bluuebunny/crossref_metadata_2025_split huggingface dataset:
Design and Performance Properties of Oilfield Fiberglass Tubulars
Authors: Huntoon G. G. , Alkire J. D. 
Published: December 2007

Abstract
Fiberglass reinforced pipe (FRP) has numerous advantages over steel pipe in oil field applications. Dominant among the advantages is resistance to corrosion and ease of handling. Historically, most FRP has been used for low-pressure beam pump well flowlines. Low-pressure applications usually demand only minimal pipe performance to be successful. In recent years FRP has been thrust into more demanding applications, such as high-pressure flowlines and downhole tubing strings. Field experience made it clear that the majority of methods used for design of these earlier applications were not adequate in high-pressure services. A rating method for high-pressure line pipe and tubing has been developed by API task groups. The rating method is based on test data that measures the long-term performance of FRP tubulars. Amoco has initiated an in-house program to develop this test data on commercially available FRP products. Results of this program to date have been most enlightening in regard to FRP behavior especially in relation to performance claims by manufacturers. In one case, slight changes in pipe design by the manufacturer more than doubled the long-term strength. Temperature effects have been measured and for some products are very dramatic, producing as much as 50% decrease in strength. Tests have shown that changing the type of connection can drastically affect system performance. The development of specifications can greatly influence the successful application of fiberglass tubulars.
The Asphaltic Properties of an Apparently Ordinary Crude Oil May Lead to Re-Thinking of Field Exploitation
Authors: Garland E. 
Published: December 2007

Abstract
The discovery of a light but abnormally asphaltic oil field held some surprises for producers who are not used to handling such oils. The crude in question has its asphaltenes which destabilize during their raising in the tubing.
This caused a difficult problem of sampling. Moreover, within a few weeks, most of the surface equipment were plugged with asphaltenes deposits. It was consequently necessary to re-design the production chain for processing and transporting the crude, and to account for the inevitable floculation and deposit of these asphaltenes.
The intensive laboratory studies which supported this work, are presented herein, as well as the tests on an 500 meters loop that we realized to study the risk of plugging the pipeline at low points, after a shut down.
All these lead to a production project, implemented on site, which is evaluated after eighteen months of operation.
Oilfield Fluid Rheology: The Use of a Controlled Stress-Measuring System to Determine Oilfield Fluid Properties
Authors: Clark P. E. 
Published: December 2007

Abstract
Historically, controlled shear rate instruments have been used to determine the rheology of fluids used in the oil field. Construction of controlled shear instruments is easier, and the electronics to control the instruments are readily available. In the last few years, technological advances in electric motor design have made it possible to build a controlled stress instrument which is both accurate and easy to use.
Particle settling is one example of a stress controlled process that is found in the oil field. Measurements made with controlled shear rate instruments have not been particularly successful in predicting particle settling behavior. Controlled stress measurements have been shown to be a better measure of fluid properties for the prediction of particle settling. Yield stress measurements are another area where controlled shear rate instruments are difficult to use. In a controlled stress instrument, a stress is placed on the fluid and the resulting displacement is measured. Small stresses can be applied in a stepwise fashion resulting in accurate determinations of yield points.
This paper covers the aspects of controlled stress rheological measurements and gives several examples of the use of these measurements in the evaluation of oil field fluids. Applications to polymer solutions and fracturing fluids will be discussed.
A Field Evaluation of a Gravel-Diverted Acid Stimulation Prior to Gravel Packing
Authors: Matherne B. B. , Hall B. E. 
Published: December 2007

ABSTRACT
Chevron USA Inc. has successfully applied a completion technique that is an enhancement to the conventional circulating gravel pack. The technique requires acidizing prior to gravel packing utilizing a gravel slurry to divert the acid stages and to pre-pack the perforations. Gravel placement and diverter effectiveness are indicated by using radioactive tracers and the spectral gamma ray logging tool. Calculated gravel placement by the two completion methods is compared. This enhancement to the circulating gravel pack has resulted in more efficient and greater well productivity.
Confirmation of Thermodynamic Modeling of Reservoir Fluid-Rock Systems with Subsurface Data
Authors: Riese W. C. , Riese A. C. 
Published: December 2007

