bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Effect of Phase Data on Liquids Recovery During Cycling of a Gas Condensate Reservoir
Authors: Fussell Del D. 
Published: December 2007

Abstract
A linear, one-dimensional compositional model was employed to study the effect of phase data on the recovery of the pentanes and heavier fraction during gas cycling of a sour gas condensate reservoir. The results show that the phase data used and the method of handling the effects of composition on phase data can affect the computed recovery performance.

Introduction
Introduction
The prediction of performance for reservoirs containing volatile fluids historically has been very difficult. The development of compositional reservoir simulators has given engineers a new tool to attack this problem. Several recent papers, have discussed the application papers, have discussed the application of this type of simulator to the prediction of reservoir performance.
Huang showed that the predicted reservoir performance for a three-component system (methane, performance for a three-component system (methane, n-butane and n-decane) was not sensitive to small errors in phase viscosity and density data, but was sensitive to the accuracy of the methane K-value data. He recommended developing phase data based on an experimental depletion curve for the original fluid system.
Experimental data for the original reservoir fluid system would be expected to be the minimum information required for reservoir simulation during gas cycling. Large composition changes occur in a reservoir during injection of a dry gas (usually plant residue gas) with a greatly different composition than the reservoir gas phase. The predicted performance, then, is expected to be sensitive to performance, then, is expected to be sensitive to the method selected for describing the phase equilibria of the volatile fluid, particularly for pressures just below the saturation pressure. pressures just below the saturation pressure. In this study, gas cycling calculations were performed on a gas-condensate reservoir where performed on a gas-condensate reservoir where experimental phase behavior data were only available for the original reservoir fluid.
Successful Pilot Predicts Bright Future for Loco Hills Water Flood, New Mexico
Authors: Darden Frank , Cook Robert J. 
Published: December 2007

Abstract
The Grayburg-San Andres reservoirs of the Artesia- Vacuum trend, Eddy County, N. M., have produced more than 2 million bbl of primary oil. The rock characteristics and production performance of these reservoirs indicate that many of them should yield substantial volumes of secondary oil. This paper describes the performance of one of the most successful waterflood pilot operations in the Artesia-Vacuum trend. The Newmont Oil Co. pilot in the Loco Hills field consisted of six injection wells in a modified five-spot pattern. Existing producing wells were converted to injection and a local water supply was used until response justified construction of a 26-mile pipeline to deliver sufficient water volumes for full development. Production rates in individual pilot wells increased from 400 to more than 18,000 bbl/month by June, 1960. Injectivity profiles indicate that this field must be flooded at high injection rates and pressures to effectively sweep all of the productive sand and that the reservoir appears to be quite sensitive to variations in injection rates. Additional development of Newmont leases surrounding the pilot area has continued, and the project had 15 injection wells and 47 producing wells on Feb. 1, 1962. These properties, which were producing 444 B/D in Aug., 1958, averaged 2,618 B/D in Jan., 1962. Unit volume recoveries in the pilot flood indicate that the Loco Hills field should be one of the more important secondary recovery projects in New Mexico.

Introduction
The Loco Hills field is located in the southwestern part of the Artesia-Vacuum trend of Eddy County, N. M., in a minor syncline on the flank of the Grayburg-Jackson monocline. Location of the field is presented in Fig. 1. The reservoir is a stratigraphic trap limited on three sides by permeability pinch-outs and on the east by a static water table. The principle producing formation his Zone 4 of the Grayburg formation of Permian age, locally known as the Loco Hills sand. This zone occurs at an average depth of 2,750 ft. It has good continuity throughout the area examined and, from the data at hand, appears to have uniform characteristics from well to well. The "typical" Loco Hills section consists of 10 to 30 ft of tight gray sand or sandy gray lime, underlain by 20 to 50 ft of soft brown sugar sand. Only the brown sand has a native permeability high enough to permit natural flow.

History of Development
The discovery well in the Loco Hills field Yates, et al, Federal No. 1 is located in the NW/4 of SW/4 Section 6, T-17-S, R-30-E. This well was completed in Jan., 1939, for a potential of 506 BOPD after being shot with 140 qt of nitroglycerine. Development on random spacing followed rapidly until the field ultimately contained 264 wells over a surface area of approximately 8,500 acres.
JPT
P. 1223^
Calculation of Stabilized Gas Well Performance Curves From Back Pressure Test Data
Authors: Cornell David 
Published: December 2007

Abstract
Back pressure test data on natural gas wells are short time test data of unsteady state nature. Performance curves from which unsteady state effects have been eliminated, called stabilized performance curves, are necessary for understanding the behavior of gas wells and for scheduling gas fields for periods up to 20 years. A calculation procedure has been developed whereby three day, seven day, 30 day, or other duration stabilized performance curves may be calculated from- back pressure test data. Such curves are essential for correct gas deliverability calculations and gas field scheduling.

