bluuebunny/crossref_metadata_2025_split huggingface dataset:
SWUG Story
Authors: Adams W. T. , Bouett L. W. , Gamble S. D. 
Published: December 2007

Summary
This paper documents the rise, the history, the workings, and the future prospects of a vigorous and unusual software user group. The software with which the user group mostly concerns itself is a single vender's set of independent programs, which analyze geological, reservoir, and production data stored in the vender's proprietary database structure. Since its introduction about 7 years ago, this PCbased software has become widespread in many of the client companies and much of the industry; it is often treated as a de facto standard. The user group is independent of the vender, but works closely with the vender on both bugs and enhancements. It consists of members from both small and major operating companies, service companies, as well as consultants. The group documents its work and keeps in touch with members, but it is officially, and in most other respects, an informal group. Its one official function may be unique to our industry: the group has a representative with a seat on the vender's software development committee (SDC), whose recommendations are carried directly to the vender's parent company's board of directors (BOD).
Using Distributed Processing on a Local Area Network To Increase Available Computing Power
Authors: Capps K. S. , Sherry K. J. 
Published: December 2007

Summary
The migration from central computers to desktop computers distributed the total computing horsepower of a system over many different machines. A typical engineering office may have several networked desktop computers that are sometimes idle, especially after work hours and when people are absent. Users would benefit if applications were able to use these networked computers collectively.
This paper describes a method of distributing the workload of an application on one desktop system to otherwise idle systems on the network. We present this discussion from a developer's viewpoint, because the developer must modify an application before the user can realize any benefit of distributed computing on available systems.
A Theory of Transitional and Turbulent Flow of Non-Newtonian Slurries Between Flat Parallel Plates
Authors: Hanks Richard W. , Valia Maheshkumar P. 
Published: December 2007

Abstract
A theoretical model is developed which Permits prediction of velocity profiles and frictional prediction of velocity profiles and frictional resistance factors for the isothermal flow of Bingham plastic non-Newtonian slurries in laminar, transitional, and turbulent flow between that parallel walls, in rectangular ducts of large width-to-height ratios, or in concentric annuli with radius ratios approaching unity. The theory is tested with available frictional resistance data for a range of Hedstrom numbers from 10(4) to 10(8) and a set of theoretical design curves of friction factor vs Reynolds number is developed. The model indices that for certain ranges of Hedstrom number (the non-Newtonian index) turbulence is suppressed relative to Newtonian flow behavior, whereas for other ranges of Hedstrom number, the converse is true.

Introduction
The handling of non-Newtonian fluids in turbulent motion is an important operation in many modern technological processes. Despite this fact, however, little has been done to develop models which are comparable to those available for Newtonian turbulent flow. In particular, a model of the transitional flow regime is notably lacking. Recently, a theory of laminar-turbulent transition for non-Newtonian slurries flowing in pipes and parallel plates was presented. A theory of parallel plates was presented. A theory of transitional and turbulent flow of Newtonian fluids in pipes and parallel plate ducts has also recently been developed. This theory permits the analytic calculation of the friction factor-Reynolds number curves as a continuous function of Reynolds number from the critical Reynolds number of laminar turbulent transition to any condition of turbulent flow. In this paper these two theories will be combined in order to develop a theory for the transitional and turbulent flow of non-Newtonian slurries in parallel plate ducts, rectangular ducts of large width-to-height ratio, or concentric annuli with radius ratios approaching unity.

