bluuebunny/crossref_metadata_2025_split huggingface dataset:
Transient Analysis of Point Arguello Gas Pipeline Behavior
Authors: Sarica C. , Shoham O. , Brill J. P. , Taitel Y. 
Published: December 2007

Abstract
The sour gas produced from the offshore Point Arguello oil field will be transported through a pipeline consisting of offshore and onshore sections terminating at an onshore processing plant. Accurate prediction of the complex flow behavior of the fluid in both pipeline sections is essential for proper operation of the pipeline. The objective of this paper is to analyze and provide engineering solutions for the operational problems occurring during the different production phases of the field.
It was found that the Point Arguello pipeline would exhibit different flow behaviors, depending upon the input flow rates. A simplified, flow pattern dependent, transient two-phase flow simulator was used to predict this complex flow behavior. For low input flow rates the offshore pipeline section would operate under slug flow conditions, with liquid accumulating in the line, and frequent pigging being required. For high input flow rates, the offshore pipeline section would operate under stratified flow, resulting in less liquid accumulation and liquid being transported into the onshore section. These different operational modes play an important role in leak detection analysis.
The rigorous analysis of the complex flow behavior presented in this paper provides solutions for proper operation of offshore wet gas pipelines. This includes solutions for liquid accumulation, pigging frequency, and pressure fluctuations for leak detection.
Pipelining of Heavy Crude Oil as Oil-in-Water Emulsions
Authors: Zhang Jingjun , Chen Dabin , Yan Dafan , Yang Xiaoheng , Shen Chen 
Published: December 2007

Abstract
This paper presents an exDerimental study on pioelining of Shanjiasi heavy crude oil as oil-in-water emulsions. Viscosity reductions of more than three orders of magnitude were achieved in laboratory by emulsification. Field trials were then made in three 4-in. gathering lines 101, 160 and 241 meters long respectively. A chemical solution was injected into the gathering line at the wellhead. Drag reductions of 40-80% were achieved provided that the formed emulsions had an injected water fraction of 0.2-0.4 and the chemical concentration was at 0.35-0.5% (based on injected water). It was also found that drag reduction was more significant at a low temperature and for a highly viscous heavy oil. A big difference existed between rheologi" cal data obtained from the field trials and those from laboratory experiments, and possible reasons were discussed.
Hydraulic Fracture Height Growth in San Juan Basin Coalbeds
Authors: Palmer I. D. , Kutas G. M. 
Published: December 2007

Abstract
Fracturing through perforations in the coal is often used in the San Juan Basin to stimulate production of natural gas from Fruitland coalbeds, which overlie the Pictured Cliffs (PC) sandstone. A data set of many fracturing treatments has been analyzed, including (a) pressure versus time profiles, and (b) wellbore gamma ray (GR) surveys of radioactive tracer added to proppant. First, factors that tend to confine a fracture's height growth are reviewed, and vertical stress profiles are discussed. Secondly, three classes of fractures are identified: When the PC sand is close (less than 20 ft) and the coal is deeper than 1800 ft, a fracture is likely to grow into the PC sand, accompanied by falling pressure.When the PC sand is more than 20 ft away, a fracture is largely confined by the shales and accompanied by rising or flat pressure, a proppant-induced pressure increase (PIPI), and ISIP &gt; 1 psi/ft. There is likely to be a T-fracture. The limited (or zero) fracture height growth in bounding shales is explained.When the PC sand abuts one of the coal seams at shallower depths (&lt;1800 ft), fracture growth appears to be limited by the PC sand, fracture pressure rises, and ISIP &gt; 1 psi/ft. This may be due to factors which encourage interfacial slippage at shallower depths.
The rapid fall in tracer signal from a coal seam into bounding zones is interpreted by a discrepancy in fracture width, or due to zero fracture width in shale. Proppant tracer signals in shale-bounded coals are asymmetric: more peaks occur at or above the coal roof than at or below the coal floor. This may reflect a horizontal fracture component near the roof of the coal seam (i.e., a T-fracture), but more analysis is needed to confirm this. When several seams are stimulated simultaneously, if two coal seams are separated by more than 15 ft, they are unlikely to be linked by tracer, and fracture communication may not exist between the two seams. Although proppant appears to have access to every seam usually, this may not mean equal fracture lengths in these seams. Finally, an anti-correlation between 40/70 and 12/20 proppant tracer supports 40/70 proppant plugging smaller flow channels, thus diverting fluid to other channels which become wider, and can more easily transmit 12/20 proppant. This may explain success of "graduated proppant" fracture treatments.
Case History of Waterflood Infill Drilling in the Johnson J.L "AB" Unit
Authors: Yadavalli S. K. , Brimhall R. M. , Wu C. H. 
Published: December 2007