Introduction
The manner in which a back pressure test is made will affect the slope of the back pressure curve because the radius of drainage changes with the length of time that the well is allowed to flow. The reciprocal of the slope of the back pressure curve is defined as n in Equation 1 and varies from 0.5 to 1.0.
(Equation 1)
If the flow is viscous and the radius of drainage constant, n will have a value of 1.0. Because of turbulence in the formation near the well bore, the pressure drop is usually greater than the viscous flow pressure drop and the exponent n is frequently less than 1.0. In addition, since the radius of drainage moves away from the wellbore during the test, the gas flows a greater and greater distance as the test proceeds, with a resulting increased pressure drop at the high flow rates, and, again, n for the test tends to be less than 1.0.
The effect of the changes in the radius of drainage may be calculated and the results used in preparing stabilized performance curves for fixed values of the radius of drainage. Such curves can be made for a definite time period, such as three day, seven day, or 30 day stabilized performance curves. These curves will show the effect of turbulence near the wellbore and can be used to predict the performance of the gas well at any flow rate or for any production period.
A Vessel for Offshore Construction In Heavy Seas
Authors: Goren Yoram , McMillan Bruce 
Published: December 2007

A new generation of construction equipment an evolving for offshore work in heavy seas. The progenitor of the line is Choctaw, the world's first column-stabilized construction barge. She is capable of sustaining operations in seas up to 16 feet and of maintaining her station in unrestricted oceans.

Foreword
Increased worldwide demand for oil and oil products, together with political uncertainties in some of the major oil producing areas, is accelerating the search for oil offshore and extending its boundaries to deeper and rougher waters. Offshore oil production necessitates the construction of platforms and production facilities, as well as underwater storage and pipelines. A great many construction barges have been built to fill this need. Until June, 1969, all construction barges had conventional box-shaped hulls, a feature that limited their operations to seas not exceeding 5 ft. Because of the excessive motion in high seas, these barges had to be towed away to sheltered waters whenever a storm was forecast. In June, 1969, the construction barge Choctaw was christened. Choctaw represented an important turning point in the industry in that she is the first column-stabilized construction barge and is capable of sustaining operations in seas up to 16 ft and maintaining her station in unrestricted oceans.
The design principles used in the vessel are discussed in detail in Ref. 2. To restate the basic design philosophy, the designers recognized that a construction barge is seldom called upon to use her maximum crane capacity. For this reason, Choctaw was designed to operate in two different drafts. In the low draft, the crane can handle up to 800 tons at 90-ft outreach, and in the high draft, the crane can handle 150 tons at 110 ft with full deck load and no ballast compensation.
On several occasions the vessel was called upon to perform lifts heavier than 150 tons while in the high-draft condition. These exercises were carried out by maintaining the list angle to a minimum through transfer of ballast. Lifts of this type necessitate that careful planning and exacting calculations be carried out by the barge engineers.
The crane was designed to sustain a dynamic load produced by roll motion of 5 degrees in 9 seconds double produced by roll motion of 5 degrees in 9 seconds double amplitude (for all but the 800-ton load condition). The force produced by a 50-knot wind was superimposed on the dynamic loading. The crane was designed to sustain a 3 degrees barge list when lifting 800 tons.
The vessel was designed to operate in adverse climates: in temperatures ranging from -35 degrees to + 120 degrees F. Both design and construction were closely monitored and approved by Lloyd's Register and the U.S. Coast Guard.
Wellbore Heat Losses and Pressure Drop In Steam Injection
Authors: Pacheco E.F. , Ali S.M. Farouq 
Published: December 2007

This mathematical model of the mechanics of flow of wet and saturated steam down the wellbore during steam injection takes into account the variation of steam temperature and pressure due to friction, as well as heat losses by radiation, conduction, and convection. It consists of two coupled nonlinear equations that are solved iteratively.

Introduction
Chekalyuk et al., Moss and White, and Fokeev and Kepyrin, investigated wellbore heat losses during injection of a hot or cold fluid down the casing. Ramey made a comprehensive study of the injection of liquids and gases down casing or tubing. Squier et al. presented a complete analytical treatment of hot water injection down the wellbore. Satter extended Ramey's treatment to the case of steam injection. Huygen and Huitt, presented results of a theoretical and experimental treatment of wellbore heat losses during steam injection, and pointed out the importance of the radiation heat loss. Holst and Flock as well as Earlougher extended the above treatments by including, steam pressure calculations. Eickmeier et al. considered the early transient performance, using a finite-difference model. performance, using a finite-difference model. Apart from these studies, Leutwyler gave a comprehensive treatment of casing temperature behavior, and Willhite presented a complete calculation of the over-all heat presented a complete calculation of the over-all heat transfer coefficients.
The chief objective of our work was to formulate a comprehensive mathematical model of steam injection into a reservoir to include simultaneous calculation of steam pressure and quality. The model took into account the variation of steam temperature and pressure due to friction, as well as heat losses by pressure due to friction, as well as heat losses by radiation, conduction, and convection, and consisted of two coupled nonlinear differential equations that were solved iteratively. The model results were compared with those predicted by several of the above-mentioned approaches.