THEORETICAL ANALYSIS
The rheological model which will be used to represent the non-Newtonian slurry behavior is the linear Bingham plastic model,
..............(1)
............(2)
For this model the laminar flow curve is given by
..............(3)
where q = 2v/b, b is one-half the distance between the plates, w = b(−dp/dz) is the wall shear stress, and D = o/ w. The end of the laminax flow, region is determined by the equations
........(4)
.........(5)
where N Rec = 4bp vc/ p is the critical Reynolds number, Dc is the critical transitional value of D and N He -16bp o/ p is the Hedstrom number expressed in terms of the hydraulic diameter for parallel plates. parallel plates. The calculation of the transitional flow field for this type of fluid will be based upon the model developed by Hanks for Newtonian fluids.
SPEJ
P. 52
An Approach to Handle Discontinuities by the Stehfest Algorithm
Authors: Chen Chih-Cheng , Raghavan Rajagopal 
Published: December 2007

Abstract
A simple, yet effective and remarkable, procedure is devised to incorporate the existence of discontinuities such as the Heaviside unit function in the construction of inverse transforms by the Stehfest algorithm. This generic method may be used to overcome difficulties in handling changes in flow rate in well-test-analysis applications.
Example applications are presented to demonstrate the viability of our algorithm. Significant savings in storage and CPU time should accrue when this method is used to compute commingled-reservoir responses. We demonstrate the application of this method to situations where layers (or perforations) are added during a test. This completion scheme has come into vogue recently and no simple procedures are currently available to compute well responses.
Improved Measurement Quality and Reliability in a Formation-Evaluation LWD System
Authors: Moake G. L. , Heysse D. R. , Jackson C. E. , Jerabek Al , Merchant G. A. , Schultz W. E. 
Published: December 2007

SummaryThis paper describes a new logging-while-drilling (LWD) tool-string, which is equivalent to a wireline triple-combo. It is composed of two tools, resistivity and nuclear, that can be combined or run separately. New features have been incorporated in the tool designs to minimize problems encountered with previous tools, and to reliably provide near-wireline-quality measurements. The resistivity tool provides symmetrical measurements of both phase and attenuation resistivity for two different transmitter spacings. This provides enough information to determine Rt, as well as to quantify invasion. The symmetrical design provides borehole compensation and ensures that the actual measure point of the tool is the same for all formations. The nuclear tool measures density, Pe, neutron porosity, standoff, and borehole diameter (caliper). The standoff measurement is used to improve the nuclear-data quality by weighting small-standoff data greater than large-standoff data. It is also used to correct the neutron porosity for standoff and borehole diameter. Logs comparing this toolstring to wireline tools are presented.
International Offshore Leasing Practices
Authors: Kaufmann Alvin 
Published: December 2007

In formulating their leasing practices, some countries are interested in maximum government revenue, others in maintaining low prices, still others in the industrial spill-overs resulting from the development of a natural resource. As a consequence of these varied goals, the regulations differ greatly from country to country.

Introduction
Governmental leasing practices are designed to achieve optimum resource development consonant with the goals of a particular country, and to provide the resource owners with a share of the income. In most countries, these practices are the same offshore and on, the major exception being the U. S. Some countries are interested in maximum governmental revenue, others in maintaining low prices, and still others in the industrial spill-overs resulting from the development of a natural resource. As a consequence of these varied goals, the regulations may differ greatly from country to country. Most of the nations of the world have coastlines with attendant offshore areas available for development. To summarize the regulations for all of these countries would be an extremely complex and, in some ways, useless task. Many of the nations have no offshore production, and thus their regulations have no real impact except perhaps negatively. Some countries have detailed petroleum legislation, others have none. In both cases, most petroleum exploration and exploitation privileges given to companies in recent years have been let after negotiation or competitive bidding. Sometimes the contract bears little resemblance to the regulations, and in such cases we have used the latest agreement available to us. For the sake of simplicity only those countries will be studied that are major offshore producers, or whose regulations illustrate a system. It should be noted that in considering the regulations we have made no judgment about what constitutes an offshore area. In all cases we have accepted, as a matter of convenience, the definition of the nation concerned. Thus, in the case of Venezuela, Lake Maracaibo would be classified as an offshore area. Offshore regulations have been discussed in some detail in a recent publication,* and so win not be repeated here. The pertinent details of regulations and contracts have been summarized in Tables 1A and 1B. These summaries are by no means definitive; they set forth only the broad outline of the individual country's regulations, or contractual agreements. The latter will vary from agreement to agreement, but we have tried to arrive at a common denominator within each country.

