bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Design Approach, Operational Performance, and Future Prospects for Self-Erecting Semisubmersible Tender Drilling
Authors: Nagel M. E. , Knecht H. I. , Jackson M. L. 
Published: December 2007

Abstract
Tender assisted drilling is an old concept finding a new following. The search for more cost effective methods for platform drilling has lead to a reevaluation of tender drilling. This paper presents a description of a successful design, the design philosophy of the system, a performance review of the system and future prospects for the concept.
Niche marketing is not uncommon to the contract drilling industry. The wide variation in offshore drilling equipment capabilities available to operators indicate clearly that unique solutions have been developed in response to niche market requirements. Rigs categorized by environmental capabilities, drilling depth capabilities, drilling program duration, platform size and space limitations and myriad others have been developed. The semisubmersible tender is, in this respect, merely another such concept, but for what niche?
Operators having older platforms with limited deck space available for a full sized platform rig wanting to drill for new or deeper horizons is an obvious application. The Derrick Equipment Set (DES) which is placed on the platform extends roughly 21 to 30 feet from the well center in directions typically critical to arrangement of packages. This minimizes platform real estate required to perform drilling operations.
Long-Reach, High-Angle Drilling in the Gulf of Mexico: A Case History of Eugene Island Block 370 Well B-11
Authors: Gadberry R. L. , Switzer S. S. 
Published: December 2007

ABSTRACT
NERCO Oil and Gas, Inc. recently drilled and completed its first high angle, extended reach well in the Gulf of Mexico from Eugene Island Block 371. The field is located approximately 85 miles offshore Louisiana in the continental slope Pleistocene producing trend (Fig. 1). The platform is located in 420′ of water and currently produces gas from the 12 slot facility. E1 370 B-11 was drilled to a measured depth of 8958′ MD and a vertical subsea depth of 3000′. Horizontal displacement was 7358′ resulting in a horizontal displacement to vertical depth ratio of 2.45. Maximum angle reached was 90.75 degrees.
First Field Trial of a Coiled Tubing for Exploration Drilling
Authors: Traonmilin E. M. , Courteille J-M. , Bergerot J-L. , Reysset J-L. , Laffiche J-M. Y. 
Published: December 2007

ABSTRACT
Within the scope of comprehensive efforts to reduce the cost of exploration drilling, Elf Aquitaine has performed with Dowell Schlumberger a first trial of open-hole coiled tubing drilling in the Paris Basin. The purpose of this trial was to determine the feasibility of using coiled tubing drilling units instead of conventional rotary rigs to drill slim hole exploration wells. The feasibility has been verified and applies to some specific prospects. A second trial is planned in 1992 in the same basin.
Design and Implementation of a Bulk Mud Additive System to Reduce Personnel Exposure and Eliminate Waste
Authors: Wisnie A. P. , Brazzel Ron 
Published: December 2007

ABSTRACT
In an effort to limit personnel exposure to oilfield chemicals and simultaneously reduce environmental waste, a bulk additive system was designed and installed for handling drilling mud products on a recent drilling project. Although some problems were initially encountered, the system was modified to completely fulfill its objectives. Both occupational safety risks and environmental wastes were significantly reduced. Efforts are currently being made to improve the ease-of-use of this system for future drilling projects.
On the Stability of Shales and Its Consequences in Terms of Swelling and Wellbore Stability
Authors: Santarelli F. J. , Aquitaine Elf , Chenevert M. E. , Osisanya S. O. 
Published: December 2007

Abstract
Recent experimental studies have shown that shales are able to transfer both mass and pressure. Consequently, they are permeable media even though their permeabilities are extremely small.
A series of free expansion tests on shales contacted by various aqueous fluids under high pressure and temperature is analysed in the light of this basic result. It is shown that a strong coupling exists between shale swelling and permeability as clay minerals expansion impairs permeability by at least one and may be two orders of magnitude. Swelling affects therefore the wellbore wall but cannot propagate deep inside the rock. It is also shown that the more inhibited the fluid is, the more permeable the rock remains.
Furthermore careful geochemical analysis show that the water front movement inside the rock is in competition with an ion counterflow. The data suggest that temperature is a major parameter in increasing the rate of such flows.
In the final part of the paper, the consequences of these results are analysed in terms of wellbore stability and it is shown that they form an excellent framework to explain the delayed failures in shales which are commonly encountered in the field.
Dielectric Constant Measurements: A New, Rapid Method To Characterize Shale at the Wellsite
Authors: Leung P. K. , Steiger R. P. 
Published: December 2007

