bluuebunny/crossref_metadata_2025_split huggingface dataset:
Building a Full-Scale Live Well Simulator
Authors: Hytten Nicolai , Thorsrud A. K. 
Published: December 2007

ABSTRACT
A land rig used for training purposes was upgraded into what may best be described as a full-scale drilling simulator. On-line computer simulation in combination with a fully operational drilling rig open up for staging of various realistic operational situations, to provide practical, hands-on training of drilling personnel in the controlled, safe environment of the live well school.
The rig/software combination has e.g. provided the live well school with a feature which was previously missing: the possibility to drill. By defining a simulated "false" bottom depth, the driller is presented with software-generated indications of weight on bit and penetration rate which realistically respond to the driller's actions on the rig controls.
The final goal should be to use the combination of live well and computer facilities to create a full-scale well control and drilling simulator, for training in well control, stuck pipe avoidance, and handling of similar drilling related problems. This may be done to the point where a student will be presented with conditions similar to those prevailing on one existing drilling location, and through hands-on manipulation of the training rig, acquires drilling experience applicable to that particular area.
Downhole Emulsification for Improving Paraffinic Crude Production
Authors: Beyer A.H. , Osborn D.E. 
Published: December 2007

This paper was prepared for the 44th Annual Fall Meeting of the of the Society of Petroleum Engineers of AIME, to be held in Denver, Colo., Sept. 28-Oct. 1, 1969. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal, provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
The downhole emulsification process has been used to improve the process has been used to improve the producibility and reduce the producibility and reduce the operating cost of oil wells that produce waxy, paraffinic crude. To apply the process, a surface-active chemical process, a surface-active chemical (surfactant) is injected into the well bore to form an oil-in-water emulsion downhole. Produced water in this emulsion wets the steel surfaces with a water film that reduces the adherence of oil and wax. This improves well operation and reduces the need to periodically remove wax deposits by hot-oiling or other means.
Benefits from the process have been demonstrated in a four-month field test involving six pumping wells that produce a paraffinic crude with a 105 degrees F pour point. Wax deposition in wells and flowlines was significantly reduced during treatment with surfactant, permitting 44% fewer hot-oil jobs. Average net gain from reduced operating cost and increased production from the test wells was about $1870 per well per year.

Introduction
The cost of paraffin control in the domestic petroleum industry is estimated by Bilderback and McDougall to be in excess of $5 million annually. This includes only the direct costs of periodic removal of paraffin deposits from oil wells and paraffin deposits from oil wells and surface facilities. Not included are the costs of lost production, increased power requirement, reduced equipment life, and additional labor resulting from wax buildup.
Various methods, such as heat, solvents, plastic-coated pipe and chemical additives, have been used by the petroleum industry in the past to reduce paraffin deposition. past to reduce paraffin deposition. However, to the authors' knowledge these techniques lose much of their effectiveness and economic advantage in wells producing paraffinic crude that has a high wax content.
The Hyde Development: Sharing Risk and Reward
Authors: Rhodes C. P. , Finch D. J. , Mound D. G. 
Published: December 2007

Abstract
The Hyde Gas Field is a relatively small pool to the North of the West Sole Field, some 70 kilometres east of the English coastline.
Whilst advanced technology and best practice have taken the Hyde project to the launchpad of success, a shared risk and reward strategy has propelled the field beyond the standard orbit of performance for marginal developments.
In 1989, the Hyde project was going nowhere fast.
Propped Fracture Stimulation in Deviated North Sea Gas Wells
Authors: de Pater C. J. , Hagoort J. J. , Abou Sayed I. S. , Donders R. S. 
Published: December 2007

Abstract
We analysed the influence of well deviation on hydraulic fracture treatments in gas bearing Bunter formations, offshore Holland. The reservoir permeability ranged from 2 to 20 mD, which was relatively high for stimulation. Analysis of the pressure records of injection tests and treatments indicated low net fracture pressure and contained fractures. Most treatments ended in wellbore screen-out, giving a high fracture conductivity, especially near the wellbore. The success of the treatments was due to by-passing of a severe skin as well as stimulation of the formation. Also, the well was connected to additional flow units, evidenced by a substantial increase of the permeability (obtained from well tests) after the treatments. In a deviated well we observed gas entry into a small section of the perforated interval. However, there was no indication for a reduced performance of wells with a large deviation compared to the performance of vertical wells.
Effects of Tortuosity in Fracture Stimulation of Horizontal Wells – A Case Study of the Dan Field
Authors: Kogsbøll H. H. , Pitts M. J. , Owens K. A. 
Published: December 2007

