bluuebunny/crossref_metadata_2025_split huggingface dataset:
Design Criteria for Completion of Steam Injection Wells
Authors: Willhite G. Paul , Dietrich William K. 
Published: December 2007

Abstract
Casing failure in production wells stimulated with steam is a serious economic limitation in the application of steam injection to accelerate oil production from viscous reservoirs. This paper discusses the causes of casing failures and develops design criteria for completion and stimulation of new and existing wells. Casing failure occurs initially when temperature-generated compressive stresses exceed the yield strength of the casing. This forces the casing material or joint to permanently deform during the steam injection period. Subsequent cooling while the well is shut in or producing relieves the compressive stress. However, the deformation induced during steam injection creates a tensile stress as the casing temperature returns to its normal level. Often this tensile force buildup results ill joint failure by fracture or pullout. The mechanisms of casing failures are discussed in detail to provide a basis for selecting safe casing temperature changes for any well completion. Design criteria derived from these mechanisms are proposed as guidelines for the safe stimulation of old wells and the completion of new wells specifically for high temperature steam injection. Field experience is presented to confirm the utility of these guidelines for the protection of casing in productions wells stimulated with steam.

Introduction
Steam stimulation of production wells can subject the casing to high thermal stresses. Casing failures after first-cycle steaming have been numerous, particularly in areas where the injection temperatures are greater than 500F. At least 30 casing failures have been verified in California steam stimulation projects. Failures have also occurred in the Mid-Continent area from Texas to Wyoming. Generally, failures are found in the joint, although a few instances of collapse have been reported.

Discussion
Joint failure is a symptom rather than the cause of mechanical problems in steam injection wells. As the caring is heated it will normally tend to elongate in direct proportion to the change in temperature. Since some length of casing in most wells is not free to elongate, the tendency to elongate is replaced by compressive stress buildup in the casing. What happens to the casing can be understood if the behavior of a typical casing during a steam injection-production cycle is considered. The pipe body and the joint are assumed indistinguishable and both will be termed "the casing". Fig. 1 is a stress-temperature change diagram for casing heated in a steam injection well assuming that the initial stress is zero. Path A-B is the elastic portion of the compressive stress T curve. For plain carbon steels the compressive stress generated by thermal expansion forces is about 200 T psi.
Drag-Bit Performance Modeling
Authors: Warren T. M. , Sinor A. 
Published: December 2007

Summary
Models for the forces required to remove a fixed volume of rock with a single cutter have been applied to different polycrystalline-diamond-compact (PDC) bit designs. The integration of the forces for each cutter over the bit face gives the torque and weight on bit (WOB) required for a particular rate of penetration (ROP). This paper presents the results of comparing such a model to laboratory drilling tests for four radically different bit designs in four different rocks. The geometry of each cutter on the bit was determined by detailed measurements of the bit with a three-axis coordinate measuring machine. Drilling tests were conducted by "reaming" rock with an 8½-in. [21.6-cm] bit that was previously drilled with a 6¼-in. [15.9-cm] bit. Only the peripheral cutters engaged the rock during reaming. Additional tests were conducted in which the WOB and torque were recorded during drilling of a pilot hole into the top of a flat rock and during drilling through two different bed boundaries with constant ROP. The model predictions compared well to the measured data for both the reaming and pilot-hole tests.
A Material-Balance Method for Deriving Interblock Water/Oil Pseudofunctions for Coarse-Grid Reservoir Simulation
Authors: Starley G. P. 
Published: December 2007

Summary
This paper describes a material-balance method for deriving interblock water/oil pseudofunctions for application in coarsely gridded areal reservoir models. The method is shown to be effective in pattern waterflood simulation. This technique differs from previous methods in (1) explicitly accounting for grid orientation by deriving directionally dependent pseudos, (2) combining a dispersion control scheme with the pseudofunction derivation, and (3) matching fractional flow in pattern models through a material balance. The pseudofunctions are derived from fine-grid pattern models and account for various effects, including anisotropic formation properties, dominant displacement forces (viscous or gravitational), and correction for preferential directional flow.
Steady-State and Unsteady-State Flow of Non~Newtonian Fluids Through Porous Media
Authors: Van Poollen H.K. , Jargon J.R. 
Published: December 2007

