bluuebunny/crossref_metadata_2025_split huggingface dataset:
Outcrop-Derived Quantitative Models of Permeability Heterogeneity for Genetically Different Sand Bodies
Authors: Lewis J. J. M. 
Published: December 2007

ABSTRACT
Core based reservoir data is insufficient in most cases for the accurate prediction and quantification of reservoir heterogeneity. In order to understand the scales and magnitudes of reservoir heterogeneity developed within specific reservoirs, we need to quantify reservoir heterogeneities in large two- and preferably three-dimensionally exposed outcrops of analogous sediments. Variations in depositional architecture are the main cause of reservoir heterogeneity and such variations can be hierarchically classified into a limited number of scales. This hierarchical classification can then be used as a framework with which to quantify reservoir heterogeneities in the field. To apply the data we derive at outcrop to actual reservoirs, we can adopt the sediment-body as the basic reservoir "building block". These building blocks are quantitative models of the scales and degrees of reservoir heterogeneity developed in genetic sediment-body types. Being genetically based, they are widely applicable and not reservoir specific. Seven such quantitative models are being constructed for sand-bodies within carbonate sand depositional environments. Permeability anisotropy can also be considered at a number of depositional scales and it is important to incorporate the correct scale of permeability anisotropy in reservoir simulation grid blocks.
Coring-lnduced Fractures: Indicators of Hydraulic Fracture Propagation in a Naturally Fractured Reservoir
Authors: Laubach S. E. , Monson E. R. 
Published: December 2007

ABSTRACT
Efficient hydraulic fracture treatment of low-permeability reservoirs depends on reliable prediction of the stimulation fracture strike, which generally is parallel to the maximum horizontal stress. Coring-induced fractures can be used to predict the strike of stimulation fractures if coring-induced fractures are aligned with the maximum horizontal stress. Our study (1) determines the orientation of coring-induced fractures in East Texas and (2) compares the strike of coring-induced fractures to indicators of stress direction and stimulation fracture strike. We used descriptions of 565 fractures in 1,802 ft (549 m) of core from seven wells in the Lower Cretaceous Travis Peak Formation, a low-permeability sandstone and shale unit approximately 2,000 ft (609 m) thick that produces gas in much of East Texas. Fracture imaging logs were available from three study wells. Stimulation fracture azimuth was independently determined by monitoring microseismicity during fracture treatment. Mean strike of coring-induced petal and petal-centerline fractures is parallel to the east-northeast azimuth of maximum horizontal stress determined from core strain recovery, borehole breakouts, and strike of fractures created in stress tests and hydraulic fracture treatments. Natural and coring-induced fractures are not parallel, but the difference in strike is generally small (&lt;10 degrees). Petal and petal-centerline fractures are useful for predicting the strike of stimulation fractures. Their usefulness is limited by the precision of core orientation methods.
Acoustic Emission Interpretation for Estimating Hydraulic Fracture Extent: Laboratory and Field Studies
Authors: Sarda J-P. , Perreau P. J. , Deflandre J-P. 
Published: December 2007

Abstract
It is useful to map hydraulic fractures in order to improve the rate of success of such operations and to optimize the pattern of stimulated wells. The proposed method can be used during a minifracturing or prefracturing operation and necessitates a downhole 3D acoustic detector clamped in the well. A few to a few dozen cubic meters of gel are injected during fracturing phases, and the acoustic activity is recorded after every injection. Then signals containing apparent P and S waves are analyzed to determine the directions and distances of the emitting sources. A number of arrivals cannot be interpreted easily, in particular those corresponding to refractions along the casing. Three field examples corresponding to a vertical, a deviated and a slant well are given. Knowing the P and S wave velocities in the different layers and a careful choice of the tool position are essential to the success of the method.
An Assessment of Borehole Seismic Fracture Diagnostics
Authors: Thome B. J. , Morris H. E. 
Published: December 2007

