bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Physicochemical Approach to the Prevention of Balling of Gumbo Shales
Authors: Chesser B.G. , Perricone A.C. 
Published: December 2007

ABSTRACT
Gumbo-type shales have presented a multitude of problems in many drilling areas of the world, including "balled" bits, collars and stabilizers, plugged flow lines, and shaker screens. These problems can result in decreased drilling rate, lost circulation, stuck pipe, logging difficulties, and, in general, increased well cost.
A study was made of the gumbo-type shales which exhibit plasticity and adhere to the drill string and other drilling equipment. This work revealed that the balling tendency of these shales could not be controlled effectively with conventional inhibiting electrolytes such as gypsum, lime, sodium chloride, potassium chloride, etc. Thus, the clay base exchange or cation fixation mechanisms have been only partially effective in preventing the drilling problems associated with gumbo.
This paper describes a physicochemical approach to preventing the balling and sticking together of the massive gumbo shales. This approach is based upon the interaction of water with silica and alumina surfaces. This interaction produces a difference in proton density between the bound water on the clay surface and the pore or interstitial water. The electrostatic forces created by the proton density difference causes adhesion of clay masses. The adhesion resulting from clay-water interaction is believed to be the dominant factor in the stickiness and balling tendencies of these shales.
An organo-aluminum complex has been synthesized, which strongly adsorbs onto a clay surface forming an organo-aluminum-clay complex. The formation of this complex decreases the interaction between the particle surface and water, thus greatly reducing the adherence factor.
A number of test wells have been drilled successfully using this physicochemical approach in various parts of the world. Data and drilling performance criteria are presented in this paper, and a comparison with previous wells drilled with other fluids is given.

INTRODUCTION
The finding of new petroleum reserves to meet the increasing demand for energy has pushed exploratory efforts towards the various continental shelves and deltaic regions of the world. The cost of finding these new resources and producing them has reached enormous proportions, as evidenced by the recent exploration activities in the North Sea.
Fluid Loss Additive Seriously Reduces Fracture Proppant Conductivity and Formation Permeability
Authors: Pye D. Stephen , Smith Warren A. 
Published: December 2007

This paper was prepared for the 48th Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Las Vegas, Nev., Sept. 30-Oct. 3, 1973. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon 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 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
Fracture proppant conductivity can be severely impaired by certain fluid loss additives. Laboratory tests show this reduction in conductivity is frequently more than 50 percent, which tends to nullify any effect of percent, which tends to nullify any effect of fracture extent beyond a few feet from the wellbore. oil soluble additives appear be a possible solution to this problem. Other possible solution to this problem. Other experiments indicate that formation permeability is severely reduced at high permeability is severely reduced at high differential pressures. This damage to permeability would seriously impair the permeability would seriously impair the productivity of any zone which was not productivity of any zone which was not fractured.

Introduction
Hydraulic fracturing is a widely used and accepted method for stimulating the production from wells. The techniques and production from wells. The techniques and procedures, however, are constantly changing, procedures, however, are constantly changing, particularly in the past few years. Justification particularly in the past few years. Justification for using a new technique is naturally based upon its capacity to increase the production improvement from the stimulation.
Of the multitude of variables which determine the effectiveness of a hydraulic fracturing operation, only a few are easily controlled—fracturing fluid properties (viscosity, fluid loss, etc), injection rate and type of proppant. These three parameters influence the fracture length and the fracture conductivity.
Frequently, these variables are extremely difficult to evaluate from field results since tests on a large number of similar wells would be required. While a few of the new procedures have been documented with field tests, most of the recent changes in technique or procedure have been recommended on the basis of analog, mathematical or laboratory models of the fracturing process.
Laboratory models were used in our investigation to study the effect that fracturing fluids, and more particularly fluid loss additives, have on productivity.
Transient Method Implemented Under Unsteady-State conditions For Low and Very Low Permeability Measurements on Cuttings
Authors: Marsala A.F. , Figoni A. , Brignoli M. 
Published: December 2007