Abstract
Hydratable shales often lead to a variety of drilling problems such as, wellbore instability, stuck pipe, and solids buildup in drilling fluids. It is important that a timely measure of hydratable clay content in shale formations be available during drilling so that appropriate action can be taken to minimize their detrimental effects. A new dielectric constant measurement (DCM) technique was developed to allow rapid, quantitative determination of shale properties at the wellsite, using a small sample of cuttings. Specific surface area is a measure of the total hydratable surface in a rock and is dominated by the hydratable smectite clay present. The dielectric constant for a shale is also strongly influenced by the presence of hydratable clays and can be correlated with specific surface area. A dielectric constant to surface area correlation was developed based on tests on hundreds of cuttings samples from many wells from around the world and thus shale surface areas can be obtained from DCM data. The wellsite DCM test is run with an inexpensive, portable test kit. Field tests on several Exxon wells showed that DCM data can be collected routinely on-site by the mud logger. This paper introduces the wellsite DCM test procedure and presents field results.
Industry Participation in the Development of an Integrated Drilling Engineering Applications Platform
Authors: Sawaryn S. J. , Grayson H. L. 
Published: December 2007

Abstract
In 1990, BP Exploration with EXLOG, Inc. commenced work on the development of a new drilling information system to support current and future drilling engineering applications.
A formal structured analysis and design methodology was employed successfully to develop a model of the drilling business, which was then used to establish the system's requirements. Information was provided by a wide range of representatives from various disciplines worldwide. The formal analysis, conducted in this way provides a sound basis for the development and future evolution of the system, though it is costly and cannot be entirely objective. Work has now commenced on the construction of the system.
The Designing and Building of an All-Purpose Automatic Torque-Wrenching Machine for Drilling Rigs
Authors: Kinzel Holger , Pietras B. G. 
Published: December 2007

Abstract
Drilling rig automation is one of the key issues for the future of safe and economic drilling operations. Tripping, as well as casing and tubing running operations, represent the considerable amount of total rig time of more than 30%. These operations incorporate the risk of possible accidents due to the manual work involved.
A hydraulic automated torque wrenching machine was developed which is capable of spinning and making up a full range of drillstring components as well as tubing and casing connections in a diameter range between 2 3/8″ and 21″. This wide size range in connection with the high torque values of up to 190,000 Nm (140,000 ft lbs) called for new concepts and developments, which are described. The full integration of this automated torque wrenching machine into an automated drilling process includes a computer based joint analyzed makeup system.
Cementing as a Total Service
Authors: Stilley R. D. , Griffith J. E. 
Published: December 2007

Abstract
Economic realities and an increasing emphasis on quality improvement and quality management have prompted a re-evaluation of the relationship between service companies and operators or drilling contractors and the ways in which they interact to perform oil and gas well cement jobs. The authors believe that on a global basis, drillers and producers would benefit from forming partnerships with service companies wherein more responsibility for the cementing operation is passed to the service company to plan and execute the work.
Using this approach, the service company would manage all aspects of the cementing program from planning prior to spudding the well through to production or abandonment.
Precedents for this type of partnership have been set by cooperative actions between service companies and operators in the past, such as (1) joint research projects, (2) interdisciplinary problem solving teams, (3) joint introduction and testing of new technologies, and (4) turnkey operations.
Potential benefits to the operator include the following:
Improved quality and improved results can be expected, and the quality of service would be uniform from one job to the next. Operators’ engineering staffs can concentrate on other aspects of the drilling and completion process. Since the service company is responsible for procurement of all materials used in the cementing process, quality can be more easily assured. By working more closely with operators or drilling contractors, the service company will have opportunities to make significant contributions in reducing total drilling and completion costs. By utilizing experience gained worldwide in cementing partnerships and by applying the best practices for particular situations, the service company is able to provide improved service to the operator. Allows for possible implementation of incentive agreements for cementing services.
Presented is a discussion of all aspects of the concept, including implementation plans.
A Field Guide for Surface BOP Equipment Inspections
Authors: Kandel W. J. , Streu D. J. 
Published: December 2007

Abstract
This document describes a detailed inspection procedure used to detect faulty BOP stacks and control systems. It includes a comprehensive visual inspection and a hydraulic operator test procedure, both of which enhance a routine pressure test.
The goal of the authors is to provide a field guide to assist wellsite personnel in performing thorough BOP equipment inspections. The ultimate goal is to ensure the BOP stack and control systems are in proper working condition.
Precontract Prescription for Success: A Painless Subsea BOP Inspection
Authors: Rawicki A. T. , Gallander F. B. , Gillis B. T. 
Published: December 2007

