bluuebunny/crossref_metadata_2025_split huggingface dataset:
The first semi-submersible platform specifically designed for dynamic positioning
Authors: Susbielles G. , Martin Y. , Vasseur B. 
Published: December 2007

This paper was prepared for the SPE-European Spring Meeting 1974 of the Society of Petroleum Engineers of AIME, held in Amsterdam, the Netherlands, May 29–30, 1974. 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 publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor PETROLEUM ENGINEERS JOURNAL is usually granted upon request 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 Netherland Section of the Society of Petroleum Engineers, P. O. Box 228, The Hague, the Netherlands. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Results are given of a study in which the behaviour of semi-submersible platforms equipped with respectively 2, 3 and 5 floaters is compared under the action of waves, winds and currents. Required conditions were minimum effects of wind and currant action and most favourable amplitude levels for drilling operations.
A three-legged platform turned out to be the best choice. Results of mathematical model studies were complemented and verified with the help of model basin tests. Additional model tests were performed in a wind tunnel to determine the optimum deck shape.
Main features of the installation of drilling equipment on deck will be shown. Information is also given on the dynamic positioning system.

Introduction
The search for new subsea oil and gas fields under greater and greater water depths and the exploration of such fields has led to the replacement of jack-up platforms by floating supports such as drilling ships and semisubmersible platforms.
In addition, consideration must also be given to the effect of extremely hostile environmental conditions (storms) on such structures. A platform must withstand such disturbances at one time or another during its effective life span, depending on the work schedule it must follow. At the same time, new sorts of dangers (icebergs) make it necessary to minimize installation time at a given site and to maintain the possibility of moving away in the midst of a possibility of moving away in the midst of a drilling operation.
Under such conditions, dynamic positioning is of great interest because it guarantees positioning is of great interest because it guarantees quick installation on a drilling site and enables the position to be changed as fast as it becomes necessary as the result of marine elements (i.e. keeping headed into the wind of current if necessary).
Laboratory Investigation of a Suitable Waterflood for the Bulgurdag Field and a Design of a Tracer Field
Authors: Durusu Ilhan 
Published: December 2007

This paper was prepared for the SPE-European Spring Meeting 1974 of the Society of Petroleum Engineers of AIME, held in Amsterdam, the Netherlands, May 29–30, 1974. 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 publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor PETROLEUM ENGINEERS JOURNAL is usually granted upon request 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 Netherland Section of the Society of Petroleum Engineers, P. O. Box 228, The Hague, the Netherlands. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
This study presents the results of a laboratory investigation of a suitable waterflood tracer for a limestone reservoir such as the Bulgurdag field. For this purpose, continuous and slug injection tests were performed in a crushed limestone pack by using potassium iodide, sodium chloride and potassium iodide, sodium chloride and sodium borate as tracers. Continuous injection tests were performed with various concentration or tracer added to the floodwater. The lengths of the mixing zone for each tracer were thereby obtained. To obtain adsorption losses during propagation, a number of slug injection tests were made in which slugs ranging from 100 to 25 to 10 and to 5 percent of the length of mixing zone percent of the length of mixing zone were injected and displaced by continuous injector of floodwater. On the basis of the laboratory results, it is concluded that because of its adsorption loss and the difficulty of the chemical analysis, sodium borate is not a suitable tracer. Potassium iodide is a suitable tracer when present even very small quantities, but its use is not considered economical due to its high price. The sodium chloride tracer, although the required amount is the largest, is the most economical tracer for use in the Bulgurdag field due to its low price.
A design of a tracer flood for the Bulgurdag field is also proposed. The weight of the tracer chemical and the cost are calculated for various slug sizes. The time at which the tracer will first appear in the production well is predicted on the basis of a presumed reservoir geometry and presumed reservoir geometry and lithology.

