bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integrated Cement Evaluation Saves Time and Money
Authors: Wydrinski Ray , Jones R. R. 
Published: December 2007

ABSTRACTCement bond logs (CBL's) are typically used to approve or condemn cement jobs. This "report card" has caused disputes between the cementing and logging companies for years because typically the CBL is interpreted independently from the cementing operation. Thus, a bad "report card" is usually translated into a bad cement job, which is often not the case. This paper illustrates the value of integrating cementing with bond logging to give a clearer picture of the actual quality of the cement downhole. Logs should be used as a tool to understand the cement quality and determine what improvements need to be made to enhance cementing job success.Four examples are presented which show that factors such as 1) borehole conditions, 2) cement job design, 3) displacement practices and 4) tool selection and calibration all have an effect on the bond log interpretation. However, in all cases, integrating the log response with a thorough cement evaluation results in a more accurate analysis of the cement quality, and a better educated decision on the necessity for remedial work.
Integration of High-Resolution CT-Scan and Minipermeameter Measurements With Wireline Logs To Correlate Thin, High Permeable Zones
Authors: Sharma Bijon , Tomutsa Liviu , Martinez Guillermo , Kerr D. R. 
Published: December 2007

Abstract
The characteristic vertical variation in petrophysical properties across thin (0.6-1.5m) reservoir units was determined at 5 cm intervals from CT-scan and minipermeameter measurements of core samples from the Upper Cretaceous UA-5B sandstone at Patrick Draw Field, Wyoming and the Pennsylvanian Bartlesville sandstone of Oklahoma. This information was used to determine their expected responses on wireline logs. The correlation with this data of a highly permeable interval at the base of the producing shoreline sandstone (UA-5B) indicated that the distribution of this interval significantly affected waterflood production from the field.
The International Synthetic Fuels Picture
Authors: Cameron R.J. , Dailey J.L. 
Published: December 2007

Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Although world oil supplies appear fully capable of providing the petroleum appetite of this planet for petroleum appetite of this planet for many years to come, national interests and geographic remoteness from prolific oil fields have promoted the establishment of synthetic fuel industries. An examination of existing and prospective synthetic fuels industries outside the United States reveals only two which may be considered to have the potential of future growth. These are potential of future growth. These are the tar sands of Canada and oil shale in Brazil. A comparison of the processing techniques now employed along with the reserves supporting these processes with a simple set of criteria for success points up the short-comings of the oil shale operations in Estonia and Manchuria and the coal facilities in South Africa. A lack of improved technology may be cited as the single most important criteria not met by these industries. Although attempts are being made to create an emerging technology from an antiquated base in these instances, the research may well have begun too late to permit the existence of these international synthetic fuel plants in a future competitive world oil market.

Introduction
This review of the international synthetic fuels picture, although not intended to be exhaustive, will attempt to outline the current situation as we know it with some thoughts on the future. Since several recent reviews adequately treat the situation in this country, our primary aim will be to bring you up to primary aim will be to bring you up to date on synfuel activities outside the United States, especially where industries are in being or where prospects appear encouraging.
Before proceeding further let us establish a definition of "synthetic fuels" as we use the term. Synthetic fuels are hydrocarbons derived from coal, oil shale or tar sands, that are similar in quality and characteristics to petroleum liquids and gases.
An Integrated Technology Approach Yields 101 MMCFPD in the Eugene Island 295 "B" Horizontal Well Project
Authors: Schroeder Tom , Mathis D. E. , Howard Ron , Williams G. N. , Sun J. A. 
Published: December 2007

Abstract
In late November 1993, Pogo Producing Company successfully completed a five well horizontal drilling program on Eugene Island Block 295. These five wells encountered over 7000 ft (2133 M) of gas sand and tested at a combined rate of approximately 101 MMCFPD. This success was attributed to the integration of geologic control with MWD, direction drilling, drilling fluids, tubular programs, and completion techniques.
The program was designed to develop three shallow gas sands which occur at 1200, 1800, and 2500 ft (366, 549, and 762 M) TVD, and are referred to as the AA-5, AA-10, and AA-15 respectively. These sands are Pleistocene in age and are associated with a broad, low relief, anticlinal structure which was confirmed by subsurface control and seismic amplitude.
The "B" platform is set over the #6 vertical well. The resistivity and gamma ray from this well were used to model the MWD resistivity responses associated with each objective as the wellbores approached horizontal. These modeled resistivity logs, along with gamma ray, were correlated with the MWD real-time logs to pick casing points within the top of the targets. The actual BHA and mud system used to drill the horizontal sections resulted in difficult conditions for the MWD resistivity logging (eccentered tool, low resistivity mud). Despite these conditions, the MWD logs provided critical information for geosteering, helping the team to drill in proximity to the overlying shales without exiting the sands.
The Influence of Shear Rate History on the Thickening Time of Oilwell Cement
Authors: Purvis D. L. , Mueller D. T. , Matson R. P. 
Published: December 2007