The United States
The Federal system (Table 1A) in the U. S. and that used by the individual coastal states are quite similar. The major differences are in magnitude rather than type. For example, all use a competitive bonus bidding system, and all have a royalty on production. The royalty varies from a low of 5 percent on discovery leases in Alaska to a high of 50 percent in the California sliding scale system.
JPT
P. 247
Oriented Perforation to Prevent Casing Collapse for Highly Inclined Wells
Authors: Morita Nobuo , McLeod Harry 
Published: December 2007

Summary
This paper shows that the oriented-perforation technique is an effective method to control casing collapse problems for highly inclined wells. Three wells were perforated with 180° phasing in the maximum in-situ stress direction. These three wells did not experience casing collapse, while surrounding wells with the standard perforation technique did. Two of the three wells with oriented perforations experienced significantly reduced sand problems. Numerical analysis was conducted to compare how effective oriented perforations were in minimizing casing failure when a sheared zone was created around a well during drilling and production.
Completion and Workover of Horizontal and Extended-Reach Wells in the Statfjord Field
Authors: Kostøl Petter , Østvang Knut 
Published: December 2007

Summary
This paper gives a short introduction to the Statfjord field and background for extended-reach-drilled (ERD) and horizontal wells. We reviewed experiences with completion and workovers of horizontal and ERD wells on Statfjord. Ten horizontal wells with horizontal sections of up to 2150 m and four ERD wells with a horizontal reach of up to 7290 m were completed. Several wells were recompleted, and we performed interventions for logging purposes. We describe the development of the completion and workover techniques since the first horizontal well was drilled in 1990 to April 1994.
Oilwell Deliverability Monitoring: A Case History
Authors: Thrasher T. S. , Fetkovich E. J. , Scott S. L. 
Published: December 2007

SummaryThis paper presents a case history study that demonstrates a method to monitor wellhead-deliverability performance for flowing oil wells in a manner similar to gas wells. Separator test data measured for production allocation are used along with the material-balance relationship and multiphase-flow analysis to develop a wellhead backpressure curve for flowing oil wells. An equivalent wellhead static pressure for flowing oil wells is described and shown to be a function of reservoir depletion and multiphase-flow rate. Determination of the equivalent wellhead static pressure extends our understanding of wellhead backpressure analysis for both flowing oil and gas wells.A case history example demonstrating the application of the methods described in the paper is developed with the separator test data from Point Arguello field wells. The resulting wellhead backpressure curves clearly defined individual well deliverability and proved to be valuable diagnostic tools to monitor well performance and to quantify production potential. We show that the procedures developed in this paper are directly equivalent to procedures applied to conventional gaswell wellhead backpressure analysis commonly used in the industry to monitor gaswell performance. By monitoring flowing oilwell performance with the methods described in this paper, operators can address the challenge of maintaining well productivity and field production plateau.
Analysis of Buildup Curves Obtained After Well Treatment
Authors: van Everdingen A.F. , Meyer L. Joffre 
Published: December 2007

Two new unit functions, based on the continuity equation of unsteady-state flow of slightly compressible fluids in permeable media, give the pressure decrease in a well produced at unit rate after its effective radius has been considerably enlarged by acidizing or when the wellbore is intersected by an induced, vertical fracture.

