid, represented by the equation:
........................................(1)
The solution of Eq. 1 is given by:
........................................(2)
If is constant, Eq. 2 reduces to:
........................................(3)
P. 121^
North Sea Pioneer
Authors: Goodwill D. 
Published: December 2007

This paper was prepared for the 96th Annual AIME Meeting to be held in Los Angeles, Calif., Feb. 19 through 23, 1967. 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
American Overseas Petroleum Limited, operator for Texaco North Sea U. K. Limited and California Oil Company Limited, drilled the first well - 38/29-1 - on the U. K. Continental Shelf after leases were issued in 1964. This well is the farthest offshore operation yet attempted and was drilled through the severe 1964 winter. The detailing of the preplanning and actual drilling of this first well is presented to offer assistance to Industry not only for the North Sea basin but also for other new offshore areas. It is the conclusion of the operator that year-round drilling can be carried out in the North Sea; however, preplanning is necessary - allowance must be made for weather induced delays - and recognition must be taken of possible leg scour problems resultant from the combination of ocean floor currents and type formation.
There have been many recent news items regarding the oil industries' successful activities on the U.K. Continental Shelf - happily one of such in October 1966 reported a gas discovery by American Overseas Petroleum Limited acting as managing agent for Texaco North Sea U. K. Limited and California Oil Company Limited on Block 48/7. However, the specific well to be discussed, Amoseas 38/29-1, garnered more publicity than any other U. K. offshore well drilled to date - and it was dry! This publicity reflected the fact that 38/29-1 was the first offshore well to be drilled on the U. K. Continental Shelf after the Shelf leases were issued by the U. K. Government in Fall 1964. This paper discusses the preplanning and actual drilling of this first well. It is the author's hope that providing such a detailed discussion of both preplanning and actual results will be of assistance to industry in evaluating the operational problems to be anticipated in such new offshore areas. For the back round behind the spudding of well 35/29-1 almost at the geographical mid-point of the North Sea on December 2, 1964, one must refer back to 1959. It was in August 1959 that Slochteren #1 discovered The Netherlands Groningen gas field now credited with reserves in excess of 50 trillion cu. ft. of natural gas.
Systems Approach to Pipe Handling, Cementing, and Mud Mixing
Authors: Merritt C.H. 
Published: December 2007

This paper was prepared for the 96th Annual AIME Meeting to be held in Los Angeles, Calif., Feb. 19 through 23, 1967. 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
This paper outlines the design objectives of current development programs toward semi and fully automated pipe handling systems and increased utilization of existing onshore skid mounted cementing units by incorporating into this unit additional functions of supplying the hydraulic source for pipe handling equipment and the capabilities of performing all mud mixing and conditioning.

Introduction
As the cost of exploration and drilling of known reserves is rapidly increasing throughout the world, the need for new improved methods and a more highly mechanized approach to labor and time saving innovations becomes apparent. The equipment presently used in the drilling industry offers untold opportunities to improve machinery design in order to help offset these costs. While the evaluation of automation in this field has been historically slow, there are at present definite parameters of equipment design which may be nearer to justifying automatic machinery than ever before.
One of these areas where development work is presently underway involves potential labor and time saving methods of pipe handling. In this conjunction, investigation is underway for the development of the following tools:
Universal Drill Pipe Tong Pipe Racking Systems Casing Stabbing System.
Further savings may be realized by incorporating the low pressure mud mixing system plus hydraulic power for pipe handling tools into skid mounted cementing units presently used on almost all offshore drilling rigs. This phase of design is already completed and remains to be proven through extended application.
As early as 1947 development was undertaken on semi-automatic power operated drilling machinery. This system performed all the routine functions of round tripping the pipe in the hole and was controlled remotely by manipulation of hydraulic and pneumatic valves.