ABSTRACT
A five year effort to apply triaxial borehole seismometer technology to mapping hydraulic fractures by detecting microseismic events associated with the fracturing process has been completed. During this time, a number of evolutionary improvements to the borehole receiver have lead to a unique sensor array geometry consisting of four geophone axes, positioned so that each axis makes the same angle with both the horizontal plane and the plane of the clamp arm. This geometry is designed to allow the use of identical geophones on all axes in order to avoid differences in resonance properties of horizontal and vertical geophones, and to distribute any effects of clamp arm resonance uniformly to all axes. Each axis consists of four geophones wired in series to provide four times the sensitivity of a single geophone.
The receiver includes downhole amplifiers which provides two gains, 112 dB for weak seismic sources and 100 dB to avoid saturation from strong seismic sources. The amplified seismic signals from the eight data channels are frequency division multiplexed onto frequency modulation subcarriers for transmission to the surface through a single conductor wire line. This combination of multigeophone reception, downhole amplification and frequency modulation data transmission results in a very sensitive receiver, almost completely free of electric noise. The data from two downhole receivers in offset wells are recorded on tape to provide a continuous record of all signals. Simultaneously, all channels are demodulated, filtered and sent to a signal analyzer which triggers analog-to-digital conversion when any channel exceeds a preset voltage.
An event location scheme, based on primary wave polarization and using directional statistics, computes the location of microseismic events with error estimates. Over 700 microseismic events were digitized during a recent stimulation experiment. Analysis of these data resulted in 160 microseismic event locations, some as far as 450 ft (137 m) from the receiver. The azimuth determined from event locations agrees reasonably well with the predicted fracture azimuth, the head agrees with temperature log tops, and fracture height is in good agreement with fracture model calculations. Wing lengths are less than fracture model predictions unless fracture width is larger than expected.
Effects of Flow Regimes on Production Logging Instruments' Responses
Authors: Roesner R. E. , LeBlanc A. J. , Davarzani M. J. 
Published: December 2007

ABSTRACT
Production logging instruments' responses in multiphase flow wells are frequently confusing due to the effects of various parameters. An important parameter is the type of flow regime encountered during the survey Special knowledge of the flow pattern is necessary if a meaningful analysis of the data is to be made. Some of the parameters affecting the flow regime are flow rate of each phase, pipe diameter, and wellbore deviation angle.
Wells often produce a concurrent flow consisting of two or three phases. Due to different fluid properties between phases, more than one flow regime might be encountered in a survey depth interval. The cause of this transition from one flow regime to another is due in part to an increase in fluid velocity. This increase may be caused by additional fluid entering the well from perforations or from expansion due to pressure changes as the fluid moves upward through the well.
The sensitivities and operating ranges of selected production logging instruments were studied by subjecting them to different parameters that directly affect the flow regime and the instruments' responses. The logging instruments selected for testing were divided into two categories: Row rate and fluid composition.
Examples are presented that demonstrate how a slight deviation angle or an increase in flow velocity alters water fallback, holdup, and the instrument's response. Typical applications of production logging instruments are described with emphasis placed on the effects of two-phase flow. After characteristics of particular flow regimes have been developed, guidelines for instrument selection, data acquisition methods, and log quality control are given.
Reproducible Rheological Measurements on Crosslinked Fracturing Fluids
Authors: Prud’homme R. K. , Ellis S. , Constien V. G. , Knoll S. 
Published: December 2007

ABSTRACT
Reproducible rheological measurements on crosslinked fracturing fluids are necessary to design fracturing operations and to evaluate crosslinked gel formulations. We present the results of cooperative tests on identical gel formulations (HPG polymers crosslinked with titanate and zirconate crosslinkers) run using different rheological instruments: Fann 50C, Rheometrics Pressure Rheometer, and a reciprocating capillary viscometer. With attention to "dynamic mixing", temperature history, shear history during crosslinking, and flow field uniformity, it is possible to obtain comparable data from all three instruments. This has not been possible previously. The effects of temperature and shear history on the evolution of gel rheology is shown to demonstrate how these variables affect the reproducibility of measurements. Experiments on "fast" and "delayed" crosslinking systems show that delaying crosslinking until after exposure to high shear increases the viscosity of the gel.
Oil/Water Emulsions for Pipeline Transport of Viscous Crude Oils
Authors: Pilehvari A. , Saadevandi B. , Halvaci M. , Clark P. E. 
Published: December 2007

