bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reservoir Study of the Roosevelt Pool, Utah
Authors: Rohr Egon H. 
Published: December 2007

The Roosevelt pool in the Uintah basin of North-eastern Utah produces a high pour-point, high paraffin content crude oil from limestones and sand stringers in the Green River formation at a depth of about 10,000 ft. Due to the low matrix permeability of the rock the productivity of the wells was found to depend upon fracture development. Total production to March 1, 1957, from nine wells was 1,669,000 bbl and current capacity production from six wells is 450 BOPD with 440 BWPD. Production to date has been as a result of fluid expansion coupled with some water encroachment.

Introduction and Geology
The discovery of oil in the Green River formation at Roosevelt by the completion of the Roosevelt Unit No. 1 in June, 1949, marked the first production in the Uintah basin from reservoirs of Tertiary age. This well was completed for a flowing potential of 1,633 bbl of oil and no water at a depth of 9,350 ft. Following the Roosevelt discovery, a number of other pools were discovered in the area, including Duchesne, Red Wash, Flat Mesa and Walker Hollow. At the top of this page is a map of the Uintah basin, which is a structural, topographic and sedimentary basin in Northeastern Utah covering an area of approximately 8,000 sq miles. On this map A marks the Roosevelt pool; B Duchesne pool; C Red Wash-Walker Hollow pool; D Gusher No. 1; E Bluebell Unit No. 1; F Flat Mesa pool; and G County pool.
All commercial oil production at Roosevelt has been obtained from the "D" zone of the Basal Green River. The Green River is a 4,000-ft section of well-bedded oil shales, marlstones, thin dolomites, limestones, and sandstones. The "D" zone is encountered in the lower 1,500 ft of the section with production from this interval being dependent upon a combination of structure, stratigraphy, and fracture development. The Roosevelt pool is located on a broad northwest-southeast trending nose, approximately 7 miles south of the Uintah basin synclinal axis. Fig. 1 presents a structure map of the area and Fig. 2 is cross section of the pool constructed from radioactivity logs. An extensive coring and testing program was followed at many wells in an effort to correlate and identify the pay zones. As shown by the cross section, two main intervals of production totalling approximately 125 ft in gross thickness have been observed, of which the upper has been the more important.
Modeling of Transient Cuttings Transport in Underbalanced Drilling (UBD)
Authors: Doan Q. T. , Oguztoreli M. , Masuda Y. , Yonezawa T. , Kobayashi A. , Naganawa S. , Kamp A. 
Published: December 2007

SummaryUnderbalanced drilling (UBD) holds several important advantages over conventional drilling technology. These include minimization of formation damage, faster penetration rate, and ability for evaluation of reservoir productivity during the drilling process. As UBD technology matures, it has also been used more and more in different applications. However, many aspects of UBD technology remain poorly understood. The model presented in this paper seeks to understand the mechanisms involved in the transport of cuttings in UBD.The model simulates the transport of drill cuttings in an annulus of arbitrary eccentricity and includes a wide range of transport phenomena, including cuttings deposition and resuspension, formation, and movement of cuttings bed. The model consists of conservation equations for the fluid and cuttings components in the suspension and the cuttings deposit bed. Interaction between the suspension and the cuttings deposit bed, and between the fluid and cuttings components in the suspension, are incorporated. Solution of the model determines the distribution of fluid and cuttings concentration, velocity, fluid pressure, and velocity profile of cuttings deposit bed at different times.The model is used to determine the critical transport velocity for different hydrodynamic conditions. Results from the model agree quite closely, qualitatively, with experimental data obtained from a cuttings transport flow loop at the Technology Research Center of the Japan Natl. Oil Corp. (TRC/JNOC)'s Kashiwazaki Test Field in Japan. These results show the importance of slippage in the formation of the cuttings deposit bed. The model is useful in evaluating the minimum flow rate for effective cuttings removal in UBD.
Assessing Uncertainty in Channelized Reservoirs Using Experimental Designs
Authors: Friedmann F. , Chawathé A. , Larue D. K. 
Published: December 2007

