bluuebunny/crossref_metadata_2025_split huggingface dataset:
A New Mechanical Pile Connector Speeds Offshore Construction Projects
Authors: Hettinger F. L. 
Published: December 2007

Abstract
During the past year, a new mechanical pile connector has been introduced to the offshore construction industry. This connector has been the culmination of an extensive development and fullscale testing program by Vetco Offshore, Inc. A family of driveable pile connectors has since been produced, ranging in size from 30" O.D. to 72" (762 mm to 1829 mm). Included in this family are standard releasable connectors and remote-releasable connectors for skirt pile recommended for permanent pile applications.
Specifically designed for skirt pile and permanent pile applications, the pile connector incorporates field-proven features that have been used on Vetco wellhead and riser connectors. The design phase included a finite element optimization and a fatigue analysis of the connector. Special anticorrosion considerations have been taken to ensure long life in the marine environment.
The connector was tested extensively at both in-plant and field facilities. These tests included tensile, pressure, bending functional, and pile driving tests. Following the development tests, the connector was supplied to several users for actual field trials. Since the connector has been introduced to the offshore industry, it has been used in a variety of skirt piles and permanent pile applications. To date, the pile connector has been supplied in 30",40", 42", 48", 54"and 72" (762 mm, 1016 mm, 1067 mm, 1219 mm, 1372 mm and 1829 mm).
Improved Pressure Response Representation and Reduction of Numerical Dispersion Effects in Reservoir Simulation
Authors: Laprea-Bigott Marcelo , Morse Richard A. 
Published: December 2007

ABSTRACT
A study has been made of the effects of numerical dispersion in reservoir simulation. A one-dimensional two-phase (water-oil) numerical model has been used in this investigation.
Instead of the regular single-point upstream transmissibilities, a new technique is proposed which consists of keeping track of the position of the displacement front, and using an interblock pseudo transmissibility. It is shown that a very significant reduction of the numerical dispersion of flood fronts and much improved representation of pressure history are obtained when using these modifications.
The applicability and effectiveness of this technique is illustrated by comparisons of numerical examples with theoretical and data published in the literature. The method proposed in this study can be implemented in any finite-difference reservoir simulator without much reprogramming effort, provided the displacement process to be simulated can be described by the Buckley-Leverett theory.
Analytical Modeling of Oil Recovery by Steam Injection: Part II. Asymptotic and Approximate Solutions
Authors: Yortsos Yanis C. , Gavalas George R. 
Published: December 2007

ABSTRACT
This article studies the development of asymptotic and approximate solutions for the growth of the steam zone in steam injection processes in one-dimensional reservoirs at constant injection rates. These solutions are generally derived by using integral balances which include heat losses to the surroundings and the hot liquid zone. In this way, the effects of preheating, caused by heat transport in the hot liquid zone ahead of the steam front are fully accounted.
At the beginning of injection the advance of the front is well described by the Marx-Langenheim model, provided that the injection rates are sufficiently high. At longer times deviations occur and a criterion is developed, in terms of a single heat transfer dimensionless parameter R, that defines the time interval of applicability of the Marx-Langenheim model. The asymptotic behavior at large times depends solely on a dimensionless parameter A, defined as the ratio of the latent to the total heat injected. It is shown that the final dimensionless expression does not depend on R (i.e., on the injection rates), although the time taken to reach the asymptotic state is significantly influenced by R.
An approximate analytical solution that reduces to the respective asymptotic expressions at small and large times is obtained under conditions of high injection rates (R ≫ 1). The solution is shown to give a better approximation to the steam zone rate of growth for intermediate and large times than the approximate expressions developed by Marx and Langenheim3, Mandl and Volek4, and Myhill and Stegemeier5. For a wider range of operating conditions (including low injection rates), i.e., for R between 1 and ∞, an approximate numerical solution based on a quasi-steady state approximation is presented. The proposed solution requiring very modest computation is expected to give reliable results under a variety of operating conditions.
Modeling of Filter Cake Buildup Under Dynamic-Static Conditions
Authors: Ershaghi Iraj , Azari Mehdi 
Published: December 2007

ABSTRACT
A method is discussed whereby the numerical solution of equations describing the filtration process of drilling fluid may be used for prediction of cake buildup and filtrate volume into a given zone. The data required for the simulation study include estimation of cake permeability during the dynamic phase, filtrate viscosity, cake compressibility and porosity, and pressure differential against the formation.
Application of the technique allows sensitivity analysis of important parameters controlling the filtration process in a given operation. Furthermore, estimation of invasion radius may be made in advance for determination of optimum timing for logging and improvements in log interpretations. This will allow the design of the best mud composition for a given application.
The Coal Bed Methane Potential of the Raton Basin, Colorado
Authors: Tremain Carol M. 
Published: December 2007