Introduction
In the secondary recovery of petroleum by water flooding, an accurate petroleum by water flooding, an accurate evaluation of the subsurface pattern of flow of the injected water is necessary.
Gas Production And Interference Effects
Authors: van Golf-Racht Th. 
Published: December 2007

This paper was prepared for the SPE-European Spring Meeting 1974 of the Society of Petroleum Engineers of AIME, held in Amsterdam, the Netherlands, May 29–30, 1974. 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 publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor PETROLEUM ENGINEERS JOURNAL is usually granted upon request 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 Netherland Section of the Society of Petroleum Engineers, P. O. Box 228, The Hague, the Netherlands. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
In the interference problem some aspects which have not yet been taken in consideration were examined in this paper. These problems are:How could paper. These problems are:How could the turbulence influence gas well interference tests, andrelationship between producing wells and their distribution.
In the first part of this work it was shown that turbulent flow is influencing the transient behaviour during well interference test, and a method of evaluation was indicated. A calculation example has shown quantitatively the importance of neglecting turbulence effect in interference evaluation. In the second part of the paper the relationship between number paper the relationship between number of producing wells and single well rate as affected by well interference was discussed. The interference concept is usually associated with the idea that an increased number of wells reduces the single well rate or, for maintenance of a constant rate, requires a higher pressure draw-down. It is demonstrated pressure draw-down. It is demonstrated that this conclusion is valid only if the hydrocarbon reserve is in direct contact with an efficient lateral water zone and if the wells are non-uniformly distributed over the structure.
Diffraction of Water on a Body of Revolution Along Several Meridians - Application to a Tank in the Sea
Authors: Le Goulven P. , Alleuard Y. , Coudert J.F. , Lamy Y. 
Published: December 2007

This paper was prepared for the SPE-European Spring Meeting 1974 of the Society of Petroleum Engineers of AIME, held in Amsterdam, the Netherlands, May 29–30, 1974. 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 publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor PETROLEUM ENGINEERS JOURNAL is usually granted upon request 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 Netherland Section of the Society of Petroleum Engineers, P. O. Box 228, The Hague, the Netherlands. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
It is advantageous for tank or platform builders to be able to calculate platform builders to be able to calculate pressure distribution on a body of any pressure distribution on a body of any shape set on the bottom of floating. This model is an initial approach to the problem. It can be used to calculate pressure problem. It can be used to calculate pressure distribution, total force or moments on a solid of revolution set on the bottom or floating. For this, the fluid is assumed to be perfect, irrotational and non-viscous. We are thus working with linear conditions. The solution is calculated in a functional space of splines in the domain between the body and an arbitrary cylinder encompassing it. The solution is continued outside the cylinder as a Bessel function series.

Introduction
For offshore structures, it appears more and more necessary to be in possession of sufficiently accurate and possession of sufficiently accurate and reliable mathematical models. The existence of very powerful computers such as the CDC 7600, for which this model has been programmed, thus makes it possible to programmed, thus makes it possible to consider methods which, although requiring relatively extensive calculating, give more accurate and complete results than in the past. This study was made for the Association de Recherche "Action des Elements" which we hereby thank for having allocated to us the necessary funds and for authorizing publication.
PHYSICAL HYPOTHESIS PHYSICAL HYPOTHESIS The fluid is assumed to be:
* Irrotational, incompressible, nonviscous.
* The pressure at the free surface is also assumed to be constant.
Under such conditions, there exists a velocity potential phi (x, y, z). So that :
in which u, v, w are the velocities components on x, y and z axis.
One can show 1 that phi thus checks out:
delta phi = 0
which is associated with the Bernoulli's equation :
Foundation Scour And Remedial Measures Foil Offshore Platforms
Authors: Sybert J.H. 
Published: December 2007

Abstract
Five platforms installed near Padre Island in the Gulf of Mexico experienced scour of foundation material caused by strong littoral currents. Dish-shaped depressions were formed under each platform; some were twelve feet deep and the edges extended as far as sixty feet from the platforms. Laboratory research projects directed the design of an inverted filter which was installed at each platform. Design information and installation techniques are given. Submarine surveys following Hurricane Carla in 1961 found a minimum amount of filter material displaced and very little additional scour.
Introduction
The Chevron Field is located in the Gulf of Mexico just offshore from Padre Island. It is approximately 25 miles southeast of Corpus Christi, and is east of Kingsville. Oil and gas wells are being produced from five platforms which are located 1 1/2 to 2 1/2 miles from the shore, where the water is approximately 40 feet deep.
During the installation or these platforms, foundation cores were taken to determine proper pile penetration. Cores could not be recovered from the upper soil layers due to its unconsolidated state; however, it was found that these layers consisted of fine sand with a few shells and a few clay stringers.
Approximately 2 1/2 years after the first platform was installed, divers who were working on a salvage operation reported that the sand had been scoured from beneath one of the platforms. Three platforms were in place at the time and the fourth was being fabricated.
Numerical Simulation of the Solution Mining Process
Authors: Nolen J.S. , von Hantlemann O. , Meister S. , Kleinitz W. , Heiblinger J. 
Published: December 2007