SummaryIt is well established that uncertainty exists in simulated recovery forecasts because of the ambiguity in the measurement and representation of the reservoir and geologic parameters. This is especially true for immature projects, such as deepwater reservoirs, where the high cost of data limits the information that is available to build reservoir models. We present two strategies based on Experimental Design (ED) to quantitatively assess this uncertainty in recovery predictions for primary and waterflood processes.We apply the ED methodology to channelized sandstone systems because of their relevance to many deepwater projects. We choose to study synthetic geological analogs of channelized systems that are built from a panoply of relevant parameters while taking into account the uncertainty that exists in the estimation of their ranges. We use the results of this study to generate type curves with neural networks. The trained neural networks can be used to predict reservoir performance rapidly where field data are very limited. We discuss applications of this methodology on field cases from western Africa.
Pressure Maintenance by Fluid Injection in the North Pembina Cardium Unit No. 1
Authors: Groeneveld H. 
Published: December 2007

Abstract
The North Pembina Cardium unit No. 1, the largest unit in The Pembina field, Alberta. Canada. covers a surface area of approximately 45,500 acres and has been developed on 80-acre spacing. Socony Mobil Oil of Canada, Ltd. is the operator. The unit was formed in Sept., 1959 for the purpose of maintaining reservoir pressure by fluid injection in the Cardium reservoir using large injection patterns. The pressure-maintenance project consists of 32,700 acres under water flood and 12,800 acres under miscible flood. The pattern arrangement includes five 2.560 acre 41-spots for the miscible flood, surrounded by 320-acre inverted nine-spots for the water flood. The Cardium sand which is sporadically overlain by a conglomerate section is characterized by severe stratification. Basic reservoir data for different areas within The unit are presented. Reservoir performance for The miscible flood as well as for the water flood is discussed. Although the performance history is short it is evident that formation stratification has a dominant effect on the reservoir performance.
Introduction
The Pembina field is located in the Province of Alberta in Western Canada, about 70 miles southwest of the city of Edmonton, as shown in Fig. 1. This large field which now covers an area of approximately 616,000 acres, was discovered in 1953 by Socony Mobil Oil of Canada, Ltd. The reservoir is a stratigraphic trap producing from the Cardium sand at a depth of about 5,000 ft. Neither bottom water nor free gas has been found. The recovery of oil by solution-gas-drive mechanism has been estimated between 13 and 16 per cent of the original oil in place. About 65 per cent of the developed area of the field is under pressure maintenance by water flooding, miscible flooding or gas flooding. To facilitate the administration of allowables, the Alberta Oil and Gas Conservation Board has divided the pressure maintenance area into approximately 100 "projects". The largest project. is the North Pembina Cardium unit No. 1, covering more than 45,500 acres. Fig. 2 shows the outline of the North Pembina Cardium unit No. 1 and its location within the Pembina field. The unit was formed in Sept., 1959 for the purpose of pressure maintenance by fluid injection using large injection patterns for miscible flooding as well as for water flooding. The present design of pressure maintenance would not have been possible without unitization. There are 21 participants in the unit and participation is calculated based on 85 per cent pore volume and 15 per cent acreage. The unit is completely developed with 569 wells drilled on 80-acre spacing. Socony Mobil Oil of Canada, Ltd. is the operator of this large unit. The purpose of this paper is to summarize the basic reservoir data for the unit, and to present a discussion on the design and performance of pressure maintenance by water flooding and miscible flooding.
Geology
The geology of the Cardium reservoir in the Pembina field has been described in the literature.
JPT
P. 977ˆ
Mechanisms of Rapid Cooling and Their Design Considerations in Underwater Welding
Authors: Tsai C.L. , Masubuchi K. 
Published: December 2007

Rapid cooling is an inherent problem in underwater welding. This paper discusses the basic understanding of cooling mechanisms during underwater welding and the effectiveness of various methods of reducing the cooling rate. Numerical results obtained from a computer analysis are used to discuss the design criteria and the effect of various parameters on the cooling rate.