Abstract
In order to determine the coal bed methane potential of the Raton basin, Colorado Geological Survey personnel studied the geography, the geology, the history of oil and gas exploration, and the coal resources and past production in the Raton coal region. Data gathered during study of the above disciplines, along with direct measurements of the coals’ gas content, can be used to estimate the methane potential of the Raton basin.
Perspective on Devonian Shale Gas Exploration
Authors: Dean Claude S. 
Published: December 2007

Abstract
Since fractured reservoirs are essential to production, exploration rationales specific to the Devonian shale unconventional gas resource are characterized by a geologic fracture creating mechanism. One such predicts intense fracturing in the shale wherever proximally associated with the major thrust faults of the Appalachian overthrust belt. Gruy Federal No. 1 Grainger Co. (DOE EGSP-TN9), a U.S. Department of Energy (DOE)-funded rank wildcat located in Grainger County, TN, successfully tested that rationale. The well penetrated the Saltville Thrust Fault (stratigraphic throw: over 10,000 feet) and encountered the Devonian-Mississippian Chattanooga Shale in the lower plate. The shale proved to be 720 feet thick, of which 480 feet or 67% was anomalously radioactive (25 API above shale base line). Two hundred twenty (220) feet of core was recovered from the most highly radioactive (organic rich) intervals and a full suite of wireline logs was run. Widespread and locally intense fracturing in the shale, especially in the organic sections, observed in the core and evidenced by the logs vindicates the exploration rationale. The well will be hydraulically fractured and tested to evaluate production potential.
The Unique Methane Gas Deposit in Lake Kivu (Central Africa) - Stratification, Dynamics, Genesis and Development
Authors: Tietze Klaus 
Published: December 2007

Abstract
Lake Kivu, situated in Central Africa, contains a scientific and economic peculiarity: 63.109 m3 of methane at STP are dissolved in the deep part of this lake. The gas is held in the water by a special density stratification. The lake has recently been systematically explored during a German research expedition. With help of the results of the expedition and theoretical exploitation models the basis for development of this unique methane deposit has been created.
Influence of Coalbed Characteristics and Geology on Methane Drainage
Authors: Finfinger Gerald L. , Prosser Leonard J. , Cervik Joseph 
Published: December 2007

ABSTRACT
Methane drainage in advance of mining using horizontal holes continues to expand. Interpretation of coalbed characteristics and geology in relation to drilling procedures and gas flows will provide additional information for further development of this technique. A study conducted in the Pittsburgh coal-bed at Bethlehem Mines Corp., Marianna mine 58, showed the effect of coalbed discontinuities, such as clay veins and sandstone channels, on drilling of horizontal boreholes and on gas flows. It has shown the need to adapt drilling techniques to the varying degrees of hardness encountered within the same coalbed.
Drilling Long Horizontal Coalbed Methane Drainage Holes from a Directional Surface Borehole
Authors: Diamond William P. , Oyler David C. 
Published: December 2007

ABSTRACT
Three primary horizontal methane drainage holes totaling 2,428.4 meters (7,967 feet) have been completed in the Pittsburgh coalbed from a directional surface borehole. Directional control and sidetracking techniques developed during the project increased the horizontal drilling rate from 24.4 meters (80 feet) per day initially to 64.9 meters (213 feet) per day on the third horizontal hole. Drilling data indicate that horizontal holes can be drilled substantially longer than the maximum 977 meters (3,207 feet) achieved.
Effect of Laboratory Core Cleaning on Water-Oil Relative Permeability
Authors: Jennings H.Y. 
Published: December 2007

Abstract
Predictions of reservoir performance are usually based on laboratory measurements of core properties. Laboratory measurements, for example of oil recovery by waterflooding, are in turn related to the wettability of the rock surface. This has been shown by recent papers in the petroleum literature on the subject of wettability. Data have already been presented by this laboratory which show that wettability determines the shape of the water-oil relative permeability curves for a given porous medium. Thus, ideally, laboratory measurements should be made on cores which have the same wettability as the reservoir rock. This paper presents results of laboratory relative permeability measurements on oil field cores. Measurements were made in the water-oil system using the dynamic or "Penn State" relative permeability method. Saturations were obtained by using a radioactive oil soluble compound. Data were obtained on cores as taken from the field in an unextracted condition. Measurements were then made on the same cores after toluene extraction.
A comparison of the relative permeability vs saturation curves obtained from the core samples before and after extraction showed a measurable change in the curves, but the changes were small and not due to significant changes in wettability. It can be concluded that the laboratory procedure of core cleaning with toluene extraction and subsequent handling during core analysis does not significantly change the relative permeability characteristics from those of the core material at the start of the core analysis operation. This conclusion is based on data from cores that were preferentially water-wet, cores that were preferentially oil-wet, and cores that were of intermediate wettability.