Formulation of the Model
Steam at a constant injection pressure, constant mass flow rate, and constant quality (at the surface) is injected through the tubing into the wellbore. The complete system consists of the fluid, the tubing, the annular space containing low-pressure air, the casing, the cement, and the formation. We propose to compute the pressure and the quality of steam as functions of depth and time.
An energy balance and a momentum balance can be written for the flowing fluid as follows:
Energy balance
..........(1)
Momentum balance
..............................(2)
The term dQ is given by,...................(3)
where the rate of heat transfer to the formation is
(4) dq = ,
JPT
P. 139
Development of an Underground Heat Wave for Oil Recovery
Authors: Grant Bruce F. , Szasz Stefan E. 
Published: December 2007

Introduction
During 1947, a Sinclair research team was assigned to investigate thermal methods of oil recovery. The assignment was recommended by a survey of possible research approaches to increase the amount of oil that ultimately can be recovered from oil producing reservoirs. The use of heat to stimulate, oil production rates by the melting of paraffin deposited in well bores can be traced back to within one or two decades of the drilling of the Drake well.
The application of heat on a larger scale has been discussed by generations of oil producers. Shortly after the turn of the century, one intrepid operator is reported to have injected steam into a Pennsylvania property. After a few weeks, he apparently became discouraged and terminated his experiment. Subsequently, the literature contains references to several well-developed techniques for supplying heat to a producing well bore to melt paraffin or to reduce the viscosity of oil contained in. the formation immediately around the well bore. Some early references discuss procedures to furnish heat to the reservoir, with the injection well as the heat source, thus obligating the process to maintain the entire rock mass at a temperature above that at which the desired improvement in oil recovery would occur.
Another approach to reservoir heating was reported by a group of Russian technologists in 1935. They definitely demonstrated that combustion can occur within the porous structure of an oil-bearing sandstone. Their field experiments, however, relied less on combustion within the rock than on heat furnished by combustion of oil supplied to the injection well bore. Ignition of the air-oil mixtures in the well bore was found very difficult, and the field tests were carried on for only short periods of time. Publication of the Russian work spurred at least one independent operator in this country to try firing an air-gas injection well. on for only short periods of time.
Publication of the Russian work spurred at least one independent operator in this country to try firing an air-gas injection well. The Brundred Oil Corp. reportedly obtained combustion in the sand immediately around the injection well bore, but the experiment was abandoned because of interference with normal production schedules. Injection capacity of the experimental well was greatly reduced by firing. The well was reshot and pieces of sand showing partial fusing of the quartz matrix were recovered.
The Bay Marchand Fire
Authors: Nelson R.F. 
Published: December 2007

Introduction
Platform "B" was launched July 16, 1969, in the Platform "B" was launched July 16, 1969, in the Bay Marchand Block 2 field. The 12-pile structure was located in 55 ft of water, 7 miles offshore and 65 miles south of New Orleans. It was designed for 36 wells, which were to be drilled by two independently operated, full-sized drilling rigs.
The first well on the platform was started Sept. 15, 1969. By Dec. 1, 1970, the two rigs, Stormdrill 20 and Stormdrill 21, had drilled and completed 22 wells. Of those wells, 21 were dual completions and one was a single completion. Daily production was 17,500 bbl of oil and 40 MMcf of gas. Two additional wells were in the process of being drilled. (Fig. 1 is an aerial view of Platform "B" before the fire broke out.)
Platform "B" was equipped with the latest safety devices and was being operated in full compliance with Government regulations.
What caused the Bay Marchand fire? Several investigations have disclosed the following facts. The plastic coating on the tubing in Well B-21 sloughed off and plugged the well. In the course of wireline operations to clean out the well a serious human error was made: during a period when the well was unattended, the well control valves were left incompletely closed. The well blew out and the fire ignited. A subsurface safety valve waiver, granted for completion purposes, was in effect at the time.
JPT
P. 225
Shear Viscosities of Ionic Polyacrylamide Solutions
Authors: Mungan Necmettin 
Published: December 2007

Abstract
Solutions of ionic polyacrylamide polymers behave pseudoplastic in purely viscometric flow. Flow rate, polymer molecular weight and electrolytes affect solution viscosities to a large extent. Equations are given for the viscosity-shear rate relations in a form that can be used conveniently to account for the effect of viscosity on mobility.