Introduction
During the last several years, systematic research efforts on underwater welding have been made at the Dept. of Ocean Engineering of the Massachusetts Inst. of Technology. Most of the research programs were funded by the National Sea Grant Office of the National Oceanic and Atmospheric Admin. Some of the reports, theses, and papers have been published. The research programs have covered various subjects including basic research on mechanisms of underwater welding as well as development of new, improved processes. This paper discusses one subject: rapid cooling during underwater wet arc welding.* This paper has been prepared primarily from results obtained in research by Tsai.The major portion of Tsai's research is composed of extensive mathematical analyses of heat flow during underwater wet arc welding. A series of mathematical equations has been developed to analyze all pertinent phenomena involved: dynamics of bubble formation, heat-loss mechanisms, etc. Experiments were made to examine the validity of the analyses. Studies were made to investigate effects of various parameters (welding conditions, plate thickness, etc.) on cooling rates in weldments, especially in the heat-affected zone (HAZ). Studies also were made to evaluate the effectiveness of various methods of reducing the cooling rate.Since details of analytical and experimental results are included in Ref. 4, this paper presents a brief summary of the analysis and some experimental results. The emphasis of this paper is placed on information of practical importance.

Brief Summary of Cooling Mechanisms in Underwater Welding
The mode of heat transfer in underwater welding is quite different from that in air welding. The existence of dynamic bubbles during underwater welding induces a flow field around the welding arc. This water flow along with the agitation of bubbles carries the heat away quickly from the base material and causes the rapid cooling phenomenon. In this section, buble dynamics and heat-loss mechanisms are discussed.

Underwater Bubble Dynamics
Bubble generation due to the high concentration of heat in the arc and its departure and final collapse during the underwater arc welding process in the wet condition was investigated by a high-speed cinematography study at the Massachusetts Inst. of Technology.
JPT
P. 1825＾
Extreme Forces in Short-Crested Seas
Authors: Huntington S. W. , Gilbert G. 
Published: December 2007

Abstract
The overall wave force on a large structure in a real multidirectional sea does not occur in a single direction but is a vector randomly varying in magnitude and direction. Although existing theories enable us to calculate the extremes of the orthogonal components of force, the designer needs the extreme resultant or total force. A theory is presented for estimating the extremes of the resultant and is confirmed by experimental measurement.
Large Wire Rope Mooring Winch Drum Analysis and Design Criteria
Authors: Song K. K. , Rao G. P. , Childers Mark A. 
Published: December 2007

Abstract
Flange splitting (separation of the flange from the barrel) is the most common structural failure in large mooring winches. Conventionally designed winches have failed on a number of occasions when wire ropes 3 to 3.5 in. (7.6 to 8.9 cm) in diameter and up to 10,000 ft (3048 m) long were employed for mooring large construction barges and semisubmersible offshore drilling units. It is believed that this is due to improper approximation of the field loading patterns on the winch, inadequate knowledge of actual forces transmitted onto the flange and drum barrel of the winch, and/or defects in the structural joint between the flange and the drum barrel.
The available design methods are often empirical, modified, or extrapolated from work done a decade ago using very small wire ropes and drums. The application of these techniques to a multilayered winch using large-diameter wire rope has proved to be unrealistic. A method is presented to calculate the flange thrust load and the barrel external pressure for winches using large-diameter wire ropes. Also, a general guide for design and analysis of such winches and the effect of the lateral modulus of elasticity of wire rope on the reduction in the layer tensions is presented.
Design Methodology for Selection of Horizontal Openhole Sand-Control Completions Supported by Field Case Histories
Authors: Price-Smith C. , Parlar M. , Bennett C. , Gilchrist J. M. , Pitoni E. , Burton R. C. , Hodge R. M. , Troncoso J. , Ali S. A. , Dickerson R. 
Published: December 2007