Abstract
This paper reports a complete description of a device, a numerical method and of a new experimental procedure that allows direct measurements of low and very low permeability on cuttings (small fragments of rock, down to 1–2 mm in diameter).
The results show the determination of shale permeability even in the order of few nanodarcies. This technique is included in a complete package of standard' measurements on cuttings (sonic, rock strength, porosity) and in particular it extends the range of permeability measurements, technique already developed for reservoir cuttings and presented elsewhere. Thanks to this technique it is now possible to obtain, while drilling, a complete permeability log' of rock formation even for very low values.
Traditionally, permeability can be determined on cores by a steady state flow rate measurement. To measure a permeability from 0.1 mD to 1 nD (=10-9 darcies) the pulse decay technique can be used. This technique is a transient method and it is implemented under unsteady-state conditions.
In a rock saturated with fluid, diffusion of a pressure gradient is much faster than the steady state flow of fluid itself. The transient method is essentially a measurement of the pressure gradient diffusion and it is applicable even for very low permeable materials. The technique applied to cuttings is described in this paper.
Some limits are intrinsic in this technology: the measurement is feasible only if cuttings have at least few mm in diameters; no discrimination is possible from a cutting's measurement in order of directionality (horizontal or vertical permeability); only matrix permeability is revealed from this measurement as no fracture permeability is detectable from the sole measurement on cuttings.
A new experimental apparatus is developed to run the tests, even at the rig site. Field results are presented and discussed along with the numerical methods to calculate permeability values from unsteady-state tests in the transient method.
From a rock mechanics perspective one application of the permeability log while drilling in shale formations is the calibration of wellbore stability models. Permeability is one of the key parameters which governs pore fluids re-equilibrium while and after drilling and definitely affects the time related instabilities.
Using this technique in the laboratory, along with other measurements on cuttings representative of field situations, improves shale-fluid interactions evaluation, aiming at optimising mud selection.
P. 33
Stress Trajectories in the Neighbourhood of Fault Zones
Authors: Pourjavad M. , Bell J.S. , Bratli Rolf K. 
Published: December 2007

Abstract
Stress trajectories around faults have been simulated with a 3-D finite element model, based on 8-model brick elements in five layers. Preliminary simulations imply that stress trajectory deflections in the neighbourhood of fault zones can be expected if there is a large geomechanical contrast between the fault zone and the adjacent rocks and if far field stress anisotropy is small. On the other hand, if the horizontal stress anisotropy is large, significant stress deflections appear unlikely to occur near a fault. Within a softer' fault zone H will be aligned approximately parallel to the trend. Magnitudes of maximum and minimum stress are modelled for soft and hard fault simulations. Significant modifications in stress magnitudes developed in the vicinity of the fault zones.
P. 33
Borehole Breakouts in Berea Sandstone: Two Porosity-Dependent Distinct Shapes and Mechanisms of Formation
Authors: Haimson Bezalel C. , Song Insun 
Published: December 2007

Abstract
We conducted laboratory-drilling experiments in Berea sandstone blocks of two different porosities in which borehole breakouts were induced under several truly triaxial far-field stress conditions. We used a petrographic microscope to study thin sections of the drilled boreholes and observed the mechanism of failure that ultimately resulted in breakout formation. In lower porosity Berea sandstone (17%) we identified a breakout failure mechanism that is similar in its final V' shape to that observed in granite and limestone, and occurring along the ah spring line. This shape results from successive spalling of slabs initiated by dilatant intragranular microcracking subparallel to a~ direction, The cracks extend intergranularly due to the much lower toughness of the rock matrix, and reach the borehole wall along tortuous diagonal paths, forming a wide-angle V'- shaped notch. A dramatically different failure mechanism was observed in the higher porosity sandstone (22.5%), a more weakly cemented but still competent Berea sandstone. Breakout failure occurs at the same locations around the borehole as above, but its final shape is best described as a narrow linear slot or fracture perpendicular to aft direction. Our interpretation of the mechanism forming this type of breakout is that it is related to the weak bonding between the quartzitic grains as inferred from the high porosity of the rock, which also implies less cementing matrix material between the grains. Under sufficient far-field stresses, high stress concentration around the hole (along the ah springline), causes the collapse of the weak and sparse matrix, and partially or totally debonds the quartz grains. The disaggregated grains spall off in non-dilatant fashion, creating a higher stress concentration behind them. This in turn facilitates further disintegration of the cementing matrix, and removal of additional grains along the ah spring line. The newly observed breakout type, different from any previously experienced, could have major significance in studying instability problems in wellbores intersecting poorly consolidated sandstones.
P.229
Thermoporoelastic Analyses of Inclined Boreholes
Authors: Li X. , Cui L. , Roegiers J.-C. 
Published: December 2007