Abstract
Non-Newtonian fluids may be injected into a reservoir during secondary recovery operations. The non-Newtonian fluid used in this work is a power-law type of fluid; that is, the viscosity of the fluid decreases as the flow rate or rate of shear increases.
This paper presents equations for steady-state, linear and radial flow of such fluids, transient behavior results from a finite difference model of a radial system, and transient behavior results from a field test.
The equations that describe the flow of a non-Newtonian fluid are non-linear and are solved numerically. Finite difference solutions are presented as curves of dimensionless pressure drop at the wellbore vs dimensionless time for a constant injection rate. Solutions were obtained for 5-percent, 10-percent and 100-percent PV of a non-Newtonian fluid for injection rates of 1, 10, 100 and 1000 cc/sec and for a 5 percent PV of non-Newtonian fluid located at r = rw, 3, 10, 20, 50 and 100 ft for a flow rate of 1 cc/sec. The buildup curves do not exhibit a straight-line portion as is the case for Newtonian flow through porous media.
Correlations also are shown for the productivity index vs rate for the computer model study and the field tests.

INTRODUCTION
During various secondary recovery operations non-Newtonian fluids are injected. Such fluids, in general, include thickened water and gelled fluids. The term "non-Newtonian" implies that the viscosity is not only dependent upon temperature and pressure, but also on the rate of shear that is applied to the fluid. For example, water, which is a Newtonian fluid, will have essentially the same viscosity no matter what rate of shear is applied. A pseudoplastic fluid exhibits a decreasing viscosity when higher rates of shear are applied; a dilated fluid has an increasing viscosity with increasing rates of shear.
The objective of studies performed and described in this report is to obtain relationships and mathematical and empirical descriptions of the flow of non- Newtonian fluids through porous media. Simple mathematical relationships, computer studies that include the unsteady- state behavior of such fluids, and field tests are used.

PREVIOUS LABORATORY STUDIES
Laboratory studies have been performed by several investigators. The fluids used in one investigation1 were surfactant-stabilized dispersions of water in hydrocarbons. Its Fig. 6 is reproduced as our Fig. 1. This effective-viscosity vs frontal-velocity diagram shows that this fluid is of the power-law type over a fairly large range of frontal velocities. Gogarty1 developed an equation for the effective viscosity as a function of shear rate that reduces to Eq. 2 for frontal velocities greater than about 2 ft/D. The fluid characteristics used in the present study are similar to those reported by Gogarty.
Comparative Study of Eight Equations of State for Predicting Hydrocarbon Volumetric Phase Behavior
Authors: Ahmed Tarek H. 
Published: December 2007

Summary
The objective of this study is to present a review of eight equations of state (EOS’s) and compare their ability to predict the volumetric and phase equilibria of gas-condensate systems. Included in the study are the Peng-Robinson (PR), the Soave-Redlich-Kwong (SRK), the Schmidt-Wenzel (SW), the Usdin-McAuliffe (UM), the Heyen, the Kubic, the Adachi-Lu (AL), and the Patel-Teja (PT) EOS’s. The SW equation exhibits a superior predictive capability for volumetric properties of condensate systems. The PR equation is found to represent the phase equilibrium behavior of condensate systems accurately. In terms of compressibility factors, the SW and PT equations give better predictions than other equations.
EOS Predictions of Compressibility and Phase Behavior in Systems Containing Water, Hydrocarbons, and CO2
Authors: Flroozabadl A. , Nutakkl R. , Wong T. W. , Aziz K. 
Published: December 2007