ABSTRACT
The horizontal wells, drilled in the Dan field of the Danish sector were initially stimulated with acid fracture treatments, the industry standard for a chalk reservoir. The placement of these treatments proved effective, however, the long term production was limited due to the low formation integrity and consequent collapse of the induced fracture system.
Propped fracture treatments replaced the acid treatments and the benefits to productivity were quickly seen. However, the placement of proppant in some of the Dan horizontal wells was difficult, and in some cases impossible using conventional techniques.
The difficulties in placement of proppant in the Dan field have been attributed to near wellbore tortuosity. This phenomenum occurs due to a variety of situations, namely when well trajectory is not in line with fracture direction, poor cement integrity in the perforated region, and perforation dominated creation of complex fracture patterns in the near wellbore vicinity.
This paper describes the mechanism of tortuosity and its effect on fracture stimulation treatment placement by reviewing several field examples of this phenomenon. The paper also reports modelling procedures utilized to predict the effect of tortuosity. Practical guidelines for removing tortuosity are provided, which have greatly increased the probability of successful proppant placement.
Through better understanding of tortuosity, modifications to completions and stimulation procedures have been implemented which have resulted in over 200 propped fracture treatments being successfully placed from horizontal wells in the Dan field.
Pressure Transient Test Using Mathematical Properties of Type Curve Models
Authors: Alvarado D. A. 
Published: December 2007

ABSTRACT
By taking the derivative of the Bourdet et. al.1 derivative type curve in the Laplace space, using Laplace Transform properties and the Stehfest algorithm the maxima of the curves were found. By inspecting these results it was found that for damaged wells (CDe2S&gt;103), the locus follows a straight line at 45 degrees to the horizontal and parallel to the line Pure Wellbore Storage. The intersection of the extrapolation of this line with the line of zero slope corresponding to radial infinite behavior, defines a unique point over the Bourdet et. al.1 type curve. This point is used as a matching point and that is enough to perform type curve analysis without the use of the type curve.
The method has been extended to analize interference tests, hidrauhc fractured reservoirs well tests and naturally fractured reservoirs well test. Several field examples are presented to illustrate the aplication of the method.
A Muitidisciplinary Study of the Complex Northern Monagas Oil Field, Eastern Venezuela
Authors: Robinson A. C. , Diamond L. F. , de Salazar A. 
Published: December 2007

ABSTRACT
The Geology of Production Study of The Northern of Monagas Oil Fields was done with the participation of a muitidisciplinary team of Geologist, Geophisicists, Petrophisical and Reservoir Engineers. Being the main objective to elaborate the best geological model for the known reservoirs in the area by means of new geological, seismical and engineering techniques. AJ] this was valuable to cuantify reserves as well as to optimize the explotaition schemes proposed for the medium and long term planning.
Sand Production as a Viscoplastic Granular Flow
Authors: Geilikman M. B. , Dusseault M. B. , Dullien F. A. 
Published: December 2007

ABSTRACT
A continuum model for sand production is developed by considering coupling of fluid flow and rate-sensitive plastic flow of granular matrix. Initial granular matrix yielding is reached as a result of wellbore fluid pressure reduction (drawdown) below some critical level. The model provides a physical mechanism of yielding front propagation away from the wellbore as the process of sand production continues. Mass balance analysis leads to a relation between cumulative sand production and the current yielding front location. Different regimes of sand production, limited and unstable, are considered. Fluid production enhancement because of simultaneous sand production turns out to be dependent not only on instantaneous sand flux, but also on the current radius of the yielded zone around wellbore, that is, the history of sand production for the well.
Mudcake Cleanup To Enhance Productivity of High-Angle Wells
Authors: Browne S. V. , Smith P. S. 
Published: December 2007

ABSTRACT
The productivity of wells with non-perforated completions can be impaired by both mud filtrate invasion and incomplete mud filter cake removal. Well inflow modelling illustrates that the percentage of the interval flowing and the distribution of the flowing intervals, are more important than the filtrate induced permeability reduction around the wellbore. Therefore adequate filter cake removal is essential for optimum well performance. This paper addresses both physical and chemical methods of mud filter cake removal.
Development of Advanced Drilling, Completion, and Stimulation Systems for Minimum Formation Damage and Improved Efficiency: A Program Overview
Authors: Layne A. W. , Yost A. B. 
Published: December 2007