Abstract
This paper presents an analytical solution for the combined temperature, pore pressure and stress distribution around a circular, infinitely long borehole drilled in a poroelastic media of infinite extent. The borehole is assumed to be subjected to a constant pressure and temperature difference applied by the drilling fluid, and the borehole axis is arbitrarily oriented with respect to the in-situ principal stresses. Utilizing a loading decomposition scheme, the problem is solved by the superposition of three fundamental problems: a thermoporoelastic plane-strain problem; an elastic uniaxial stress problem; and an elastic anti-plane shear problem. The potential impacts of non-isothermal drilling processes on inclined borehole stability are illustrated through an application example.
P. 443
The Effect of Phase Behavior on Recovery Efficiency with Micellar Floods
Authors: Lorenz P.B. , Bayazeed A.F. 
Published: December 2007

Abstract
Phase diagrams were developed for two oils and two combinations of petroleum sulfonate and alcohol to determine whether such diagrams are useful as a screening test for surfactants to be used in micellar flooding. The diagrams illustrate the effects of surfactant concentration, salinity, cosurfactant, calcium, and tripolyphosphate; temperature and pH effects were also examined. Because of the importance of rheological properties in recovery, an aqueous micellar fluid was properties in recovery, an aqueous micellar fluid was studied. Viscosity data were supplemented by conductance measurements to get a better understanding of the colloidal changes taking place. A few laboratory micellar floods showed an encouraging correlation with phase behavior.

Introduction
Because of the improved economic climate for tertiary oil recovery and the technological promise of micellar flooding, the Bureau of Mines is supporting the development of this technique in laboratory and field tests. Screening tests for micellar fluids are needed to determine the optimum formulation for a particular reservoir. particular reservoir. The term "micellar fluids" here designates emulsions produced by blending petroleum sulfonate, an alcohol as a "cosurfactant," and brines. The term applies to a surfactant at above its critical micelle concentration. There is no sharp boundary between micellar flooding and other types of surfactant flooding.
Since the pioneer work of Gogarty, Davis, and coworkers, fluids of higher oil content have been tested in the laboratory and field by Holm and others, and fluids of higher water content have been studied elsewhere. Related work with petroleum sulfonate surfactants has been reported from petroleum sulfonate surfactants has been reported from several laboratories. The various micellar fluids differ in viscosity and homogeneity, and in their response to salinity, temperature, and the presence of divalent ions.
It is often assumed that the most effective micellar fluids for tertiary recovery are those that best solubilize crude oil, but this assumption is open to some question. If, however, it can be supported by investigation, it could form the basis for screening tests. This was a major reason for undertaking the present work. present work.
Clean Air and the Petroleum Industry in West Texas
Authors: Short Charles Gregory 
Published: December 2007

Abstract
For a number of years the oil and gas fields of West Texas have supplied Texas and the nation with large amounts of fossil fuel. In recent years the Texas Air Control Board has adopted regulations which directly affect the exploration, production, and processing of these energy sources. The purpose of this paper is to show how adopted air pollution control regulations affect the various pollution control regulations affect the various phases of development of these fuel sources phases of development of these fuel sources in this age where concern for both a clean environment and abundant energy supplies is paramount. paramount