Abstract
Performing precontract inspections on subsea blowout preventer stacks and their control systems have proven beneficial to both the contractor and operator. General inspection procedures and actual field results are detailed, and estimated savings are quantified. Contractor perceptions of the program are discussed, as are the benefits of having an inhouse inspection team.
Casing Operations on Deep, Directional, and Horizontal Wells: A New Approach on Planning and Follow-Up
Authors: Possamai Ermenegildo , Bianchi Roberto 
Published: December 2007

ABSTRACT
Centralizer/hole size combinations, minimum centralizer restoring forces and recommended test procedures are specified in API specification 10 D. This specification also includes a recommended procedure for calculating the lateral forces exerted by casing on centralizers in 2-D inclined borehole. However these recommendations are no longer adequate for highly deviated/horizontal boreholes and deep, heavy strings. Extensions are needed in order to consider 3-D borehole curvature variations due to simultaneous changes in hole inclination and direction and to guarantee the influence of external loads on the casing strings.
A computer program, named "Lateral Load Program (LLP)", was developed and field tested during the last few years based on the above assumptions. The LLP has the capability to calculate, starting from wellbore profile data (measured depth, inclination and direction), the dogleg severity, the spacing (constant or variable), the axial and lateral loads. The program also computes the stand-off according to the sag deflection prediction, based on lateral load and tension force from the pipe hanging below the centralizer, and generates a casing stand-off/depth/deviation and the hookload diagrams in advance, representing a valid support for operational planning and follow-up.
Actual field data studies show that the LLP is accurate in predicting the real hookload;in the cased hole such predictions are exact, whereas in open hole they are few tons of the actual up and down weight. As a result of our field experience in many years of drilling activity, it is possible to conclude that achieving a stand-off of 60-70% is not enough to avoid channelling and to obtain proper cement placement. Based on this experience, by late 80's the casing centralizers spacing in deep, deviated and horizontal wells was optimized in order to achieve, as close as possible, a 100% stand-off. Several field examples confirm this assumption. The LLP is still upgrading and the fixed ends boundary condition is used in the last version (’91) for the calculation of casing deflection between two centralizers.
Acid Removable Cement System Helps Lost Circulation in Productive Zones
Authors: Vinson E. F. , Totten P. L. , Middaugh R. L. 
Published: December 2007

Abstract
Lost circulation into a potential producing zone typically creates a dilemma for the drilling engineer: lost circulation materials which are readily removable from the formation typically lack strength, while strong materials like cement can permanently damage the zone. This paper describes laboratory development and field usage of a high-strength cementitious system which is over 96% soluble in hydrochloric acid.
This acid-removable cement has been formulated to have moderately thixotropic properties, but with sufficiently small particle size and low rheologies to penetrate near-wellbore fractures and voids. The synthetic cement is readily mixed using conventional oilfield cementing equipment. Thickening times and fluid loss behavior are controllable up to 220°F fluid temperature using dry-blended additives.
The paper presents laboratory data on slurry properties, strength development, and acid solubility and reaction rates for this cement system. Case histories of field application in instances of lost circulation to a producing horizon are discussed. Potential areas of application in gas storage fields, temporary abandonments of high (or low) pressure zones, and blowout control are also treated.
Drilling Safely at Well Design Limits: A Critical Well Design Case History
Authors: Quitzau Robert , Muchtar J. B. 
Published: December 2007

ABSTRACT
Risks of blowouts while drilling deep, high pressured wells can be managed through strenuous well planning and operational contingencies. A new risk management parameter, killable kh, along with conventional drilling parameters were used on the Madura CD-1 well to select casing points, develop operational contingencies and safely drill to high pressured objectives offshore Indonesia.
Horizontal Injection and Production Wells for EOR or Waterflooding
Authors: Taber J. J. , Seright R. S. 
Published: December 2007