Abstract
Thermodynamic modeling of reservoir fluid-rock systems can accurately predict the tendency for scale to form in a formation during completion, stimulation, and production, and can be useful in identifying well bore fluids which exacerbate this tendency if they are employed during any of these procedures. The calculations which we employ in modeling these reservoir systems account for activity coefficients via the extended Debye-Huckel relationship and for elevated temperatures with van’t Hoff or Kirchoff equations. The description of reservoir environments that can be obtained using these thermodynamic relationships is more accurate than any obtained using Stiff-Davis or similar approaches. Concurrent consideration of all potential precipitation phases is also only possible with this type of analysis.
Characterization of the Oligocene age Vicksburg Formation reservoirs in the Tabasco field in Hidalgo County, Texas began after a well failed to come on line as predicted: fluids introduced to the wellbore and formation during testing and completion procedures were suspected to have caused formation damage in spite of the fact that these same fluids had been used successfully in other wells in the same field without causing apparent damage.
Our modeling of the fluid-rock reservoir systems demonstrated that these CaBr2-bassd fluids were in fact the probable causes of damage to the formation and thus accounted for the poor reservoir performance. Our modeling also indicated that KCl-based fluids would have induced scale precipitation had they been used as alternatives.
Subsequent frac stimulation of another well in the field allowed us to confirm these predictions. During frac cleanup, some of the proppant used was flowed back and found to be coated with a foreign substance. This coating proved to be composed of aragonite, a finding consistent with the results of our modeling and our prediction that introduction of KCI-based fluids to the formation would result in carbonate and other scale precipitation.
A Three-Dimensional Hydraulic Propagation Theory Coupled With Two-Dimensional Proppant Transport
Authors: Lee W. S. , Jantz E. L. 
Published: December 2007

ABSTRACT
A three dimensional hydraulic fracture propagation theory, coupled with two dimensional proppant transport, has been developed. Principal features of the theory are listed below. Initial fracture is assumed to be initiated from a line source with length equal to the perforated interval, and the fracture will, propagate as an ellipsoid if the formation is homogeneous with no stress variation.Fracture shape deviates from the perfect ellipsoid as soon as the fracture reaches a layer having stress change.Pressure drops from the center of the fracture in the perforated interval to fracture tips in all directions are equal. Thus the width profile in every flow line varies according to the stress variation in that direction.Proppant is assumed to move with equal velocity as fluid along the flow line but has an additional vertical settling velocity which allows proppant pumped at earlier stages to mix with proppant pumped in latter stages. Settled proppant will continue to fall to a place where fracture is too narrow to allow further drop.Fluid losses are considered for both the pay zone and non-pay zones. With state-of-the-art improvement in microfracturing processes, fluid losses in non-pay zones are measurable and should be measured.
The new theory can handle the special case of a fracture that is confined to a constant gross height either from above or below.
Deficiencies of two dimensional models are removed by the new theory: Assumption that constant height is achieved instantly.Assumption that the width at any vertical plane is either constant (Christianovich and Zheltov)1 or with a fixed shape (Perkins and Kern).2 Subject paper presents development of theory and an example of selecting proppant-laden fluids for optimum proppant transport.
Nurturing the Geology-Reservoir Engineering Team: Vital for Efficient Oil and Gas Recovery
Authors: Sessions K. P. , Lehman D. H. 
Published: December 2007

ABSTRACT
Of an estimated 482 billion barrels (76.6 Gm3) of in-place oil discovered in the U.S., 158 billion (25.1 Gm3) can be recovered with existing technology and economic conditions.1 The cost-effective recovery through infill drilling and EOR methods to recover any portion of the remaining 323 billion barrels (51.4 Gm3) will require a thorough understanding of reservoirs and the close cooperation of production geologists and reservoir engineers.
This paper presents the concept of increased interaction between geologists and reservoir engineers through multi-functional teams and cross-training between the disciplines. A discussion of several factors supporting this concept is covered, including educational background, technical manpower trends, employee development, and job satisfaction. There are several ways from an organizational standpoint to achieve this cross-training, with or without a formal change in job assignment. This paper outlines three approaches, including case histories where each of the approaches has been implemented and the resulting benefits described.
Applicability of Fractals to the Description of Viscous Fingering
Authors: Fanchi J. R. , Christiansen R. L. 
Published: December 2007

ABSTRACT
The applicability of fractals to the description of fluid flow in porous media is evaluated. Special attention is paid to determining the feasibility of using fractals to predict the performance of unfavorable mobility displacement processes. The state-of-the-art of viscous fingering research is established before the fractal concept is explained. The application of fractals to fluid flow problems is then considered.
Laboratory measured fractals are shown to have potential usefulness as predictors of such field-scale information as sweep efficiencies and breakthrough times if the fractal dimension of a displacement process is scale independent. Calculations using data from the literature and laboratory experiments with a radial Hele-Shaw cell indicate that viscous fingers do not have scale independent fractal dimension except in regions of fluid flow which are free of steep pressure gradients. Steep gradients are usually present near sources (injectors) and sinks (producers). Thus, fluid displacement in regions near wells does not appear to be fractal.
Pressure Transient Behavior of Naturally Fractured Reservoirs Considering the Effect of High-Velocity Flow
Authors: Villalobos-L. H. , Rodriguez F. , Samaniego-V. F. 
Published: December 2007