Summary
Two cubic equations of state (EOS) have been adopted to compute multicomponent two-phase compressibility, CO2/water and hydrocarbon/water phase behavior, and gas- and liquid-phase densities. The equations used in this paper are the Schmidt-Wenzel (SW) EOS and the Peng-Robinson (PR) EOS. While these cubic equations have the same form, the SW is reported to be more accurate for predicting hydrocarbon gas- and liquid-phase densities. Density predictions are compared with experimental data to confirm the superiority of the SW EOS.
The use of EOS to predict equilibrium phase compositions of water/hydrocarbon and water/CO2 systems is discussed. For the water/hydrocarbon systems, the aqueous-phase interaction coefficient between water and the dissolved component shows a strong temperature dependency, while in the gas phases, a constant value of interaction coefficient is adequate. In the case of the CO2/water systems, the interaction coefficients for both the aqueous and gas phases show temperature dependency.
A scheme to compute the two-phase compressibility of multicomponent reservoir fluid systems is also introduced. Our results show the expected sharp change in the compressibility during phase change. Such computations are required in some reservoir simulators.
Bottomwater Drive in Tarmat Reservoirs
Authors: Al-Kaabi Abdul Aziz , Menouar Habib , Al-Marhoun Muhammad Ali , Al-Hashim Hasan S. 
Published: December 2007

SummaryThis paper addresses the class of tarmat reservoirs subject to bottomwater drive. Different shapes of tar layers are simulated physically and numerically to study the behavior of WOR and oil recovery.Four different cases were studied: a square barrier beneath the well, a disk beneath the well, a hollow square or disk beneath the well, and a half plane. The results showed that breakthrough time occurs earlier in the case of hollow tarmat barriers, while it is delayed considerably in the case of tarmat barriers shaped in the form of a disk beneath the well. Paradoxically, in this last case, the WOR increases more rapidly and becomes higher toward the end of the depletion than in any other case. Among all the cases studied, the no-barrier case gives the highest recovery, while the hollow-tarmat-barrier case leads to the lowest recovery.
Enhanced Water Recovery Improves Stimulation Results
Authors: Ford William G. F. , Penny Glenn S. , Briscoe James E. 
Published: December 2007

Summary
The effects of capillary pressure, wettability, and relative permeability in controlling load water recovery following hydraulic-fracturing treatments have been examined. Laboratory studies have indicated that the alteration of wettability to control capillary pressure and/or relative permeability can promote a rapid, thorough cleanup of injected water. Field applications of these concepts have resulted in enhanced load water recoveries and higher production because of longer effective fracture lengths and/or higher effective fracture conductivities after treatment cleanup.
The Outlook for Louisiana's Offshore Production
Authors: McCollum S.V. 
Published: December 2007

Statistics Reflect Erratic Growth
The offshore area offers more challenge, more promise, more problems, more heartaches and more disappointments than any other oil and gas producing region in the world.
The growth and development in the offshore area of Louisiana has been a series of ups and downs, as verified by figures on the active drilling rigs running in the Gulf of Mexico since 1947.
From 1947 until the early part of 1953, there was a period of "no leasing". In early 1953, there were approximately 10 rigs running seaward from the Chapman line. There was a steady increase in drilling operations up to the middle of 1956, when the U.S. Supreme Court issued its injunction that shut down everything within the disputed area.
When the agreement between Louisiana and the Federal Government was reached, the number of rigs operating increased to 106. This peak period, with over 100 rigs operating, lasted until the latter part of 1957. The operators then decided that it would be wise to shut down and "look at their hole card"; maybe offshore drilling was not the "economic plum" they had thought. This offshore recession lasted until the latter part of 1958, when the operators began a cautious recovery climaxed by the sale in Feb., 1960.
As of April 1, 1960 (according to industry statistics), there had been 3,091 wells drilled in the offshore Louisiana area. Of these, 1,799 were completed as oil wells, 418 as gas wells and 874 (or 28.3 per cent) were dry. Production of oil and condensate is approximately 226,000 B/D, and gas production is averaging 909 MMcf/D.
At the present time, there are approximately 3,375,000 acres under lease, with an accumulative investment in this acreage of $616,266,000. At the last offshore lease sale held Feb. 24, 1960, 454,046 acres were sold for $246,379,283. Left on the table was $133,078,895.
Field Examples of Nuclear Magnetism Logging
Authors: Hull Paul , Coolidge John E. 
Published: December 2007