ABSTRACT
Heavy (viscous) crude oils have become an increasingly important source of hydrocarbons in many parts of the world. Transport of these viscous crudes from the source to the refinery can be a problem. In a number of producing areas, a pipeline is in place, but the line was designed for lighter (less viscous) crudes. Pipeline transport can be effected by heating, dilution with lighter fractions, or thermal viscosity breaking. All of these techniques are expensive and are not practical in many situations. Techniques are needed to reduce the pumping costs without significantly increasing the handling costs at: either end of the pipeline.
High oil content oil-in-water emulsions have been shown to be a viable alternative to the techniques mentioned above. Dramatic decreases in viscosity can be achieved while transporting a fluid which has an oil content of 70% or greater. A knowledge of the rheological behavior of these emulsions, under both laboratory and field conditions, is important.
In this study, four different viscous crude oils were used. The viscosities ranged between 2000 and 500,000 (estimated) centipoise (2.0 to 500 Pa·s). The emulsions ranged from 60 to 72.5% oil in tap water stabilized with an emulsion stabilizer.
Rheological measurements were carried out with a tube flow viscometer equipped with three tube sizes and a concentric cylinder viscometer (Rheometrics Pressure Rheometer). The data obtained showed that the shear stress-shear rate behavior of the emulsions are highly dependent on oil droplet size. For a given oil concentration, the non-Newtonian character and the apparent viscosity increased with decreasing droplet size. The majority of the emulsions showed shear thinning behavior at low shear rates (below 50 s−1) and Newtonian behavior at shear rates above 1000 s−1.
These data show that the power law model is insufficient for the whole range of shear rates. A three parameter model needs to be considered. Results show that oil droplet size is the dominant factor in the behavior of emulsions. The influence of mixing intensity and duration while preparing the emulsion and emulsifier concentration on the resulting droplet size were investigated. Pipe flow data were collected for scale-up studies. Data were collected in both the laminar and turbulent flow regimes. This study reveals that careful laboratory testing and scale-up is needed prior to the designing of pipeline systems for the transport of heavy crude oils as emulsions.
Carbonate Stimulation Optimization Using Hydraulic Fracturing Field Testing
Authors: Huckabee P. T. 
Published: December 2007

Abstract
Stimulation designs of the Wasson San Andres dolomite have been optimized at the Bennett Ranch Unit through the use of hydraulic fracturing field tests. In-situ measurements of fluid leak-off, vertical distribution of minimum horizontal stress, and fracture propagation overpressures are incorporated into routine stimulation designs of this West Texas carbonate. This "state of the art" design procedure has resulted in a significant increase in oil rate productivity over the more conventional San Andres stimulation techniques. Additionally, the procedure has significantly reduced both the cost per barrel of oil increase, and the water rate increase typically observed foilowing stimulations at the Bennett Ranch Unit.
The hydraulic fracturing field test procedure is described and the interpretation summarized. Observations from the test are discussed and application of the data in stimulation designs is presented. Stimulation procedures evaluated in this study include; 1) fracture acidizing, 2) sand propped fracture treatments, 3) rock salt diverted acid treatments, and 4) acid soaks (or squeezes). A summary of the productivity results, by stimulation type, is presented and discussed.
Trends in World Crude Oil Production and Reserves
Authors: Babson E.C. 
Published: December 2007

American Institute of Mining, Metallurgical and Petroleum Engineers, Inc.
This paper was prepared for the 42nd Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Houston, Tex., Oct. 1–4, 1967. 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
Trends in the growth of crude oil production and reserves in various areas of the world are presented graphically, illustrating the dramatic changes in distribution of crude oil availability during this period. While Eastern Hemisphere reserves passed those of the Western Hemisphere in 1945, production remained below that of the Western Hemisphere until 1962.
Reserve growth trends have been projected ten years into-the future in an effort to evaluate the future distribution of crude oil availability. It appears likely that U. S. reserves will decline, Western Hemisphere reserve growth will flatten, and Eastern Hemisphere reserve growth will continue approximately the present rate.

Introduction
The purpose of this discussion is to review past trends of crude oil production and reserves in various areas of the world in the hope that this study will throw some light on the future distribution of the world's oil resources. The importance of the subject is almost self evident because a modern industrial economy is almost completely dependent on an adequate supply of petroleum products and even the economies of the less developed nations would be severely crippled if the supply of these products were interrupted. Events of the last few months have reminded us dramatically that the location of petroleum reserves can be a matter of critical importance.
While some idea of present and future availability of crude oil from an area can be obtained by a study of production trends, reserves can be a more reliable guide although it is recognized that even reserve trends are not completely adequate for this purpose. The difficulty is in some degree the result of our concept of the meaning of the term "reserves". A proved petroleum reserve can be defined as a quantity of hydrocarbons, the presence of which can be proved to a high degree of probability and which can be recovered at a profit by presently known methods.
Application of Hydraulic Jet Pump Technology on an Offshore Production Facility
Authors: Boothby L. K. , Garred M. A. , Woods J. P. 
Published: December 2007