Summary
Reservoirs requiring sand control pose a major challenge for selecting a suitable completion method. Horizontal openhole completions have been successfully used in such reservoirs to eliminate sand production while maximizing productivity/injectivity and well deliverability throughout the expected life of the completion and minimizing risk and complexity.
Although horizontal, openhole, sand-control completions, ranging from preperforated/slotted liners to gravel packs, have been applied widely in the last decade and many case histories have been discussed in the literature, a systematic methodology for selecting these completion methods remains to be documented. It is the objective of this paper to propose such a design methodology by unifying the broad experience and understanding from a global, technically integrated perspective.
The paper first discusses a generalized and unified methodology for determining when to install sand control, what to install for sand control, and how to install it in horizontal openhole completions. Specific factors recognized as affecting "when" are in-situ stresses, pore-pressure decline (sand prediction), expected well life, production rate, hydrocarbon and well type, gross product value, sand tolerance capacity, environmental limitations, and intervention capabilities, while the integration of all these factors has an impact on the overall risk analysis. In addition to many of the previous factors, critical drivers affecting "what" are identified as wellbore architecture, reservoir lithology and petrophysical properties, and sandface equipment reliability. Additional parameters impacting "how" are reservoir drilling fluid, displacement and cleanup methodology, screen type, operational implementation/ assurance (risk management, operational timing, and location logistics), torque and drag analysis, and gravel-placement simulations.
Secondly, examples of this methodology are presented in detailed case histories pertaining to different types of horizontal, openhole, sandface completions, including slotted liners, standalone screens (including expandable), and gravel packs, as well as various integrated cleanup methods, along with a summary of the lessons learned by each company.
Modeling of Multiple Echo-Time NMR Measurements for Complex Pore Geometries and Multiphase Saturations
Authors: Toumelin E. , Torres-Verdín C. , Chen S. 
Published: December 2007

Summary
We develop a numerical algorithm to simulate nuclear magnetic resonance (NMR) measurements in the presence of constant magnetic field gradients. The algorithm is based on Monte Carlo conditional random walks in restricted and unrestricted space. Simulations can be performed of 3D porous media that include both arbitrary bimodal pore distributions and multiphase fluid saturations. The ability to account for the presence of a constant external magnetic field gradient allows us to replicate actual well-logging conditions that include the effect of Carr-Purcell-Meiboom-Gill (CPMG) pulse sequences at a microscopic level. This is accomplished by simulating ideal pulse-acquisition techniques that include multiple interecho times (TE) similar to those currently used by the well-logging industry. Benchmark examples are presented to validate the accuracy and internal consistency of our algorithm against previously published results for the case of a null magnetic field gradient. Validation examples also are presented against actual NMR measurements performed on core samples of carbonate rock formations.
Interpretation work is focused on the petrophysical assessment of both partial oil/water saturations and pore structures exhibiting diffusive coupling. Simulation examples are designed to quantify whether the inclusion of diffusion under a magnetic field gradient can improve the interpretation of multiphase fluid saturations when diffusion coupling is significant. The simulation algorithm sheds light on new NMR data-acquisition strategies that could be used to improve the detection and quantification of fluid types, complex fluid saturations, and complex pore geometries.
Integrated Core Analysis for Fractured Reservoirs: Quantification of the Storage and Flow Capacity of Matrix, Vugs, and Fractures
Authors: Bona N. , Radaelli F. , Ortenzi A. , De Poli A. , Peduzzi C. , Giorgioni M. 
Published: December 2007

Summary
Answering general questions such as "Where is the oil?," "How much oil is there?," and "Can we extract it?" is a challenging task for a large fractured field in southern Italy. Various studies were conducted to gain more insight into the way oil is distributed in the rock and the producibility of the different structures observable on the cores (matrix, vugs, and fissures).
These included the cryogenic scanning electron microscope (CryoSEM) and gas chromatography (GC)-pyrolysis, pore-size-distribution measurements, SEM analysis on thin sections, and a number of nonconventional techniques that were designed specifically for that type of rock. Nuclear magnetic resonance (NMR) imaging was conducted on several whole core samples and the different porosity contributions (microporosity, vugs, and fissures) defined on a 3D basis. An analytical approach based on the percolation theory was used to separate the permeability contributions and define the conditions under which vugs and fissures may form a conducting system. The inputs were distributions of pore throats, throat length, coordination number, fissure orientation, and porosities. Wettability is a key parameter for production estimates, and we used a technique for measuring it in both microporosity and fissures, which makes use of dielectric constant measurements. All the data contributed to our current understanding of the reservoir.
Discussion of Reservoir Characteristics, Cedar Creek Anticline Fields, Montana
Authors: Hols Arnold , Bethel Frank T. 
Published: December 2007