Abstract
Field examples are presented from various operating areas which demonstrate the capability of the nuclear magnetism log to operate under most drilling and formation conditions. On the basis of these examples, it is shown thatthe free fluid index of nuclear magnetism logging provides a superior means of reservoir rock definition, yields a measure of formation permeability and productivity and is an excellent correlation tool andhydrocarbon and water can be differentiated with good reliability.
Operational factors are discussed along with methods of interpretation of original data.

Introduction
In Sept., 1959, Brown and Gamson presented a paper concerning the application of nuclear magnetism to oil-well logging. Some early examples of field performance were discussed along with a detailed explanation of the basic phenomenon as it applies to down-hole operations.
It is the purpose of this paper to discuss the operations of nuclear magnetism logging (NML) and to present additional field results. As will be evident, NML is in the early stages of development, and its full significance is yet to be realized. Its ability to define fluid-bearing zones is well established. In addition, considerable evidence suggests its application as a permeability or productivity index, its ability to distinguish hydrocarbon and water zones, and its capability of operating in all borehole conditions.
Certain operational problems of a commercial NML must still be evaluated. Only a limited number of logs have been conducted with a recently completed prototype tool, and continuous changes are being made for more satisfactory operation.
A Career of Human Significance
Authors: Glenn Wayne E. 
Published: December 2007

EDITOR'S NOTE: Although aimed toward graduating senior engineers and delivered as a commencement address, the following paper offers stimulating thoughts to all engineers on "technical obsolescence", community responsibility, budgeting of time and other important matters. A somewhat more detailed version of this paper was delivered at Montana School of Mines on June 6, at which time the author received his honorary doctorate degree.
The years immediately ahead - 1961, 1962, 1963 - will be critical years from every standpoint for the young engineer. In the next few years, he must learn to grow professionally. Most often, the rate and extent of this growth will be governed by his own initiative and perseverance. Habits and attitudes acquired during these early professional years relate very closely to, and even foreshadow, future accomplishments.
The future goal of the young engineer is a moving target. It will change with professional growth, family requirements, changes in predominant interest, general economic and business conditions and geographic location. However ambitious and steadfast in his goal he may be, the young engineer should not hesitate to adjust or change - for he really does not know initially what he is best fitted for and will not know until he has tried a number of things patiently and persistently.
Professional development in specific technical competence and, broadly, as an individual and as a citizen will have many facets. To achieve "A Career of Human Significance" will require a well conceived plan, properly timed and executed. The successful engineer will need to maintain a thirst for knowledge throughout his career, for one of his critical personal problems will be the constant pressure to keep up with the parade of advances and new findings in the profession-to escape what might be termed "technological obsolescence".

Technological Obsolescence
The problem can be stated as a paradox. The engineering graduate leaves college partially educated for his career. Nevertheless, at that time he may possess a wider range of detailed scientific and technical knowledge than he will at any later stage of his career. To maintain the highest level of technical "know-how" calls for a life-long study habit.
Analysis of Prestimulation Test Data in Devonian Shale Reservoirs
Authors: Holgate K. E. , Lancaster D. E. , Lee W. J. 
Published: December 2007