ABSTRACT
The Department of Energy's (DOE) Natural Gas Resource and Extraction Program consists of industry/government co-sponsored research, development, and demonstration (RDfiD) projects, which focus on gas recovery from both conventional and nonconventional resources. The Drilling, Completion, and Stimulation (DCS) Project focuses on advanced, non-damaging technology systems and equipment for improving gas recovery from conventional and nonconventional reservoirs. As operators move from development of current day economically attractive gas-field development to the lower permeability geologic regions of domestic onshore plays, increasing the emphasis on minimum formation damage DCS will permit economic development of gas reserves. The objective of the Project is to develop and demonstrate cost-effective, advanced technology to accelerate widespread use and acceptance of minimum formation damage DCS systems. The goal of this product development effort is to reduce costs and improve the overall efficiency of vertical, directional, and horizontally drilled wells in gas formations throughout the U.S.
The current focus of the Project is on the development of underbalanced drilling technology and minimum formation damage stimulation technology concurrently with the appropriate completion hardware to improve the economics of domestic natural gas field development. Ongoing drilling technology projects to be discussed include development of an electromagnetic measurement while drilling system for directional and horizontal drilling in underbalanced drilling applications and . the development of a steerable air percussion drilling system for hard formation drilling and improved penetration rates. Ongoing stimulation technology projects to be discussed include introduction of carbon dioxide/sand fracturing technology for minimal formation damage.
Formation Damage in Gravel Packed and Non-Gravel Packed Completions: A Comprehensive Case Study
Authors: Chuah Beng-Swee , Hasumi A. R. , Samsudin Noren , Matzain Ahmadbazlee 
Published: December 2007

ABSTRACT
A comprehensive formation damage study was undertaken on selected fields in the Baram Delta acreage, offshore East Malaysia, to determine the extent and main causes of formation damage in the area. This was due to the high skin factor values interpreted from most transient well tests conducted throughout the years. A total of 70 gravel packed and 60 non-gravel packed wells (involving 220 completion zones) in 6 fields were covered in the study.
Based on statistical and pressure transient data analysis as well as an in-depth review of drilling and completion activities, it was found that the majority of non-gravel packed wells have low or negligible formation damage. Between 60 and 70% of the non-gravel packed wells have skin factors of less than 10. Most of these wells have constant skin factors as a function of time indicating that the damage, if any, did not increase with oil production.
On the other hand, the majority of gravel packed wells were damaged. As much as 70% of these wells have skin factors varying between 10 and 40. About half of these gravel packed wells have skin factors which increased with time indicating that the damage worsened with oil production. Formation damage in these gravel packed wells may be attributed to the gravel packing operations. This was further substantiated by well test results which showed that skin factors immediately after perforating were essentially zero while those determined from pressure build-up tests carried out at a later date after gravel packing operations were in the order of 10 to 100. It was also observed that although improvements in gravel packing and perforating practices were implemented through the years, no significant enhancement of flow efficiencies had resulted.
Productivity Comparison Of Sand Control Techniques Used for Completions in the Vermilion 331 Field
Authors: Mullen M. E. , Norman W. D. , Granger J. C. 
Published: December 2007

Abstract
This case history covers three different types of sand control completion techniques used to complete the Ang B and Lentic reservoir sand series. This paper makes a comparison of the following techniques: Slurry packs, Water packs and Frac packs on 16 completions. This paper includes a rudimentary description of the techniques covered. It includes a brief review of the data evaluated for design considerations in selecting the different techniques used in each case. A review of execution considerations, procedural requirements and an evaluation of the completion performance is also included.
The evaluation of completion techniques for optimum reserve recovery is a controversial topic. Case histories help to separate fact from presumption when fairly evaluated. In an effort to fairly evaluate these completions, a normalized productivity index was developed and used. This paper evaluates the old and new completion techniques employed in the Vermilion 331 field.
Formation Damage and Skin Factor Due to Filter Cake Formation and Fines Migration in the Near-Wellbore Region
Authors: Liu Xinghui , Civan Faruk 
Published: December 2007

ABSTRACT
Particle invasion and fines migration are among the major factors causing formation damage. Extensive studies of formation damage in laboratory and several modeling efforts for prediction of formation damage have been reported in the literature. However, a satisfactory model to simulate the near-wellbore formation damage in field conditions is still not available. In this paper, the linear flow core-scale model presented previously by Liu and Civan is converted into a radial flow field-scale model to simulate the formation damage near wellbore regions in actual field conditions. The radial flow field-scale model utilizes the values of model parameters obtained by a model assisted analysis of the laboratory core tests to determine the temporal and spatial variation of formation damage and the associated skin factor. Simulation results indicate that the overbalance pressure of drilling fluids is an important factor for formation damage control and that the formation damage due to constant-pressure mud filtration is less severe in two-phase flow of oil and water than single-phase flow of water in the formation.
Ultrasonic Treatment for Removal of Asphaltene Deposits During Petroleum Production
Authors: Gollapudi U. K. , Bang S. S. , Islam M. R. 
Published: December 2007