Abstract
Current industry thickening time test methods adopted by the API simulate shear rates in excess of 725 sec-1. Yet, under many circumstances, a cement slurry encounters much lower shear rate during its pumping history. Thickening time testing was performed comparing standard API methods with lower shear rate conditions simulated with a helical screw rheometer. Results indicate that thickening times are directly influenced by the shear rate found during mixing and displacement.
Previous investigation of wellbore shear rate effects on cement thickening time has shown an unexpected reduction in API thickening time under the low shear rate conditions common to many field operations. Using the helical screw rheometer and mathematical modeling presented in SPE 265761, this paper expands upon the initial studies by investigating a variety of typical slurry formulations under low, intermediate and API shear rate environments at temperatures up to 308 °F.
Flowline Insulation Thermal Requirements for Deepwater Subsea Pipelines
Authors: Rubel M. T. , Broussard D. H. 
Published: December 2007

Abstract
Current technology limits the distance over which subsea produced well fluids may be transported to approximately 10–15 miles. Many offshore leases exist in water depths in the order of 4,000 feet that could require transportation distances of 50–60 miles. The prevention of hydrate formation in the flowline is of concern for this service. Injecting a chemical inhibitor has typically been considered as the primary method for preventing hydrate formation. The current knowledge of subsea insulation, particularly for deepwater applications, is very limited.
The purpose of this study is to develop data needed to evaluate the effectiveness of flowline insulating systems in maintaining the fluid temperature above the hydrate formation temperature for a typical Gulf of Mexico application.
Database Analysis of Thru-Tubing Inflatable Packer Systems
Authors: Coronado M. P. 
Published: December 2007

Abstract
Since early 1986, Thru-Tubing inflatable packer technology has allowed operators throughout the world to improve the efficiency of many of their workover operations, as a result of working through the existing production completion, and thus decrease the cost of these operations. As this technology has evolved, new applications are continuously being investigated and executed in the field. Thru-Tubing inflatable packer technology has proven to be a very versatile way of performing many workover operations, and the number of different applications being done today is ever increasing1.
This paper will detail the types of applications being done today using Thru-Tubing packer technology, utilizing information compiled in a database which dates back to the original packer runs made at Prudhoe Bay, Alaska, where this technology was pioneered. Many of these applications are a result of creative thinking on the part of operators who realize the flexibility of using an inflatable tool system.
Also analyzed in this paper will be the success rates that have been demonstrated with these systems, including a discussion of the types of failures that have been seen in the field. Since inflatable packer performance is thought to be related to the expansion the element must withstand during the application, the database will also be utilized to study the success rates experienced as a function of element expansion. Advancements made in elastomer and design technology during the last few years has allowed for increased expansion capability, along with differential pressure capabilities and temperature resistance. Element success rates will also be given as a function of element outside diameter and bottom hole temperature in which the element is being used in.
Utilizing the various fields set up in the database system, a series of frequency analyses will also be presented which cover wcllbore deviations, setting depths and geographical information. A comparison of conveyance means will also be made which will describe the ratio between electric wireline (EWL) and tubing (including coiled tubing (CT)) tool conveyance by year.
The Effect of Viscosity on Near-Wellbore Tortuosity and Premature Screenouts
Authors: Aud W. W. , Wright T. B. , Cipolla C. L. , Harkrider J. D. , Hansen J. T. 
Published: December 2007

Abstract
The success of most fracture treatments is primarily dependent on the ability to evaluate the characteristics and critical mechanisms that control how a formation hydraulically fractures. By developing an understanding of the mechanisms, it is possible to make the necessary improvements to ensure optimum proppant placement and therefore maximize economic results. This discussion presents a simple, low cost method for improving the overall fracture geometry and reducing the risk of premature screenouts. Dramatic improvements in near-wellbore tortuosity and improvements in proppant placement can be achieved by maximizing the viscosity of fluid that is used to initiate the fracture and carry proppant through the near-wellbore region. Using the approaches presented, it has been possible to eliminate premature screenouts and improve the overall proppant placement in many different environments.
State-of-the-Art Survey on Hydrate Formation
Authors: Hight M. A. 
Published: December 2007