ABSTRACT
A new digital computer program simulates the solution-mining process. This program calculates, as a function of time, the shape of a salt cavern created by the single-well leaching process, the concentration of the produced brine, and the rate of increase of cavern volume.
In this paper the method of simulation is briefly described, as are a special core analysis technique and a method of log interpretation used to prepare data for the simulator. Calculated cavern shapes are compared with field measurements for two caverns leached in a heterogeneous salt formation.
It is concluded that the simulator is capable of accurately calculating the shapes of salt caverns leached in such formations and that core analyses and properly interpreted well logs can provide good estimates of the salt properties necessary for simulation.

INTRODUCTION
Solution mining has long been used to produce NaCl, KCl, and other soluble salts. Now it is being increasingly applied as a method of creating storage for crude oil, natural gas, refinery products, and industrial wastes.
Among the reasons for the great interest in salt-cavern storage are the following: (1)Salt formations are stable within known limitations; therefore, it is possible to construct structurally sound storage caverns for long period of operation.Salt is so impermeable to flow that fluids can be stored in a cavern for long periods without leakage, provided the well is carefully completed.Virtually 100% of storage liquids are recoverable from salt caverns. In high pressure gas caverns the ratio of working gas to cushion gas is high.
Advanced Well Construction as Integral Part of Reservoir Management
Authors: Holm W. H. 
Published: December 2007

Abstract
The continued challenge to increase reserves from producing fields has highlighted the need for further integration of the well construction process into reservoir management.
During the early nineties, the need to reduce costs while improving safety and drilling performance led to a change in Phillips Petroleum Company Norway's approach to drilling management. Despite staffing reductions, changes to engineering and operational philosophy created the foundation for significant improvements in safety, environmental and operational performance.
Faced with a reduction in offshore activities as a consequence of redeveloping the giant Ekofisk Field, a major organizational re-engineering effort was initiated in the spring of 1996. The result was a radically, new organizational model, which emphasizes customer satisfaction and value creation, while maintaining focus on competence building, multi-discipline team work and shared learning (organizational learning).
This paper describes the continued organizational and technological evolution that has enabled Phillips Petroleum Company Norway (PPCoN) to deliver advanced wells, such as horizontal and multilateral wells, with a clear focus on reserves replacement, while making continued progress on safety and cost reductions.
Rig Upgrades and Proper Planning Result in Successful Drilling in Bohai Bay, China
Authors: McRae J. D. , Boudreaux B. A. , Yao Wang Zhen , Hai Yang Yuan 
Published: December 2007

Abstract
This paper describes the pre-planning and execution of Kerr-McGee China Petroleum's Laohai #1 drilling project in Bohai Bay, China. It details our approach in ensuring a safe and efficient drilling program utilizing a Chinese drilling unit that had never worked for a foreign operator nor drilled in a deep, abnormally pressured environment.
The paper will detail the strategies used for implementing rig upgrades, training and working with Chinese National personnel, and improving the well design in order to reduce risk and increase efficiency. It will also describe the operational successes and failures due to these strategies and the improvements made during the well operations. Finally, recommendations for future projects with similar circumstances are presented. This approach will provide valuable insight for a foreign company planning a well using a Chinese drilling unit.
Variation of Skin Damage with Flow Rate Associated with Sand Flow or Stability in Unconsolidated-Sand Reservoirs
Authors: Tippie D.B. , Kohlhaas C.A. 
Published: December 2007