ABSTRACT
A multiwell hydraulic jet pump lift system was installed on Tenneco Oil Company's Main Pass 297 "A" platform during the fall of 1986. The need for increasing reservoir voidage rates, beyond those observed using conventional gas-lift methods, was the main catalyst for this high volume lift system. The inefficiency of the gas lift system was attributed to the low gravity crude (19.4 degrees API), low reservoir pressure, and highly deviated wellbores (40–50 degrees).
Technical Considerations for Deepwater Pipeline Installation and Connections
Authors: Brown R. J. 
Published: December 2007

ABSTRACT
During the past decade hydrocarbon energy related supplies have evolved from shortage to surplus. Naturally then, the cost of this energy has varied considerably with the market availability and demand. During the latter 1970's and early 1980's this market price supported exuberant installation costs, and the producers were still able to make attractive profits. As over production and competition increased the market experienced a drastic fall in price per barrel of oil produced. Also the number of extra large and giant oil fields have diminished which means the small or marginal fields are the largest number remaining for development. Marginal fields, because of their size, in the past, have been thought to be uneconomic by virtue of their costs of development based on the conventional methods of construction. In several recent developments the flowline and export lines have cost more than the drilling and production components. Hence, the Oil companies are now looking to new solutions to reduce costs to justify the development of new and marginal fields. With this new cost restraint has come re-appraisals of methods for developing fields and their transportation systems. A part of this re-appraisal of the pipelines is to look carefully at the installation methods from the stand point of cost of operations offshore specifically looking at the economics of the spread sizes and relate these to actual working and stand-by times.
The operating companies are looking more and more to engineering innovation to provide them with cost effective approaches for developing these transportation systems. The engineers problem now is to develop the methods and then convince the various non-technical management within the large operating companies that innovation can infact provide a low cost solution to their problems. This places a specific demand on the engineers abilities which, to date, have not been required to solve this type of specific situation and problem.
This paper describes the innovative technique of bottom towing coupled with diverless tie-ins for the Placid Green Canyon Block 29 Development. Also described is the latest techniques which have evolved making this towing technique cost effective and within acceptable risks during the pipelines installation, stabilization, and connection process.
NMR Imaging for Core Analysis
Authors: Edelstein W. A. , Vinegar H. J. , Tutunjian P. N. , Roemer P. B. , Mueller O. M. 
Published: December 2007

ABSTRACT
2 Tesla, 12" horizontal bore NMR systems have been adapted for imaging/spectroscopy of oil cores. Strong and fast shielded gradients (up to 18 G/cm with a settling time of less than a few hundred microseconds) have been developed to produce good quality images of cores with very short relaxation times. Accurate and rapid spectroscopic porosity measurements have been made on carbonate and sandstone whole cores, including some shaly samples. Porosity images have been made of carbonates and clean sandstones. Oil/water saturation has been determined spectroscopically in carbonates and clean sandstones, and selective water and oil images have been produced. Other NMR nuclei, such as H2 (deuterium), C13, F19, and Na23 can be used for a variety of oil core applications. In particular, we have produced C13 spectra of oil in many different rocks; these spectra can potentially determine oil saturation in shaly materials where the proton NMR lines of oil and water overlap.1
Effect of Drainage Area Shapes on the Productivity of Horizontal Wells
Authors: Mutalik P. N. , Godbole S. P. , Joshi S. D. 
Published: December 2007

ABSTRACT
This paper presents a technique to forecast the production from horizontal wells in rectangular drainage areas. The technique is useful for wells located either centrally or off-centrally in the areal drainage plane.
Analytical pressure transient solutions were used to calculate the shape factor, СA, and the corresponding equivalent skin factor, sCa. Moreover, dimensionless time at which the pseudo-steady state begins is reported for centered and off-centered horizontal wells and fully penetrating infinite-conductivity vertical fractures. These results are presented in the form of easy to use correlations. Furthermore, these correlations were tested by analyzing the relevant pressure transient data reported in the literature.
The pseudo-steady state shape factor, СA, and skin term, sCA, for a horizontal well approaches fully penetrating infinite-conductivity vertical fracture for very large values of dimensionless horizontal well length, LD. Knowledge of shape factor, СA, and of corresponding beginning of pseudo-steady state time, tDA, pss would facilitate computation of the horizontal well production forecast from a corresponding infinite-conductivity, fully penetrating vertical fracture forecast.
The methods for prediction of the inflow performance relationship for horizontal wells is also outlined, using example problems representative of horizontal well applications in on-shore and off-shore areas.