Abstract
The formation of hydrates in wells and pipelines can seriously hamper production operations since hydrates can completely block flowlines. The formation of hydrates is due to the presence of water along with certain low molecular weight gases. To avoid hydrate blockages it is imperative to first know under which temperature and pressure conditions hydrates will form. This can be predicted by computer models based on the fluid composition. This study predicts hydrate formation conditions for a range of live oils by computer simulation and determines the sensitivity of several physical properties.
Biotechnological Breakthrough Improves Performance of Moderate to High-Temperature Fracturing Applications
Authors: Brannon H. D. , Tjon-Joe-Pin R. M. 
Published: December 2007

ABSTRACT
Historically, the application of breakers in fracturing fluids at elevated temperatures has been a compromise between maintaining proppant transport and achieving the desired fracture conductivity. Conventional oxidative breakers react rapidly at elevated temperatures, potentially leading to catastrophic loss of proppant transport. Encapsulated oxidative breakers have experienced limited utility at elevated temperatures due to a tendency to release prematurely or to have been rendered ineffective through payload self-degradation prior to release.
Enzymes, from a theoretical perspective, are known to provide superior performance relative to oxidative breakers. This is due to the inherent specificity and the "infinite" polymer-degrading activity of enzymes. However, the application of enzymes has historically been limited to low-temperature fracturing treatments due to the perceived pH and temperature constraints. Recent developments in biotechnology have resulted in the isolation of hyper-thermophilic organisms, which led to the separation and purification of extreme temperature-stable, polymer-specific enzymes. Laboratory evaluations utilizing these enzymes as gel breakers have demonstrated exceptional performance capabilities over a pH range of 3-11 and temperatures exceeding 300°F.
Performance properties of systems incorporating the new breakers are provided, including rheology, proppant transport, and retained permeability. Case histories of fractured wells in several moderate to high-temperature reservoirs are provided to validate the utility of this technological breakthrough. The data illustrate that the enzyme breakers can be successfully incorporated without compromising proppant transport capabilities, yielding improved productivity relative to observations in offset cases treated with conventional breakers.
On the Threshold: Subsea Multiphase Pumping
Authors: Beran W. T. 
Published: December 2007

Abstract
Subsea multiphase pumping offers an economic alternative for developing offshore reserves otherwise thought to be unreachable or uneconomical. Primarily for satellite subsea field development scenarios, subsea multiphase pumps can provide pressure boosting and increased production flowrates without the need for satellite surface pumping facilities and riser systems. Such surface facilities can be prohibitively expensive, particularly in deepwater fields.
This paper presents an update on the state of technology of subsea multiphase pumping systems. The potential production benefits of subsea pressure-boosting systems and the advantages of seafloor multiphase pumps relative to other pressure-boosting alternatives are also briefly discussed; field conditions that are especially appropriate for such pumping systems are also outlined.
The general design and operational difficulties facing multiphase units are briefly recounted, and the various generic types of multiphase pumps proposed and tested over the years are listed. The types that are evolving into the leading contenders are briefly described along with a concise and current status of their development. Future development, prototype testing, and field application is also forecasted.
The Use of Metallic Films to Improve Gas-Lift Valve Operability
Authors: Patterson J. C. , Lagerlef D. L. 
Published: December 2007

Abstract
This paper provides a status report of ARCO’s use of thin metal films to improve the operability of gas lift valves. Thin metal films have been used to minimize the problems associated with performance degradation of the gas lift valves due to scale accumulation and sticking of the gas lift valve packing in the mandrel. A brief discussion of the problems, the theory behind the performance improvement with thin metallic films and field test results are provided.
Predictive Model and Verification for Sand Particulates Migration in Gravel Packs
Authors: Bouhroum Ahsene , Liu Xinghui , Civan Faruk 
Published: December 2007