Introduction
Many papers have appeared that contain detailed analyses of the pressure data in wells from the moment the well is shut in until such data form the straight-line relationship, described by Horner,1 between pressure increases and the log of ?t/(t+?t). When formations are not very permeable, it may take some time to gather sufficient pressure data. Attempts have been made to limit the duration of buildup tests and to extract information on the characteristics of the formation and the efficiency of well completion from data recorded in the first hours of the shut-in period. Details are well presented in Refs. 2 and 3, which also contain an extensive bibliography of articles of interest.
The relation between pressure and time is a function of the producing rates and the characteristics of the formation and its fluid content, which can cover a considerable range as shown by the following data. Depending on the formation, the permeability, k, can have a value anywhere between 1 and 1,000 md; the porosity, f, varies from 5 to 35 percent; the fluids can have a viscosity, µ, between 0.02 for gas and 5 cp for oil. The compressibility, c, can be somewhere between 5×10−1 atm−1 for undersaturated fluids and 10−2 atm−1 for gas, whereas the hole diameter can be as small as 4 in. and as large as 10 in. (radius, rw, 5 to 12.5 cm). To simplify computational work, these units were combined into dimensionless groups in Ref. 4 so that only a few fundamental curves are required to analyze flow problems in wells and reservoirs. The following conversion factors are used in these analyses.
Dimensionless time:Equation 1
Dimensionless rate:Equation 2
Dimensionless cumulative production:Equation 3
As it is difficult to measure, with any precision, pressure increases occurring in less than 1 minute after shut-in, 1 minute is about the shortest time interval to be considered. The following table gives the values assigned to the factors in Eq. 1; they convert 60 seconds to 62 dimensionless time units.k=0.001 darcyt=60 secondsf=0.12µ=0.02 cpc=0.005 atm−1rw=9 cm
Design and Installation of an Ultra Deepwater Subsea System: How To Minimize Risks and Costs
Authors: Izetti R.G. , Moreira J.R.F. 
Published: December 2007

Summary
The world's deepest Subsea Tree was successfully installed offshore Brazilat a water depth of 1027m. The "psychological" barrier of 1000m was fmally broken.
Actually, subsea completion technology reached a point where the fundamental question is no longer whether fields located at water depths beyond 1000m can be profitably completed. The key issue now is: is there a better and safer way to do it?
PETROBRAS has pursued an aggressive strategy m research and development concept evaluations and various field studies aiming at a continuous decrease in both CAPEX and OPEX.
This paper primarily describes the major subsea completion achievements, resulting from this great effort, which among other topics include:implementation of an standardization program; sharp reduction of both subseacompletion and drilling time; a new flowline connection method which combines the advantages of both lay-away and pull-in methods; design and future installation of the world first subsea electrical submersible pump; completion equipment simplification and resulting cost reduction.
Also addressed are the key safety aspects related to deepwater completions and the equipment design improvement necessary to safely conduct those operations.

Introduction
Since its first Subsea Tree installation in June, 1979 on the RJS-3 8 well in 189m (620ft) water depth, PETROBRAS has been overcoming challenges towards deeper waters, basically motivated by its necessity of producing in increasingly water depths, where the latest important giant oil fields were discovered. Although presently only 22.5% (160000 bpd) of the production comes from wells that are located deeper than 400m, this figure is expected to reach61% by the year 2003.
Since that first one up to now, 219 Subsea Trees have already been installed, breaking some remarkable barriers.
In September, 1984 the first diverless Subsea Tree was run on the Pirauna-02well at 307m (1007ft) water depth, breaking the divers operational limits.
Calculation of Pressure-Temperature Phase Envelopes of Multicomponent Systems
Authors: Kalippan C.S. , Rowe Allen M. 
Published: December 2007

Abstract
K-factor data for hydrocarbon systems have been correlated as a function of temperature, pressure and convergence pressure. Recently, a very precise technique was developed to predict precise technique was developed to predict accurate convergence pressures, even in the area of the critical state. It is the object of this paper to demonstrate bow this convergence pressure paper to demonstrate bow this convergence pressure calculation can be used to determine the p-T envelopes of multicomponent systems, including the retrograde region.