Introduction
In 1967, the 60th Texas Legislature passed the Texas Clean Air Act. The stated purpose of the Act was to "…safeguard the air resources of the state from pollution by controlling or abating air pollution and, emissions of air contaminants, consistent with the protection of health, general welfare, and physical property of the people, including the esthetic enjoyment of the air resources by the people and the maintenance of adequate visibility." The Act establishes the Texas Air Control Board as the state air pollution control agency, and names the Board as the "principal authority in the state on matters relating to the quality of the air resources in the state and for setting standards, criteria, levels, and emission limits for air contaminants and pollution control." The Act also provides for an Executive Director to be administrator of air control activities for the Board. His responsibilities include any and all things necessary to achieve the purposes and objectives of the Act and to purposes and objectives of the Act and to provide general supervision over all personnel provide general supervision over all personnel employed by the Board. The Executive Director has established 12 Air Quality Control Regions in the state. Within each region the Executive Director has established a regional office at a convenient location. These regions and their corresponding regional offices are designated in Figure 1. The Regional Supervisor is responsible for the operations of the regional office as well as all air pollution control activities within his assigned region. In January 1972 a regional office of the Texas Air Control Board, Air Quality Control Region 6, was established in Odessa, Texas. From the time of establishment of the Odessa regional office it became apparent that the largest number of air pollution problems in the region were those directly related to the production and/or processing of oil and gas from the rich deposits in West Texas. This paper is concerned with the air pollution problems encountered by the oil and gas industry in West Texas, and how that industry might operate in compliance with the Regulations established by the Board.
Prediction Of Overpressures In The North Sea
Authors: van Baaren C. 
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.

Summary
Overpressures are encountered on the North Sea in rocks of Tertiary to Permian age. The distribution of overpressures varies from basin to basin and examples are discussed.
The mud logging techniques such as d-exponent, temperature records and wireline logging techniques such as the sonic transit time - depth plot and the shale resistivity - depth plot may indicate overpressures in specific cases.
However the adjustment of mud weights and casing setting depths in exploration and appraisal wells in the North Sea, based on the overpressure prediction techniques, is not justified generally at present due to the unreliability of the methods.

Introduction
The term overpressure is used for formation fluid pressure exceeding the normal hydrostatic fluid pressure. The formation pressure gradients vary from 0.433 psi/ft for pressure gradients vary from 0.433 psi/ft for fresh and brackish water to approx. 0.465 psi/ft for salt water with a salinity of 80000 ppm NaCl eq. Appendix 1 shows the nomenclature used.
Overburden pressure gradients calculated from bulk density logs vary from 0.80 psi/ft at shallow depths to 0.95 - 1.0 psi/ft at greater depths. These values are in agreement with the formation strength data obtained from tests carried out below a cemented casing of which results are presented in Appendix 2.
Knowledge of the distribution of overpressures will make drilling safer and will attribute to more economical casing schemes.

OVERPRESSURE PREDICTION METHODS
A summary of the overpressure detection methods is shown in Appendix 3. One group of methods has to be applied during the actual drilling phase, while the methods in the evaluation phase can be applied after the hole is drilled.
Status of Midwest SNG Operations
Authors: Krol Casimir A. 
Published: December 2007

This paper was prepared for the Second Midwest Oil and Gas Industry Symposium of the Society of Petroleum Engineers of AIME, to be held in Indianapolis, Ind., March 28–29, 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 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 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 continued difficulty in meeting demand for natural gas has forced many gas utilities to seek supplementary supply by synthetic production. Particular interest has been drawn to gasification of petroleum fractions.
From 1972 throughout 1973 the number of interested companies has increased tremendously. A number of synthetic gas plants are presently operating in the Eastern part of the United States.
In the Middle West a considerable activity has taken place also. A number of plants are in start-up or operation and at least two (2) additional plants should be in full operation during the heating season of 1974–1975.
The Peoples Gas Light and Coke Company's SNG Plant is particularly unique in that being a grass-roots plant it had to be designed with extreme care to prevent any adverse environmental impact. prevent any adverse environmental impact. As a result, special systems and methods were incorporated into the plant's complex make-up.

Introduction
Most gas utilities instituted a major program in the late 1960's to find and develop new sources of natural gas. The continued growth of energy requirements in the nation made a severe impact on the entire gas industry. Natural Gas was being used to such a great extent that it represented about 40% of the total national energy used. Since wellhead prices were controlled and no deregulation was in sight, drilling incentive dropped off to such an extent that supplies to the nation were being decreased.
A study was conducted on the advisability of producing supplementary gas supplies through such means as synthetic gas production, importing of liquefied natural gas and development of Alaska gas fields. Unfortunately, satisfaction of demands by most of these methods was not envisioned until well after 1980. The actuality of this shortage was brought to the public when on July 16, 1973, the Federal Power Commission released a statement wherein it was estimated that 15 major interstate transmission companies would be forced to curtail their firm gas contract deliveries by 1.16 trillion cubic feet.