ABSTRACT
This paper presents the results of a 3-D, 3-P reservoir simulation study of waterflood infill drilling in a study area of the Johnson J.L. "AB" unit, located in Ector county, West Texas. The primary objective was to evaluate the waterflood infill drilling performance in the study area. This was accomplished by simulating the waterflood infill drilling performance followed by simulation of an alternative infill scheme or targeted infill drilling, utilizing a detailed reservoir characterization model. An economic evaluation was carried out for both the actual and targeted infilling schemes. The targeted infill drilling scheme resulted in higher recovery and better economic returns as compared to the actual infill drilling scheme. The major inference of this study was that the optimal infill drilling pattern need not necessarily be a regular pattern.
Surge Test Simulation
Authors: Petak K. R. , Prasad R. K. , Coble L. E. 
Published: December 2007

Abstract
Post-perforation surge tests are frequently used in the oil industry. A surge test is normally conducted by flowing fluids into a closed chamber. This category of testing includes backsurge perforation washing, underbalanced perforating with subsequent flow, and closed chamber drillstem testing. Typically, downhole response is measured by a pressure/temperature gauge. This response may be analyzed for reservoir parameters by using existing techniques; however, variable wellbore conditions and rapidly changing rates make finding a solution difficult and sometimes impossible.
This paper presents a numeric simulator which is used to model surge behavior for various wellbore and reservoir conditions. Because variable wellbore conditions are considered, the resulting analysis is more reliable and often possible when other techniques fail.
Reservoir flow into the wellstring is controlled by the wellstorage coefficient and completion and reservoir parameters. At each time step the wellstorage coefficient is explicitly solved by performing a mass balance on the wellstring fluids. This calculation accounts for compression of air in the surge chamber, variable cushion pressure, displacement of rathole fluid into the wellstring, changing inside diameter in the wellstring, and volume of reservoir fluid produced into the wellstring.
Simulated pressure profiles are presented for various reservoir and wellbore conditions. A simulated match of field test data is also given to illustrate the practicality of this work. The matching process yields permeability, skin, static formation pressure, and radius of investigation.
Scale Prediction During CO2 Huff 'n' Puff Enhanced Recovery, Crooks Gap Field, Wyoming
Authors: Smith L. K. , MacGowan D. B. , Surdam R. C. 
Published: December 2007

ABSTRACT
Perturbation in the rock-water systems of petroleum reservoirs during CO2 enhanced recovery processes may cause precipitation of scale in production lines. Therefore, a prediction of the scale potential of a particular system is valuable in the design of the enhanced recovery treatments. On the basis of formation mineralogy, formation water chemistry, and estimated temperature and pressure conditions, scale build-up during a CO2 Huff ‘n’ Puff treatment in the Cretaceous Crooks Gap reservoir in Wyoming was predicted to be minimal. Carbonate mineral cements (mostly calcite) and plagioclase, both of which are sources of scale constituents, are present in the reservoir only in trace amounts. Also, the estimated pressures both in the formation and in the production lines were sufficient to keep most of the bicarbonate ions in solution. Finally, organic alkalinity was insufficient to buffer pH which otherwise might have stabilized carbonate minerals during the CO2 injection and cause them to precipitate within the reservoir.
Water chemistry was monitored during the production phase of the Huff ‘n’ Puff treatment to test the reliability of the predictions. Initial production showed an order of magnitude increase in the calcium concentration in the produced waters as well as a two-fold increase in the bicarbonate concentration. Calculations of mineral stabilities using the post-CO2-injection produced waters indicated a slight over-saturation with respect to calcite. However, further calculations done to determine the amount of scale precipitation needed to bring the system back to saturation demonstrate that the scaling potential was minimal. The concentrations of both constituents dropped back to pre-CO2-injection levels within thirty days after the production began, which further diminished the potential for scale problems.
A Review of Horizontal Methods and Drilling Technology
Authors: Leaf R. C. , Pittard F. J. 
Published: December 2007