ABSTRACT
Crude oils produced in many parts of the world contain asphaltenes. Asphaltenes are known to deposit in the vicinity of production wells during miscible floods or during thermodynamic changes. Asphaltene deposition leads to production loss and involves expensive corrective measures. This study proposes a new technique for cleaning asphaltenes with an ultrasonic device. A laboratory ultrasonic disruption device was used in this study to carry out experiments. A thin layer of asphaltene was applied to small glass beakers and the beakers were ultrasonically treated for different time periods at different amplitudes in aqueous and kerosene media, separately. Subsequent to ultrasonic treatment, the weight loss fractions were calculated. In a second series of experiments, a two inch long column of asphaltene/sand mixture was placed on top of a sand column in a flow cell, and the flow rates were measured before and after the ultrasonic treatment. The flow rates were correlated with those of sand packed columns in absence of asphaltenes.
Experimental results indicated that the asphaltenes get disrupted effectively after a minimum exposure of one and a half minutes to ultrasonic radiation. However, the maximum amount of cleaning was noticed after an exposure of two minutes and at higher cycles that affect amplitude of the ultrasonic radiation. The increased flow rates measured after the treatment indicated that the technique can be used in an oil-field to disrupt, or desegregate asphaltenes from the vicinity of producing oil-wells. However, simultaneous pumping is recommended during the ultrasonic irradiation, to avoid the reprecipitation of the disrupted asphaltenes. The ultrasonic cleaning appears to be disrupting the maltenes that form a continuous phase to provide adhesive and ductile properties to the dispersed asphaltenes. If this technique is used, following scaled studies, in a field with a modified device, it can reduce the expenditure of taking corrective measures, and can provide technological breakthrough to petroleum industry.
Experiences Gained in the Use of Frac-Packs in Ultralow BHP Wells, U.S. Gulf of Mexico
Authors: DeBonis V. M. , Rudolph D. A. , Kennedy R. D. 
Published: December 2007

ABSTRACT
Four wells in the U.S. Gulf of Mexico were worked over in reservoirs with bottomhole pressures (BHPs) ranging from 0.17- to 0.23-psi/ft gradients using the frac-pack technique. The purpose of the paper is to detail the chronology and expose the learning curve which led to the successful completions. Treatment tools, tubulars, design, rate, and fluid selection are discussed as they were applied in the implementation of each successive treatment.
Effect of the Perforation Damage on Well Productivity
Authors: Asadi Mahmoud , Preston F. W. , Green D. W. , Ghalambor Ali 
Published: December 2007

Abstract
This paper reveals new information on the reduction in productivity caused by the crushed zone surrounding a jet perforation tunnel. A Berea sandstone sample was perforated according to a slightly modified API RP 43 Recommended Practice Standard Procedure for perforation, using a 3.5 gr. RDX type charge. The crushed zone was identified using a scanning electron microscope, SEM. The crushed zone was divided into a number of cells both radially (away from the shot center) and longitudinally (along the perforation tunnel). Porosity and permeability of each cell were obtained using image analysis. The permeability value of each cell was arranged around the perforation tunnel according to their original orientations. Using a black oil simulator, productivity of a well was found and compared to one where no permeability reduction was assumed for the crushed zone. In addition, the Dykstra-Parsons relation was employed to estimate permeability values for a suite of 20 cells. The estimated values were then oriented around the perforation tunnel in ascending, descending, and randomly orders. Productivity of the well was obtained for each permeability orientation. A 55% permeability reduction around the perforation tunnel, as the result of the perforation process, led to a 60% reduction in well productivity. Also, ascending orientation of the permeability around the perforation tunnel resulted in a higher well productivity than descending or random orientation.
A Current Look at Thermal Recovery
Authors: Ramey Henry J. 
Published: December 2007

Abstract
Modern interest in thermal recovery began in the early 1950's with discovery of the insitu combustion process. By the end of the 50's, the first commercial installations of insitu combustion had been made and are still operating today. But there are only a handful of commercial insitu combustion operations, most of which are located in California. In the early 1960's, the main interest in thermal recovery shifted to cyclic steam injection and production of oil. Where applicable the cyclic process has been very successful and many California operators feel they have fully-developed their cyclic steam injection potential. Currently, interest appears to be shifting toward operations involving continuous injection coupled with cyclic steam injection stimulation of producing wells. Cyclic steam injection is one important factor credited with arresting declining oil production rate in California.
Economically successful thermal oil recovery operations of all three major types: insitu combustion, continuous steam injection, and cyclic steam injection, are or have been conducted in many portions of the world.

Introduction
The start of modern interest in thermal recovery dates from publications on insitu combustion in the early 1950's. It was evident from the beginning that there were a large variety of ways to introduce heat into an oil reservoir. Many publications and patents concerning hot fluid injection and patents concerning hot fluid injection and variations on insitu combustion appeared throughout the 1950's. By the end of the decade, the important features of continuous drive thermal methods such as combustion, steam, and hot water injection were thoroughly documented in the literature. In regard to field operations, a number of pilot tests of insitu combustion had been conducted and described, but very little was known regarding field results of hot fluid injection. It was evident that insitu combustion was not economically feasible in all heavy oil reservoirs, and thus a growing interest in hot fluid injection was appearing.