ABSTRACT
The influence of high-velocity flow of a liquid of constant compresibility on the transient pressure behavior of a naturally fractured well is studied in this paper. The study is based on a numerical solution to the radial liquid flow problem as described by Warren and Root but considering high-velocity flow through Forchheimer equation. An expression for the rate-dependent pseudo-skin term is derived. It is demonstrated through an integration of the Forchhaimer equation and the simulation of drawdown tests that consider no skin damage that this pseudo-skin in essentially equal to the product Dqw, where D is the turbulent term coefficient defined as βρk/2πrwhμ. It was also found that the correlation of Ramey et al. for the end of the wellbore storage period in homogeneous systems, can be extended for conditions of high-velocity flow in naturally fractured reservoirs provided that the apparent skin s’ is used instead of the skin factor s. This study also considers the influence of high-velocity flow on pressure buildup tests. The effects of a finite formation skin and wellbore storage are also included in this work. One main conclusion of this work is that after the high-velocity flow region is stabilized, the slope of the semilog straight line for matrix dominated flow is equal to the conventional value of liquid flow of 1.151. Results of this study show that pressure derivative analysis with Bourdet et al.'s type curves are to be taken with caution when high-velocity flow affects the test.
Well Test Analysis of a Multilayered Reservoir With Formation Crossflow
Authors: Park H. , Home R. N. 
Published: December 2007

ABSTRACT
The purpose of well test analysis is to identify the type of a reservoir and to determine the parameters of the reservoir quantitatively. This work is about the well test analysis of a multilayered reservoir with formation crossflow. The results are described in two parts.
In the first part, the effects of the reservoir parameters such as permeability, vertical permeability, skin, storage coefficient, and the outer boundary conditions on the wellbore response (pressure and layer production rate) were investigated. Some important discoveries are: The wellbore response is observed in three different stages. It is identical to that of the commingled system at early time and and to that of the homogeneous system at late time. Transition occurs at intermediate time.The vertical permeability is the only parameter governing the initiation and termination of the transition from the early time commingled system response to the late time homogeneous system response.The direction of the formation crossflow is determined first by the layer permeabilities and later by the skin factors.The influence of the wellbore storage effect can be minimized by using sandface flow rate from each layer.The outer boundary conditions have only small effect on the wellbore response as long as the transition terminates before the system feels the boundary.
In addition, the early time and the late time limiting forms of the wellbore response were derived and some approximation for the late time layer production rate was suggested.
In the second part, the non-linear parameter estimation method was applied as a means to determine the layer parameters. Here, two new methods for the initial estimation of the parameter values were suggested and tested, where the early time and the late time limiting values of the layer production rate were used with the conventional pressure analysis for the average permeability and skin of the total system.
A Case Study of Improved Recovery Options in a Volatile Oil Reservoir
Authors: Schenewerk P. A. , Heath B. 
Published: December 2007

Abstract
The South Buck Draw (Dakota) Field lies on the eastern flank of the Powder River Basin along the border of Converse and Campbell Counties, Wyoming (Figure 1). The reservoirs in the field produce a volatile oil from stratigraphic traps made up of fluvial channel and marine longshore bar deposits. This paper presents the results from a field study which was made to determine the feasibility of partial pressure maintenance operations for improved recovery. While it was found that partial pressure maintenance operations could recover incremental oil, it was determined that the field would not be amenable to flooding operations because of reservoir discontinuities, a developed fracture system and highly unstable oil and gas prices.
The study showed that primary recovery in volatile oil reservoirs can be very good, generally in excess of 20% of the original oil-in-place. It also showed that estimation of original oil-in-place for volatile oils is difficult even when pressures remain above the bubble point. Additional work, done after the original study, is also presented which shows the effects of both full and partial pressure maintenance operations begun above and below the bubble point pressure. Incremental oil can be produced, however, the economics of these projects must be carefully scrutinized.
The Powder River Basin is located in northeastern Wyoming and southeastern Montana. The basin was formed as a result of deformation which occurred due to the late Cretaceous-early Tertiary Laramide Orogeny 1. The field produces from deposits of the Lower Cretaceous Fall River Sandstone which is known locally as the "Dakota Sandstone". Structure across the field is uniform with a southwest dip of approximately 100 feet per mile. Structure does not play a significant role in the production process in the field.
A Flexible Approach to Predictive Well Management Via User-Defined Strategies
Authors: Miertschin J. W. , Weiser A. 
Published: December 2007