Introduction
Reservoir rocks are porous media with high specific surface area and exceedingly fine pore structure. It is not difficult to understand why a knowledge of the surface properties of reservoir rocks is fundamental to an understanding of how fluids flow in such porous media. The molecular processes that occur on the surface of the reservoir minerals and at the fluid interfaces have been shown to be a dominating factor when considering the recovery of oil from porous media. Intensive research is being conducted by most oil field research laboratories in an to evaluate qualitatively and quantitatively the role of wettability. The activity in this field can be verified by noting the number of recent publications and patents dealing with the subject of "wettability". Prior to these recent articles, only a meager amount of wettability data was available in the petroleum literature. These articles show that wettability can materially affect predictions concerning the volume of oil-in-place, and controls to a great degree the relative success of completion methods and several recovery processes.
Emulsion Characteristics Associated With An Alkaline Water Flooding Process
Authors: Chang Mun-Sik M. , Wasan Darsh T. 
Published: December 2007

ABSTRACT
This paper presents the results of an investigation of emulsions containing an acidic crude oil from Wilmington Field, California, and sodium hydroxide/sodium orthosilicate solutions. The effect of alkaline water formulation on emulsion characteristics was determined.
The characteristics of emulsions were evaluated as a function of salinity, alkali type, and alkali concentrations in the aqueous phase. Emulsion stability, as defined by the coalescence rate of oil droplets in water-external emulsions, was determined as a function of salinity and alkali type. Shear viscosity measurements were made for both the oil-external and water external emulsions formed as a result of crude oil/alkaline water interaction. When the emulsions were oil-external, the degree of incorporation of water by the oil was measured in terms of oil phase volume swelling. The effect of divalent ions on shear viscosity and phase volume swelling were also evaluated.
The results indicate that there is some optimum salinity in the aqueous phase which needs to be maintained to minimize the problems associated with viscous emulsions. Also the emulsions formed with sodium hydroxide are different from those formed with sodium orthosilicate, especially in the presence of divalent ion salts, so that different salinities are required to minimize the shear viscosity of emulsions for the two systems.
Improving Cement Bond in the Rocky Mountain Area by the Use of Spacer, Wash, and Thixotropic Cement
Authors: Waremburg Philip A. , Kirksey James M. , Bannister Charles E. 
Published: December 2007

ABSTRACT
Extensive results from field tests in the Rocky Mountain area show how cement bonding may be improved through the use of a spacer, wash, and thixotropic cement. These results are the culmination of nearly three years field work undertaken to determine what factors affect bonding and what methods or materials could be used to consistently improve the cement-to-pipe and cement-to-formation bond.
This paper discusses the recognized conditions associated with poor cement bonding and the materials that were used alone and in combination to improve cement bonding. Bond logs and other data are presented to show the results obtained through the use of a spacer, wash, and thixotropic cement. Other techniques used to improve cement jobs are briefly discussed.
Foamed Hydrocarbon Stimulation Water Sensitive Formations
Authors: Holcomb David L. , Callaway Ralph E. , Curry Lynn L. 
Published: December 2007

ABSTRACT
A system of synergistically combining fluorocarbon and hydrocarbon surfactants has been developed to provide specific foaming agents which will function effectively in various hydrocarbon media. The uses of these agents are potentially tremendous in foam fracturing, paraffin and heavy hydrocarbon removal, hydrocarbon/water hydrostatic head removal, and foamed drilling operations.
Development and research of three specific foaming agents in three different condensates will be reviewed to correlate data necessary to optimize foaming agent selection.
The hydrocarbon media that can be foamed are virtually unlimited and include kerosene, diesel, condensate, aromatic solvents, crude oil and water/condensate combinations.
This technique provides a new alternative for completion and stimulation in areas where formation sensitivity to water must be considered.
Petroleum Vaporization Recovery by High Pressure Gas Injection
Authors: Barney C.L. 
Published: December 2007

Abstract
This paper presents a method for estimating recovery and performance under a program of high pressure gas injection in volatile oil reservoir under vaporization conditions. A discussion or the equations and data needed to make the estimates is given with a description of how these data are obtained. A description of vaporization phenomena during the recovery process is also given.
The "vaporization process as a means of recovery in volatile oil reservoirs" is defined as a pressure maintenance program, whereby gas is injected into the oil column of a reservoir under high pressure, resulting in oil production by miscible displacement and absorption. The vaporization recovery process is a relatively new concept in oil reservoirs even though a similar process has been used for years in condensate reservoirs. When carried out under proper conditions, the program is expected to yield very high oil recovery.
The recovery method is developed by using an injected gas reservoir oil phase diagram and certain volumetric balance equations. A volumetric balance of various reservoir fluids is maintained by simultaneously solving sweep efficiency of the respective fluids. A sample calculation is included.