Discussion of this paper is invited. Three copied of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
A semi-cylindrical sand-pack model of a cased-and-perforated completion was loaded with an overburden pressure and fluid flowed through the pack to simulate production. Flow rate was gradually increased in each test. Sand arches formed to stabilize sand movement. As reported previously by the same authors, arch size was a function of flow rate. Skin effect caused by arch formation, destruction, and size variation is also a function of flow rate. Minimum skin effects were noted for a particular flow rate. Potentiometric flow particular flow rate. Potentiometric flow models were used to verify sand-pack results. Flow tests in a linear flow cell indicated a significant damage effect (permeability reduction) due to fines migration. The sand-pack completion model indicated that the fines migration and skin effect change are associated with sand instability.

Introduction
Sand production from oil and gas wells has become a major problem in many regions of the world. A high percentage of current exploration and develonment effort is being expended in these areas. Sand control with plastic injection and gravel packing is not only time-consuming and expensive, but also generally causes severe productivity restriction.
The authors studied flow through a sand pack in the laboratory to understand the natural mechanism which prevents sand production from some wells completed in production from some wells completed in unconsolidated sands. That work was based on the arching studies of Hall and Harrisberger and Stein and Hilchie. Natural stabilization by arching of unconsolidated sand during production was confirmed with a sand pack model of a well completion. Fluid was flowed radially through a semi-cylindrical sand pack which was loaded vertically to 260 psig to simulate overburden pressure. (See Figure 1). Inlet fluid flow was distributed evenly over the outer surface. The inner cylindrical surface represented well casing. Sand used was 20–40 mesh Gopher State proppant sand. Sand arches formed around the fluid outlet ("perforation") to establish static equilibrium between the stressed sand pack and unstressed sand at the perforation. (See Figure 2). perforation. (See Figure 2). Flow rates were increased until sand flowed.
Validation of Wax Deposition Model by a Field Test
Authors: Hsu J. J. C , Lian S. J. , Liu M. , Bi H. X. , Guo C. Z. 
Published: December 2007

Abstract
An accurate prediction of wax deposition profiles along a production line has significant impact on savings, pipeline design, flow assurance and operations of waxy crude production system in oil industry. Validation of wax deposition model by a field test is a necessary step to ensure accuracy of the modeling results.
A field, located in Northeast China, was chosen for the field test. A pipeline was installed between wellhead and original production line. After 18 days of field test, the pipeline was disassembled and cut into 31 pieces. The amount of wax deposition in each piece of pipe was measured and recorded. In the field test pipeline, waxy crude was transported under multiphase flow conditions at temperatures below pour point. The wax deposition model is a semi-empirical model to include molecular diffusion and shear effects. A scaler is proposed for the modeling. The accuracy of this model relies on the accurate experimental data obtained from the special wax-deposition-flow-loop test procedures. The state of art wax deposition flow loop, built in Beijing, China by two oil companies, can accurately and cost effectively determine wax deposition tendency and rheology of waxy crude from temperatures above the oil cloud point to ambient.
A recombined live oil was used in the laboratory flow loop tests. The laboratory data and the field operating conditions were input to the wax deposition model. The modeling results were compared to the field data for validation. The accuracy of the modeling results and modeling technique are discussed in this paper.
Measurement of Dielectric Parameters of Rock Cores at 300 kHz to 3GHz Frequencies
Authors: Nguyen Buu-Long , Bruining Johannes , Slob Evert C. 
Published: December 2007

Abstract
We describe a new experimental setup which enable measurement dielectric response of rock cores at different saturation. The experimental setup combines the well-known steady-state core flooding technique and measurement of the S11 scatter functions.
We derive the equations describing the scatter functions for a multisection coaxial transmission line ended in lossy media. We consider the case when the transmission line contains a coaxial sample holder.
Based on the theoretical model of the scatter function, we developed a procedure for the calculation of the frequency-dependent complex dielectric permittivity of rock cores from the scatter functions.
The complex dielectric permittivity of brines, oil and dry sandstone, as well as complex dielectric permittivity of brine-saturated sandstone, obtained from experimental measurements and numerical optimization process are also presented.
We observed high dielectric losses in brine-saturated sandstone. The effects of brine concentration on dielectric losses are however not significant.