Summary
Prestimulation testing in Devonian shales has proved to be complicated because of the long duration of wellbore storage distortion that must be exceeded during flow and shut-in periods to obtain an analyzable test. This paper presents field examples of four prestimulation well tests that illustrate the practical difficulties in obtaining analyzable data. We were not able to analyze these tests with conventional semilog and type-curve methods.
To understand the cause of the difficulties, we simulated a prestimulation well test to verify that the actual wells had not been produced long enough to exceed wellbore storage distortion. We then history matched the actual test data from two wells using a finite-difference simulator. Because we lacked good estimates of many formation properties, we performed a sensitivity study that indicated that the calculated permeability-thickness product is only slightly affected by errors in porosity and net pay estimates. We conclude with guidelines to aid in the design and implementation of a prestimulation test in Devonian shales.
Reservoir and Stimulation Analysis of a Devonian Shale Gas Field
Authors: Shaw J. S. , Gatens J. M. , Lancaster D. E. , Lee W. J. , Avary K. L. , Terry D. P. 
Published: December 2007

SummaryThis paper presents a study of a shallow, low-productivity Devonian shale gas field consisting of 48 wells in Mason County, WV. Gas production from wells in the field was found to be associated with zones of substantial free-gas porosity in the presence of high kerogen (organic) content. Most wells are poor producers; the best wells are located in the northwest portion of the field, which corresponds to an area of natural fracturing identified by remote sensing imagery. We identified and mapped quality reservoir areas and predicted performance for all wells in the field. The stimulation treatments conducted on all wells in the field successfully initiated gas production from the shales, but these treatments generally failed to achieve the degree of stimulation expected from such jobs.
Effects of the Quadratic Gradient Term in Steady-State and Semisteady-State Solutions for Reservoir Pressure
Authors: Finjord J. , Aadnoy B. S. 
Published: December 2007

Summary
Constant-rate analytical solutions of the one-phase radial-flow equation in two dimensions, including effects of the quadratic gradient term, are derived for an oil reservoir with constant diffusivity and compressibility. The combinations of compressibility contributions to the various terms are analyzed. It is shown that the standard condition allowing the quadratic gradient term to be neglected (cp≪1) is incorrect; pressure, p, should be replaced by a function of the production rate and other reservoir parameters except absolute pressure.
The effect of the quadratic gradient term, for which quantitative expressions are given for steady-state and semisteady-state flow, may amount to several percent of the pressure drawdown at the wellbore.
Effect of Directional Permeability on Sweep Efficiency and Production Capacity
Authors: Landrum Bobby L. , Crawford Paul B. 
Published: December 2007

Abstract
Theoretical and potentiometric model studies have been made of the effect of non-uniform lateral permeabilities on pattern sweep efficiency and production capacity in waterflood and gas-cycling programs.
It is shown that a difference in directional permeability by a factor of three may result in a sweep efficiency of only 43 per cent for a five-spot pattern or a sweep of either 79 or 38 per cent for a direct line-drive square pattern, depending on the direction of the line-drive flood. Changes in the pattern conductivity varied from about 0.8 to 1.34 over this same permeability variation, depending on the pattern used.
It is suggested that measurements be made to determine the possible magnitude and extent of the directional permeability phenomenon early in the field development and certainly prior to the initiation of any fluid-injection program.

Introduction
Irregularities in reservoir sand properties long have been a major difficulty to anyone attempting to explicitly describe the field characteristics of oil production. In particular, it is well known that vertical and lateral permeabilities often differ appreciably; however, the existence of large regions with lateral permeability variation is not widely recognized. A number of years ago, extensive studies were conducted by the Secondary Recovery Research Laboratory of the Pennsylvania Grade Crude Oil Association, primarily on the Bradford field. Johnson and Hughes reported a permeability trend in the northeast-southwest direction. They indicated that flow in the preferred direction may be 25 to 30 per cent greater in that direction than in the northwest-southeast direction. They also reported that similar effects may be found in other nearby fields. The origin of the permeability variation has been discussed by Griffith. Hutchinson described the results of laboratory tests on limestone cores, pointing out that preferential directional permeabilities were significant in one-half of 10 formations studied and that the average permeability ratio was 16:1.