Abstract
At the present time, over one-half the total oil production in Montana originates from Williston Basin fields in Eastern Montana. Six of the seven foremost producing fields in this area are located along the Cedar Creek anticline. The characteristics of the reservoir rocks which constitute these fields, the characteristics of the reservoir fluids and the behavior of the fluids in the rocks are discussed.
The conclusions drawn from the data available are that the carbonate reservoirs of the Cedar Creek anticline are under-saturated, of poor-to-fair permeability and of fair-to-good porosity with some localized fracturing. By comparison of various fields on the anticline, a general improvement in reservoir rock and fluid properties is shown to exist in a south-to-north direction. The valuable aid to reservoir interpretation and operation which can be obtained through a systematic gathering of data and modern mechanical methods of statistical analysis is emphasized.

Introduction
The nation's attention was focused on the Williston Basin potential in early 1951 by significant discoveries in Manitoba, Canada, and on the Nesson anticline in North Dakota. Later during the same year discoveries were made on the Cedar Creek anticline of Eastern Montana; namely, the Glendive and Pine fields. Rapid developments along the Cedar Creek anticline led to the discovery of 12 oil fields by 1955, one of which is located on the southern end in South Dakota (Fig. 1). Production from the Montana portion of the Cedar Creek anticline currently amounts to 34,000 BOPD which represents 44 per cent of the total Montana oil production. The first and third largest oil fields in Montana from the standpoint of production are found here, respectively, Pine and Cabin Creek.
The purpose of this paper is to discuss the different reservoir characteristics in those fields where Shell is operating, e.g., those from Glendive to Buffalo. The discussion will not deal with stratigraphic detail but is limited to those aspects which are of practical value to the reservoir engineer, and are presented in the following order:reservoir rocks,reservoir contents, andreservoir pressures.
Second-Order Directional Seas and Associated Wave Forces
Authors: Sharma J. N. , Dean R. G. 
Published: December 2007

Abstract
Most methods for wave force computation incorporate either the nonlinearities of the ocean surface for a single fundamental component or the random and/or directional characteristics using superposition of linear wave components. One exception is the intuitive "hybrid" method1 which combines elements of linear and nonlinear waves. This paper describes and applies a method correct to the second order in wave height for calculating waves and wave forces caused by a directional wave spectrum on an offshore structure.
Starting with a prescribed linear spectrum of directional waves, a set of random phases is generated and the second-order spectrum computed with phases defined by all contributing pairs of first-order components. Thus, with one realization of the spectrum complete up to the second order, the wave profile and water particle kinematics can be simulated in the time domain. The wave forces also are computed in the time domain, taking full account of their nonlinear and directional properties. The resulting wave forces at any level vary in direction and magnitude. The total wave forces summed over all piling of a structure are less than those for a unidirectional train of waves with the same one-dimensional spectrum.
Several examples are presented to illustrate reductions in maximum wave forces caused by the directional distribution of waves. We found that for a single piling the maximum force decreases by a factor ranging from 1.0 to 0.61 as the directional spread increases from unidirectional to uniformity over a half plane. For a four-pile group on a square array of 300-ft (91.4-m) spacing, the corresponding decrease in the factor is 1.0 to 0.51 for a Bret-schneider spectrum with a peak period of approximately 12 seconds. The results of this complete model are compared with the more intuitive and approximate hybrid method and are found to agree quite well. Force spectra are presented and discussed for the inline and transverse directions.