Abstract
This paper covers the geology of the Rocky Mountains, low permeable hydrocarbon producing formations and the problems associated with horizontal drilling tools in these regions. The paper includes representative horizontal well data from the Rocky Mountain region and low permeable hydrocarbon producing formations outside the United States. Oil producing trends with respect to fracture and formation are described as they pertain to horizontal drilling tools. Where applicable emphasis is placed on solutions to problems associated with horizontal tools.
Fluid Loss During the Fracturing of Naturally Fractured Reservoirs
Authors: Stahl R. M. , Clark R. E. 
Published: December 2007

ABSTRACT
There are several different types of reservoirs that have a high degree of natural fracturing. In these reservoirs, the fluid loss mechanisms are more complicated than those found in more coherent formations. The loss of fluid to intersecting fractures is especially important in the fracturing of coalbeds, Devonian type shales, limestones and naturally fractured sandstones. In many cases, the reservoir permeability is often such that the fluid loss to these fractures is the primary fluid-loss mechanism. Little is known about how to handle this type of fluid loss in fracture simulation calculations, or the effects of this fluid-loss mechanism on pressure drop in the fracture. While the loss of fluid to intersecting fractures is not the only fluid-loss mechanism in naturally fractured sandstone reservoirs, it can dominate the fluid loss to the reservoir under some conditions. Examination of the problem from both a computer based modeling and laboratory standpoint is clearly warranted.
Flow of fluid down a fracture in a sandstone reservoir is modified by the continual loss of fluid to the reservoir through the permeability of the rock. In a naturally fractured reservoir, fluid loss occurs mainly at points where the fracture intersects an existing fracture in the rock. This not only changes the nature of fluid loss in the fracture, but it also creates serious flow disturbances that can change the pressure drop in the fracture. It has been shown that flow into orifices placed perpendicular to the major axis of flow results in a highly extensional flow situation. Extensional flows have been shown to increase pressure drop in porous media using non-Newtonian fluids. In addition, it has been shown that two-phase fluids will separate to some extent when a branching of the flow path occurs. These factors have important implications in the flow of fracturing fluids in fracturing treatments in naturally fractured reservoirs.
To study the flow effects, a computer model of a small section of a fracture with one intersecting fracture was setup. A commercial finite element analysis program (FIDAP) is used for the fluid flow calculations. This program is optimized for power law type fluids. Computations for several different values of the power law parameters coupled with different intersecting fracture widths and fracture width ratios will be presented. Conclusions about the nature of the fluid loss in naturally fractured reservoirs will also be made.
Reservoir Characterization of the Frontier Tight Gas Sand, Green River Basin, Wyoming
Authors: Harrison C. W. , Dutton S. P. 
Published: December 2007

ABSTRACT
A research study has been performed to improve the formation evaluation and reservoir description of the Frontier Formation located in the Green River Basin of southwestern Wyoming. Results of this study are presented which include the integration of data from an extensive wireline logging program, a comprehensive core analysis program, and well test production performance from two wells completed in the Frontier formation. Features of several core analysis techniques are reviewed which were used to determine more accurately the ¡η-situ porosity, water saturation, permeability and producibility from logs. This includes correcting core water saturation for mud filtrate invasion, correcting porosity and permeability to net overburden stress, and comparing core data and log responses to quality control the laboratory core analyses. Log derived lithology was calibrated to that determined from cores using thin section point count and x-ray diffraction analysis. The log evaluation model, which was calibrated to core porosity, uses porosity and saturation exponents derived from electrical property measurements on cores. A preliminary log derived permeability relationship has been developed and compared to that obtained from production well tests.
A Slimhole Coring System for the Deep Oceans
Authors: Storms M. A. , Howard S. P. , Reudelhuber D. H. , Holloway G. L. , Rabinowitz P. D. , Harding B. W. 
Published: December 2007