ABSTRACT
This paper describes the potential benefits of using combinations of horizontal injection and production wells for EOR processes or waterflooding.
Our results show that a very favorable configuration occurs when two opposed horizontal wells are drilled from injection and production wells so that the opposed laterals are parallel in the patterns, and extended until the horizontal segments almost meet midway between the like wells. Compared to five-spot patterns with vertical wells, opposed horizontal wells can increase injectivity (injection rate per applied pressure drop) by as much as a factor of ten, depending on well spacing and formation thickness. Areal sweep efficiency can be increased by 25% to 40%. The horizontal-well advantages are greatest for thin formations with wide spacing, and decline significantly for thick formations and/or close spacing. Also, for a given injection pressure, the pressure gradient in the bulk of the reservoir can average several times greater when using opposed horizontal wells than when using vertical wells. This could significantly improve microscopic displacement efficiencies for EOR processes, such as micellar/polymer flooding, that are sensitive to interfacial tensions.
Because of the better sweep efficiencies, faster flooding rates, and/or lower injection pressures that are possible with horizontal wells, all EOR methods should benefit by their use. For example, polymer floods can be improved by the higher injectivity and lower rates of shear at the injection sandface. The advantages of horizontal wells for CO2 flooding include: (a) delayed CO2 breakthrough because of the better sweep efficiency, (b) the potential for maintaining the MMP in more of the reservoir with no increase in the injection pressure, (c) better injectivity at the same pressures, and (d) the opportunity to convert more pumped producers to flowing wells. Thermal EOR was not investigated in this work, but the cited references show that horizontal wells have been successful in several field applications and more projects are being planned.
A Simple Technique to Forecast CO2 Flood Performance
Authors: Shaw E. C. 
Published: December 2007

Abstract
This paper presents a technique which takes a one-dimensional (1D) compositional simulation output and scales the results up to an entire pattern. The scale-up procedure takes into account the pore volume and heterogeneity of the pattern. Several parameters are adjusted to match the production history allocated to the pattern. Once a model has been developed to reproduce the waterflood performance, the initial date and target volume of carbon dioxide (CO2) injection is specified.
This scale-up technique has been successfully applied to forecast the performance of the McElmo Creek Unit CO2 project (SE Utah), in operation since 1985. A history match was obtained for each of the 119 patterns in the project. In the mature CO2 flood patterns, both secondary and tertiary performance was matched. The composite of all the pattern forecasts closely follows the actual production history. The production and injection forecasts will be used to determine future water handling and gas processing requirements, and will assist with planning the timing of further field development.
The Rotating Tubing Hanger System: A Unique New System Designed to Extend the Run Time of Rod Pumped Wells
Authors: Lacy R. D. 
Published: December 2007

ABSTRACT
Beam pump systems are among the most cost efficient artificial lift systems in the industry, assuming a long run time between pulling jobs to repair tubing failures caused by rod wear. The tubing string represents the second largest investment in the well. Tlie longer the period of time the well can be kept on-line and producing between pulling jobs, the more efficient and cost effective is the beam pump system.
This paper will describe in detail the conception, development and implementation of a new system that extends tubing life on rod punped wells. The system Lises a very simple concept; rotate the tubing string to extend the length of time between tubing failures and the resultant pulling jobs. The system is pcwered directly from the walking beam and requires no additional power source; nor does the system use any additional energy.
Case histories will be presented that document the effectiveness of the system in extending tubing life and reducing operating costs on rod pumped wells. Data will be presented which shews the system can be effective in reducing problems caused by paraffin build-up, resulting in extended pumping time and additional savings in operating expenses.
Pressure Transient Digital Data Acquisition and Analysis From Acoustic Echometric Surveys in Pumping Wells
Authors: McCoy J. N. , Podio A. L. , Becker Dieter 
Published: December 2007

ABSTRACT
Increased efficiency in production operations requires that the formation and completion characteristics be well defined and analyzed before committing funds to stimulation and/or workover operations. Such information is generally obtained from analysis of pressure transient data measured with wireline recorders. Until recent times, these measurements have been seldom made in pumping wells, due to the time required to trip the rods and pump out of the tubing in order to run the wireline pressure recorders. This need spurred the development of techniques for calculation of transient bottomhole pressure from surface measurements.
This paper describes the design and application of a fully digital system for automatic calculation of bottomhole pressure from echometric surveys of the annular fluid level. This portable system integrates specially designed high resolution A/D conversion and conditioning with advanced signal processing and digital filtering techniques. This results in very accurate determination of the depth to the fluid level, even in the presence of background noise caused by gaseous liquid columns.
Automatic signal generation and recording is undertaken by the software at predetermined, operator selected frequency so as to maximize the quality of the pressure transient data. Surface pressure and temperature measurements are used in conjunction with gas gravity and gas acoustic velocity to determine the pressure at the gas/liquid interface and the pressure at the sandface.
Graphic displays allow the operator to monitor the progress of the transient test by plotting in real time the current status of the well, the acoustic signals and the calculated pressures. Data that has been acquired at that point can be plotted as standard transient analysis graphs ( Horner, MDH, Log-Log etc.) Data files can be exported to other analysis programs.