Introduction
Polymers are being used increasingly in oil recovery operations, and therefore, an understanding of their flow behavior is gaining pragmatic importance. Past studies have shown that in the flow of polymeric fluids through porous media, the increase in solution viscosity, decrease in permeability, and viscoelastic deformations cause permeability, and viscoelastic deformations cause the fluid mobility to be greatly reduced. In general, viscoelasticity, i.e., extensional flow, is not so important because, for the largest part of a reservoir, polymer solution moves at very low and fairly steady polymer solution moves at very low and fairly steady velocities. Jennings et al. have concluded this for the specific polymers that they studied. Permeability reduction plays an important role in Permeability reduction plays an important role in the mobility control, particularly in porous media having low permeabilities initially. Reductions ranging from 25 to 70 times have been reported. However, the alterations that take place in a porous medium during polymer flow, the coupling between the geometry of the porous medium and the properties of the flowing fluid, and the influence of the flow regime on permeability have not been looked into in sufficient detail. A separate study, directed to the understanding of these important phenomena is required.
In the present work, the purely viscous behavior of solutions of three partially hydrolized polyacrylamide polymers was obtained under experimental conditions far polymers was obtained under experimental conditions far more extensive than any reported in the literature. Some data have been available in the past for two of the polymers, but the third is a new polymer for which no data have been reported before. Using a Weissenberg rheogoniometer, Cannon-Fenske viscometers, and various capillary cubes, viscosities were measured over 8 decades of shear rate, ranging from 10 to to 10 (5) sec-1. These are the limits of measurable rates of shear and cover those that may apply to flow in reservoirs. Distilled water and various NaCl solutions were used as solvents to afford comparison of the rheological properties between fresh and saline solutions. Measurements were also made with solutions containing calcium' and magnesium to study the effect of divalent cations.
Inaccessible Pore Volume in Polymer Flooding
Authors: Dawson Rapier , Lantz Ronald B. 
Published: December 2007

Abstract
We have found that solutions of typical waterflooding polymers do not occupy all of the connected pore volume in porous media. The remainder of the pore volume is inaccessible to polymer. This inaccessible pore volume is occupied polymer. This inaccessible pore volume is occupied by water that contains no polymer, but is otherwise in equilibrium with the polymer solution. This allows changes in polymer concentration to be propagated through porous media more rapidly than propagated through porous media more rapidly than similar changes in salt concentration. At the front edge of a polymer bank the effect of inaccessible pore volume opposes the effect of adsorption and pore volume opposes the effect of adsorption and may completely remove it in some cases.
This paper presents three experimental polymer floods showing the effect of inaccessible pore volume in the presence of varying amounts of adsorption. Results of these floods clearly show that about 30 percent of the connected pore volume in the rock samples used was not accessible to The polymer solutions. The changes required to include polymer solutions. The changes required to include inaccessible pore volume in mathematical models of polymer flow and in held prediction methods are discussed.

Introduction
One way of improving the mobility ratio during waterflooding operations is by addition of a water-soluble polymer to the flood water. Several different polymers have been proposed and a number of investigators have presented results on the behavior of these polymer solutions in porous media. In addition, mathematical models have been developed for predicting the field behavior of polymer flooding. In all these studies movement polymer flooding. In all these studies movement of the polymer bank through the reservoir rock is of great importance.
One phenomenon that has been repeatedly observed in polymer flooding is the removal of polymer from solution by adsorption on the reservoir rock. As a polymer bank propagates through porous media, the polymer bank propagates through porous media, the front edge is gradually denuded of polymer. The amount of polymer lost from a bank may be large or small, depending on the nature of the polymer and rock surface. This loss of polymer must be measured and included in any realistic mathematical model of polymer behavior. It has been widely assumed that polymer behavior. It has been widely assumed that adsorption is the most significant factor causing polymer to propagate through porous media at a polymer to propagate through porous media at a velocity different from that of water.
In this paper we present data that demonstrate that all of the pores may not be accessible to polymer molecules and that this "inaccessible polymer molecules and that this "inaccessible pore volume" can affect polymer propagation pore volume" can affect polymer propagation significantly. In addition to the experimental results, we discuss the changes in interpretation and in mathematical models that are required to include this phenomenon.
A Method for Creating 2-D Orthogonal Grids Which Conform to Irregular Shapes
Authors: Hales Hugh B. 
Published: December 2007

Abstract
Reservoir simulations in the past have usually been made using Cartesian grid systems. However, the Industry's current integration of reservoir simulation and reservoir characterization has demonstrated the need for more flexible gridding methods. Flexible grids allow the incorporation of more accurate reservoir descriptions into reservoir studies, but generally result in more complex simulation mathematics and decreased simulation speed. Only curvilinear orthogonal grids offer increased flexibility without such complications. This paper describes a simple method for generating grids of this type. It provides several examples of curvilinear orthogonal grids and compares their simulation results with those of Cartesian grids using a real reservoir.