ABSTRACT
Specialized drilling and coring techniques and equipment have been developed by the Ocean Drilling Program (ODP) to recover fractured basalt cores in deep water. Cores were successfully retrieved in 5900 feet (1800 m) water depth using the new equipment during seatrials in June and July 1990. This paper presents the history of the development and use of the Diamond Coring System (DCS) equipment, and includes information on planned future enhancements to the system to improve operational efficiency.
Side-Drive Drilling System: Description, Installation, and Field Data Performance
Authors: Renfro J. G. , Gaddy D. W. , Moses J. K. 
Published: December 2007

ABSTRACT
In 1987, the Side Drive Drilling System was introduced and has proven to be another successful system for drilling from the top.
This paper describes a new approach to an already proven field. This is an overview of the Side Drive Drilling System concentrating primarily on the following three areas: What is the Side Drive and how does it differ from conventional Top Drives? This examines unique design aspects of the tool by major components.Installation requirements and how they impact rig modifications, cost and time.Actual performance data taken from several installations in various geographic locations. This is a compilation of new data and that which has been reported in various trade journals.
World Record in Extended Reach Drilling, Well 33/9-C10, Statfjord Field, Norway
Authors: Rasmussen B. , Sørheim J. O. , Seiffert E. , Angeltvadt O. , Gjedrem T. 
Published: December 2007

ABSTRACT
This report is a case history of drilling well CIO in the Statfjord Field. The well is a world record in Extended Reach Drilling with a horizontal reach of5003 meters (16 414 ft). This report will mainly concentrate on planning and executing the work; how torque, drag, hole cleaning, welbore stability and surveying were handled through careful planning, follow-up and performance on the rig.
Features of Logging-While-Drilling (LWD) in Horizontal Wells
Authors: Hansen R. R. , White J. 
Published: December 2007

ABSTRACT
Logging While Drilling (LWD)* tools are formation evaluation sensors engineered into drill collars. Using LWD in horizontal wells offers significant advantages over other logging systems for formation evaluation. When LWD is provided in real-time via mud pulse telemetry the system becomes a geological steering tool which can be used to accurately place the horizontal section with reference to formation features and/or fluid contacts. The combined benefits of formation evaluation and real-time geological steering make LWD an essential tool for many horizontal wells.
We will describe the benefits of LWD measurements and the improvements in both drilling and logging efficiency which LWD offers. These features are illustrated with practical examples of LWD from a number of horizontal wells in the North Sea. Although these examples are from horizontal wells in particular, the same benefits can be realized in directional wells in general.
Regulatory Processes for Mining on the Outer Continental Shelf
Authors: Monkelien K. E. , Conner-Hite T. A. 
Published: December 2007

ABSTRACT
This paper describes the regulatory requirements and procedures which will govern Outer Continental Shelf (OCS) mining activities. The regulatory environment for OCS mining is in the early stages of implementation in the United States. Although seven lease offerings involving nonenergy-related materials have been held in the past, the OCS Mining Program, Norton Sound Lease Sale will be the first competitive lease sale (offering) for nonenergy minerals conducted under new regulations promulgated in 1989. These regulations cover leasing and operations for minerals other than oil, gas and sulphur (Code of Federal Regulations (CFR), Title 30, Parts 281, and 282). The regulations establish procedures for leasing and for postlease exploration and mining activities so that operations will be conducted in a safe and efficient manner which provides optimum protection for the environment and for human health and safety. This paper will be directed to the postlease processes.
Research on New Alaskan Mining Technology
Authors: Chamberlain P. G. 
Published: December 2007