Introduction
In 1951, Atlantic initiated a high pressure gas injection project in its Block 31 field in West Texas. Although current comparative recovery data are not available from this project, it is known to be performing successfully. Atlantic has continued to pioneer the high pressure, miscible gas injection theory of production as evidenced by papers starting in 1950.
Even though the vaporization process of hydrocarbon recovery has been used for many years in condensate reservoirs, it is a relatively new concept in oil reservoirs. As is true in condensate reservoirs, very high recovery is expected when the process is applied to oil reservoirs.
Wave Theory and Free-Surfaces - A Study of the Motion of Oil Reservoir Fluids
Authors: Rowan G. 
Published: December 2007

Abstract
This paper deals with the time-varying solutions of free-surface problems in porous media as an extension of the steady-state theory developed by M. King Hubbert. Examination of the equations shows that a marked similarity exists between these and those of the linear exact wave theory for the propagation of a disturbance at the interface of two superposed fluids. This purely formal analogy is extended so that solutions in hydrodynamic theory may be transformed quite simply to give solutions to similar problems in porous media.
The auxiliary problem in water wave theory, namely the shallow water problem, is next considered. The resulting equation is found to exhibit a similar analogy to the Boussinesq equation or the Dupuit-Forchheimer theory of ground-water flow.
On the basis of these analogies and the relationship between the theories of deep and shallow water waves, an analysis is made of the errors involved in the Dupuit approximation. A discussion on the application of the Dupuit approximation to model experiments indicates the importance of the size of the model on the interpretation of results. A method is suggested for analysing gravity flow problems by means of a combination of the Dupuit theory and the more exact theory.

Introduction
This paper is concerned with the study of the motion of an interface separating immiscible liquids of different density and viscosity in a porous medium. It is assumed that the flow of the fluids in question is governed by Darcy's law and that the presence of an interface is due to complete segregation under the action of gravitational forces. Hence in a multi-fluid system, whenever gravitational effects are of importance, interface or free-surface problems naturally present themselves.
Strictly speaking, the term "free-surface" is usually applied to the hypothetical surface of demarcation between air and water in ground water studies. However, it is a convenient description and is applied quite generally to surfaces of separation as defined above, thus avoiding any confusion with the interfacial phenomena studied in capillarity theory.
Coal Conversion Plans and Plants in the United States
Authors: Fedde Paul A. , Hagerman Robert L. 
Published: December 2007

Abstract
Just a few years ago energy analysts were projecting U.S. energy requirements to be 150 quads (1 quad = 1015 Btu) by the year 2000. The rapid rise in energy costs, particularly petroleum derived fuels, since 1973 has resulted in the spending of millions of dollars by industry and individuals to increase the efficiency of energy utilization in the U.S. This trend toward energy conservation has become so apparent that recent estimates of U.S. energy requirements for the year 2000 have been lowered, and now range between 95 quads and 120 quads.
Coal usage which was 770 million tons in 1979 (15 quads) is projected to be approximately 40 quads in 2000 (see Table 1), a 150% increase. Coal, which supplied 18% of the U.S. energy requirements in 1979, is estimated to supply about 37% of the U.S. energy in the year 2000. This huge increase in coal consumption is needed if the U.S. is to meet its goal of two million barrels of oil equivalent energy from coal conversion and shale oil plants by the mid 1990's.
Table 2 is my estimate of the contribution of substitute fuels to U.S. energy requirements in 2000. To supply 7.5 quads of substitute fuels will require building five 100,000 bbl/dy oil shale plants, twenty 100,000 bbl/dy coal liquids plants and twenty-eight 250 MMCFD coal gasification plants in a period of just 20 years. The capital cost of these plants in today's dollars is in excess of $175 billion. Most of the coal conversion plants produce both gaseous and liquid product streams so it will not be possible to classify the plants as simply as stated above. The proposed Texas Eastern-Texas Gas Sasol type plant for example will produce the equivalent of 56,000 barrels of oil per day but 44% of the plant output, on a Btu basis, will be pipeline quality gas.