ABSTRACT
A phenomenological model is presented to optimize the performance and to minimize the costs of gravel-packs, which are subjected to severe flow and pressure conditions. The theoretical basis for the development of the model equations is discussed and the equations are derived to represent the mechanisms involved in gravel-pack damage. This model is an averaged representation of the experimentally observed step-like motion of particulates, which is characteristic for particulates transport in gravel-packs. An implicit finite difference solution of the gravel-pack damage model is utilized.
The identification of the model parameters is emphasized. The influence of error in the determination of parameters is estimated by performing a sensivity analysis. Of the three parameters, namely the amount of mobile particulates, the particle deposition rate constant, and particle mobilization rate constant, the last one is found to be less important because particle mobilization is sensitive to reduced transport capacity of the clogged gravel-pack
The model has been verified by data from a set of 35 experiments conducted via large scale non-Darcy flow tests with optically transparent filtration cell. The predictions of the model are found in reasonable agreement with the test results with respect to the particulates migration distance and the amount of mobile particulates.
A Three-Phase Separator for the Removal of Oil and Solids from Produced Water
Authors: Seureau J. J. , Aurelle Yves , Hoyack M. E. 
Published: December 2007

Abstract
A novel three-phase cyclonic separator has been developed to remove solids and oil from produced water in a single unit. This new cyclone configuration combines the functional characteristics found in both desanding and deoiling hydrocyclones. The result is a lighter and more compact system that performs as well as existing hydrocyclones and is particularly adapted to off-shore use.
Modeling of Fracture Propagation During Overbalanced Perforating
Authors: Petitjean L. , Couet B. 
Published: December 2007

Abstract
We present here a model that describes the propagation of a fracture created during extreme overbalanced perforating or overbalanced surge of existing perforations. Model predictions are compared with field results. This paper shows that the wellhead pressure (WHP) decay is well predicted by our model and that this type of operation exhibits new features compared to hydrofracturing operations (high propagation speed, turbulent fracturing fluid flow, noticeable friction losses in the tubing). Finally, a sensitivity analysis defines some of the key parameters affecting the success of such operations. Impact on the fracture extension of the in-situ stress, the WHP, the volume of gas, the formation permeability and the number of fractures is investigated.
The Application of Fluid Injection To Mitigate Coning
Authors: Patel R. S. , Batycky J. P. , Tang J. S. , Lai S. Y. , Tibold M. P. 
Published: December 2007

ABSTRACT
As an oil zone thins during the mature stages of a vertical miscible or immiscible flood, oil production becomes dominated by coning of water, gas and / or miscible solvent. This results in lower revenues and increased operating costs which in turn accelerates well abandonment. In contrast to the early operations of a pool, the remaining oil volumes which are increasingly at risk have access to only limited capital. Coning therefore is controlled by conventional techniques such as re-completions, choking back oil production or intermittent operation. As the effectiveness of these techniques becomes reduced, other less conventional approaches are sought.
Such techniques as the placement of polymeric agents or the injection of oil or water to divert the coning fluids, are becoming attractive because of their low capital requirements. In support of the present work, scaled laboratory experiments and numerical simulation studies have demonstrated the recovery benefits using fluid injection as a way to maintain production from a thinning oil sandwich. Currently, Imperial Oil is developing oil re-injection technology to increase recoveries by 1.5 to 3 percent of the original oil-in-place (OOIP) by reducing solvent coning in a number of their vertical miscible flood pools located in the Pembina Nisku area. A pilot project evaluating this technology has been in operation for nearly a year. After overcoming a number of start-up and other operational problems, the pilot has demonstrated that oil re-injection can successfully control GOR. History matching the pilot performance has confirmed the design approach and performance expectations. Based on the encouraging results, four more projects have been planned for start-up in 1994.
An Integrated Model for Underground Coal Gasification
Authors: Biezen E. N. , Bruining Johannes , Molenaar Johannes 
Published: December 2007

Abstract
Underground coal gasification receives renewed interest in both Western and Eastern Europe because of the vast amounts of otherwise unminable coal deposits that occur on the European continent.
A field test is currently being carried out in Spain. Other countries in Europe show interest in this method of utilizing coal resources. In this study we present a model that describes the development of an underground coal gasifier. Both permeable bed and channel surface gasification are combined with thermo-mechanical failure of both coal and overlying rock. By this combination the model predicts the channel development and thus the sweep efficiency of the gasification process.
The model consists of two modules: the first module solves the flow equations in the entire flow domain. The second module selects a block of coal for gasification and a block of coal and/or rock for thermo-mechanically induced spalling. Other features such as ash content and heterogeneity are included in the model as well.
Model calculations show that the ash content of the coal and the coal and rock spall rate determine largely the sweep efficiency of the gasification process.
The model is used for field test evaluation purposes and can be used for extrapolation of the test results to other situations, e.g. the deep lying thin coal layers that occur in Northwestern Europe.