Introduction
The petroleum engineer is interested in the p-T envelope that describes the fluid existing in a given reservoir. If the reservoir temperature and pressure are sufficiently high, relative to this pressure are sufficiently high, relative to this phase envelope, it may be economically feasible phase envelope, it may be economically feasible to miscibly displace the reservoir fluid with a drier, less expensive gas (Fig. 1). These phase envelopes are normally established by laboratory measurements involving expensive PVT equipment. By the use of a computer program that utilizes some of the latest correlations of hydrocarbon property data, these envelopes can be generated property data, these envelopes can be generated in seconds from composition analysis data including the molecular weight of the C7+ fraction. It is the purpose of this paper to show how convergence pressures can be used to predict be p-T envelopes of multicomponent systems. p-T envelopes of multicomponent systems. Convergence pressure is shown to be a phase-rule variable for the two-phase, three-component system at equilibrium. Ternary phase diagrams are presented for three-component systems that define the convergence pressure for a given temperature pressure, and system composition.

PREDICTION OF THE PREDICTION OF THE PRESSURE-TEMPERATURE ENVELOPE OF A PRESSURE-TEMPERATURE ENVELOPE OF A TWO-COMPONENT SYSTEM
The data for the two-component system will be used to demonstrate how convergence pressure calculations can be used to predict p-T envelopes for multicomponent systems. Figs. 2 and 3 show experimental p-T-Z data for a system such as the ethane-heptane system. (p-Z)T = C1 data has been used to establish convergence pressure K-factor correlations such as those published in the 1957 NGSMA Data Book. These K-factors are plotted as functions of T, p, p cv. plotted as functions of T, p, p cv. These data, in turn, can be used to predict the (p-T)Z = C1 envelope. Suppose we wish to calculate the p-T envelope of Mixture Z of Fig. 3. To use the convergence pressure correlations to establish such a p-T envelope, the following three methods (A, B and C) were developed to predict dewpoint and/or bubble-point states. The predict dewpoint and/or bubble-point states. The method depends on whether the temperature was equal to, greater, or less than the critical temperature.
SPEJ
P. 243
Well Construction Team Approach Creates a New Future for One Company's Operations on the Dutch Continental Shelf
Authors: Stringer R.B. , Bakker T.W. 
Published: December 2007

Summary
Rising costs and low energy prices were inhibiting the development of marginal fields on the Dutch Continental Shelf, resulting in a reduction in drilling activity and a loss of business opportunities. Independent benchmark surveys and critical analysis of total well costs showed the potential for major cost reductions that could turn many of the smaller offshore gas finds into economic development prospects. This triggered a change from traditional operating and contracting strategies to a partnering approach with the principal drilling and service contractors and the institution of a well-construction team (WCT). The WCT proved so successful, with an average well cost reduction of 21% in the first year, that a similar organization has been set up for all the land drilling and workover operations. This paper describes the strategies used and presents a comparison between the traditional performance and the results from the first year of operating as a WCT. The comparison includes the results of an independent benchmark study of 20 North Sea operating companies.

Introduction
The operator's Well Engineering Dept. delivered 22 offshore wells of various types during 1992 at a cost of $260 million. Subsequent remedial work with associated production deferment cost a further $60 million, giving a total cost to the operator of $320 million. Although this was considered to be representative of the general industry performance on the Dutch Continental Shelf, these cost levels made many of the smaller gas finds subeconomic development prospects. This resulted in a reduction in activity from five rigs in 1992 to two rigs in 1993. Further reductions in drilling activity were likely in the following months unless major cost savings could be realized. The prospect of minimal activity threatened both the contractors' survival and the continuation of the operator's offshore activities. These threats dictated a need for a radical change in strategy.
The following options for achieving this change were considered by the operator:terminating the current contracts and retendering in order to obtain lower rates oraggressively pursuing improvements in all elements of the well-construction process while retaining the existing contracts.
The latter option was selected as the only sure way of delivering the "best -value" wells to the operator while providing the contractors with the profit margins necessary to sustain and improve their business into the future. This decision was supported by an analysis of the 1992 well costs, which indicated that, in an ideal world, the total costs could be halved by a combination of optimization of well design and working practices, the development and application of new technology, and avoiding workovers through improved quality.