ABSTRACT
An integral part of any reservoir simulator is the well management program. In prediction mode, this program employs some of the simulator's most complex logic in an attempt to emulate the decision-making process in the field. During predictive well management, constraints are applied at various levels (well, platform, reservoir, trunkline, etc.) and corrective actions (remedies) are taken when a constraint is violated.
The types of constraints applied and the remedial actions taken when a constraint is violated can differ greatly from field to field. The traditional practice has been to customize the predictive well management code for the particular reservoir study at hand. This ultimately results in duplication of code and effort, since no customized well management program is general enough to be applicable to all new reservoir studies undertaken. In addition, later changes in well management strategies for a given field can require coding modifications which are often cumbersome and time-consuming, since they were not part of the original program design.
Our goal was to develop an engineering tool that would give users, for the first time, essentially unlimited flexibility in performing predictive simulation. The code we have developed accomplishes this goal by allowing users essentially to write their own well management strategies by way of input data. The input data can be viewed as a high level programming language with its own special syntax and structure.
An added benefit from our approach is that it allows users to have a better understanding of exactly what the well management program is doing during the simulation, leading to fewer wasted runs and improved interpretation of results.
Thermal Zone Monitoring in an Athabasca Oil Sands Pilot
Authors: Lowe K. W. , Donovan T. E. 
Published: December 2007

ABSTRACT
The Gregoire Lake In-Situ Steam Pilot in northern Alberta, Canada investigated the use of steam for recovering heavy oil from the Athabasca Tar Sands deposit. To evaluate pilot performance, an extensive program was initiated to monitor the thermal zone development in the reservoir.
This paper presents a summary of monitoring techniques utilized to quantify reservoir response from the Athabasca McMurray pilot. The techniques examined in this paper include temperature observation wells, 3-D seismic mapping, micro-seismic mapping, surface level surveys, tracer analysis, and tiltmeters.
Cross-correlation of data from the monitoring program allowed the effectiveness of individual techniques to be evaluated. The merits and the negative aspects of each technique are discussed. Specifically, the value of new remote sensing technology is appraised.
Data analysis utilizing computer-based graphic techniques is also discussed.
Recommendations for MWD Tool Reliability Statistics
Authors: Ng F. 
Published: December 2007

ABSTRACT
MWD reliability plays a major role in the overall economic success of that service. MWD customers need to consider reliability when evaluating bids from various service companies. The least expensive bid may not necessarily correlate with the most economic service. Comparing different MWD services is difficult due to the variety of services available and the lack of a standard method for determining reliability. This paper outlines an equitable method to evaluate the reliability of different MWD services.
Petroleum Engineering Manpower Demand
Authors: Crouse P. C. 
Published: December 2007

Abstract
Over the years, the Society of Petroleum Engineers through the society-wide Manpower Committee has attempted to obtain a better understanding of manpower for the upstream side of the petroleum industry. One of the critical areas of this understanding is engineering manpower demand. In former years data has sometimes been sparse, negating any meaningful understanding of manpower drilling and production engineering needs and trends for the U.S. petroleum industry.
The basic questionnaire sent to companies is in need of revision to expand its scope to international engineering manpower for the exploration and production industry at large. Questions and data should be focused to obtain more interpretable information which would be beneficial to the overall industry and which could be easily correlated year to year.
This year the responses to the manpower survey were up significantly from 11 responses in 1988 to 23 responses in 1989. Responses were received from majors, large service companies, and independents. 5 respondents had 15-50 engineers employed in the subject sector, 5 with 51-100 engineers, 4 with 100-500 engineers, and 6 with more than 500 engineers. The remaining responses were not usuable.
Ultrahard Laser Coatings on Rock Bit Cutters for Wear and Erosion Resistance
Authors: Kar N. J. 
Published: December 2007

ABSTRACT
Ultrahard coatings are being deposited on the exterior surfaces of rock bit cutters and other downhole tools for increased wear and erosion resistance. Processing entails hypersonic spray deposition of carbide containing coatings and subsequent fusion using high powered lasers. These coatings are put on finished components within a matter of minutes without damage to the cutting elements. Field tests conducted on 7 7/8 F27 and F17 type bits have indicated above average performance of the coatings. These hard coatings dramatically decrease fluid erosion of cutter surfaces, leading to improved insert retention and the potential for increased bit performance. Implementation of this state of art technology on entire families of downhole tools will be discussed.
The Effect of Extended Nozzles and Crossflow Hydraulics with 17½-in. Tricone Bits in Northern Germany
Authors: Young T. L. , Durkee D. L. 
Published: December 2007

ABSTRACT
Penetration rates achieved with 17-1/2" bits in Northern Germany have historically been slow. Over the last 5 years, many different practical solutions have been tried to increase the ROP including higher rotary speeds, weights, different mud types, PDC bits and various hydraulic configurations. Of all of the different techniques attempted, the usage of crossflow hydraulics and extended nozzles brought about the biggest and most consistent improvement in bit performance. This paper will summarize the different nozzle configurations used and the performance rate gains achieved in each formation through the 17-1/2" section.