ABSTRACT
As readily accessible ore deposits in this country are mined to depletion, mining companies must turn to deposits in remote, environmentally sensitive regions. Alaskan deposits may well offer opportunities for new production of many important minerals. Bureau of Mines engineers and scientists have begun a research program that features new technology for mining in Alaska. The program emphasizes efficient extraction of the mineral value while minimizing environmental disruption. Projects on borehole slurry mining, underground placer mining, back - filling, rock mechanics/mine design, and mine closure practices are reviewed.
FEM Analysis of the Creep Behavior of a Spray Ice Island and Comparison with Actual Island Performance
Authors: Thiel D. T. , Reddy D. V. 
Published: December 2007

ABSTRACT
Although the use of spray ice as a construction material in the Arctic has gained wide acceptance, little quantitative information has been published on the time dependent deformations experienced by spray ice structures due to internal and externally-applied loads. This paper describes a finite element analysis of the time dependent, viscoelastic (creep) behavior of Amoco's MARS spray ice island. Two dimensional, plane strain elements were utilized to model the island. Emphasis was on the deformation of the structure due to its self-weight and the weight of the drilling rig, as well as from lateral displacements occurring in the surrounding ice sheet. The analysis was limited to secondary (steady state) creep behavior. Required values for all physical parameters were obtained from actual island measurements, including those from in situ pressuremeter tests carried out at the island.
The analytical results were compared to actual island performance characteristics, measured during its operating life over the winter and spring of 1985-86. The results show reasonably good agreement between modeled behavior and actual island performance. Observed discrepancies are discussed in the paper.
The Cuttings Grinder
Authors: Smith R. I. 
Published: December 2007

ABSTRACT
The Cuttings Grinder was built as an innovative method to dispose of drilled cuttings, providing an alternative to placement of drilled cuttings in reserve pits. The Cuttings Grinder reduces drilled cuttings into a slurry, which is then pumped down a disposal well into the Tertiary sandstone. This paper explains why the Cuttings Grinder was built and describes how it works, together with the modifications that have been made since it has been in operation.
Full-Signature Multiple-Channel Vertilog
Authors: Adams G. W. , Moffat W. D. 
Published: December 2007

ABSTRACT
A new version of the Vertilog flux leakage (DC Magnetic Inspection) pipe evaluation tool has been developed. This new system is called the Digital Vertilog (DV). This paper presents an explanation of the DV tool theory, operating system and its working components. The sensor system of the standard Vertilog has been provided with an updated data gathering system in order to increase the information available to the log analyst. This new system transmits true bi-polar representations of each flux leakage sensor and a number of eddy current sensors to the surface recorder. The multiple bi-polar flux leakage (FL) channels allow easier interpretation by contrasting changes due to hardware and corrosion. Some of the features more easily determined include pitting, perforation (including the phase of gun used), scratchers, and centralizers. Log examples generated in the lab and their interpretation will be presented. These examples successfully demonstrate the advantage of recording full signature wave response and accurately differentiating pipe hardware from corrosion.
A New, Low-Cost, Ice- and Wave-Resistant Port Facility at Nome, Alaska
Authors: Swigart W. S. , Nottingham D. 
Published: December 2007

ABSTRACT
This paper describes the design and construction of an ocean dock that will be built in Spring 1991 in Nome, Alaska. The dock will be constructed near the offshore end of a rock causeway that extends about 2,700 feet (823 m) into the ocean. The project features the opencell dock concept, which was developed by the writers in 1981 and used on about 40 docks and bridge abutments since that time. The open-cell dock will consist of interlocking sheet pile cells filled with granular fill, heavy-duty energy-absorbing fenders on the dock face, and pipe bollards to secure vessels.
The open-cell dock concept is particularly suited for use in Nome and other Arctic locations because it is inexpensive, relatively simple and fast to construct, makes use of locally available fill materials, and is highly resistant to ice forces. The Nome dock will be constructed through a large hole in the approximate four-foot-thick arctic pack ice which should provide total protection against storm waves during construction. Some other logical uses for the open-cell concept in the arctic include drilling islands, bridge piers and abutments, erosion control structures, retaining walls, marine breasting dolphins, and harbor entrance channels.