bluuebunny/crossref_metadata_2025_split huggingface dataset:
Failure Prevention by Selection and Analysis of Drillstem Connections
Authors: Armstrong G.M. , Wadsworth T.M. 
Published: December 2007

Abstract
Connections for drill stem components are routinely selected on an as-available basis or with little regard for the function of the connections. This occurs because most of the effort in drill stem design is usually concentrated on the operating characteristics of the pipe and tools. Dependent upon the type and condition of the connections selected and the drilling conditions encountered, the connections may be a major source of failures and other operating problems. By planning and selecting connections with performance characteristics appropriate for specific drill stem components, the risk of failures can be significantly reduced through more accurate designs which identify and minimize weaknesses.
This paper discusses a systematic method of identifying and analyzing connection characteristics which are pertinent to drill stem design. An understanding of connection characteristics and how to analyze and compare them is provided. Basic characteristics such as bending strength ratio and make-up torque are reviewed. Also included are the effects of machining variations such as stress relief grooves and characteristics such as torsional strength ratio, bearing stress and external load capacity.

Introduction
The design and selection of drill stem components usually occurs after the framework of the drilling programs, such as the directional program, tubular design and hole sizes, have been completed. Consequently, it is often given minimal attention even though the affects can be substantial. Some of the common criteria are:Selection of components based on inside and outside diameter (ID, OD) without regard for the connection.Use of the lowest priced equipment (such as contractor furnished components), the lowest priced rental equipment available or locally available rental tools.Selection of equipment with connections which will minimize the number of crossover subs required.
When selected in this manner, the connections may be inadequate or mismatched and result in higher failure frequencies.
To reduce the risk of failure, the connections should be matched to the component by taking into account the anticipated operating conditions and predominant failure mechanisms. The method described in this paper is:Selection of connection OD based on hole conditions, contractor equipment capacities and equipment availability.Selection of the optimum connection, including size, thread form, ID and special features based on the performance properties of the connections.Development of operational criteria for the connection including make-up torque and dimensions (OD and bevel diameter).

SELECTION OF CONNECTION OD
The selection of component and connection OD's should consider the factors described below. Since the emphasis of each item must be tempered by the anticipated drilling conditions, the priority of each factor must be considered on a well-by-well basis.
P. 207^
A Case History of a Trouble-Free, 20,000-ft Well: Teamwork Pays Off
Authors: Chaney B. P. , Nelson J. 
Published: December 2007

ABSTRACT
Combining the best efforts of operator, drilling contractor, and service company personnel is the goal on any drilling project. This is exactly what happened on Ballard Exploration's Carey and Corolla #1, in Grimes County, Texas.
A partially hydrolyzed polyacrylamide (PHPA) was used as a protective colloid in a low pH, low solids mud system to prevent cuttings dispersion and promote wellbore stability. The optimization of mud properties and a preventative approach to hole problems was responsible for reaching 20,631 feet (6288 m) in a safe and trouble-free manner. The consensus of all concerned parties was that the primary reason for these desirable results was the hole stability achieved with this inhibitive water-based mud. Obviously, there were other factors which played an important part. Teamwork, and careful attention to detail, allowed total depth to be reached in only 119 days, and 2184 rotating hours. Overall drilling performance was improved compared to offsets in the area.
Well Control Insurance: An Overview and Outlook
Authors: Rice W. E. , Burris G. D. , Johnson B. C. 
Published: December 2007

ABSTRACT
Insurance designed strictly for and tailored to risks inherent in oil and gas operations has been available since the 1940's. Originally, this insurance was offered to operators and nonoperators and covered only indemnification for costs incurred to control blowouts, fires, or craters, but over the years, coverage has evolved so as to extend protection to operators, nonoperators and drilling contractors for indemnification for other costs incurred consequent upon the occurrence of events the risks of which are inherent in day to day drilling operations.
The purpose of this paper is to discuss the history of "well control insurance" as well as to touch upon current changes which will shape its future. In addition to generally discussing the duties and responsibilities of operators, nonoperators and drilling contractors in the proper formulation and presentation of an insurance claim consequent upon the occurrence of a loss suffered during the drilling of or other operations concerned with an oil and/or gas well, the recently developed and newly accepted form of control of well insurance wording entitled "Energy Exploration and Development Insurance (8/86)" receives comprehensive treatment.
A Look Ahead: Back to Basics?
Authors: Turrentine R. E. 
Published: December 2007

ABSTRACT
The future status of the offshore drilling contracting business is very uncertain. Assuming that oil and gas will continue to be in demand, it is important to identify and implement steps that can restore the offshore contracting business to a sound footing. Fundamentals of the business must be redefined, understood and applied. Rational pricing for drilling services should be a natural consequence as exploration activity increases over the longer term.
Scientific Approach Leads to Bottomhole Assembly Standards
Authors: Kadjar D. , Delafon H. , Leveque O. 
Published: December 2007

ABSTRACT
Great progress has been made in the understanding of bottom-hole assembly behaviour through computer programmes. However, in the operating company the Drilling Engineer does not yet benefit from this progress. Operating charts should be set up with possible adjustment to field characteristics.
This paper first presents a thorough analysis of the mechanics behind pendulum bottom-hole assemblies. An optimization principle is introduced which allows maximum weight-on-bit. A table recaps the optimized pendulum bottom-hole assemblies for vertical wells.
The second part of this paper deals with directional drilling where, in most cases, a great number of wells have to be drilled in a specific area at various inclinations. Basic designs for lock-up, build-up and dropping bottom-hole assemblies are presented with charts, field recommendations and practical examples. The proposed designs ensure a weak sensitivity of the bottom-hole assembly to variations in drilling conditions. Directional reports for bottom-hole assembly runs must be carefully filled in and stored in a data base. Thus a statistical analysis can be made allowing precise adjustment of the bottom-hole assembly by changing one parameter only.
This application of the bottom-hole assembly models and the use of a data base enable the operating company to define bottom-hole assembly standards to reach the target:
– with the minimum number of bottom-hole assembly runs, – with the optimum drilling parameters, – with the minimum dog-leg severity.
Application of Thermally Stable Polycrystalline Bits/Downhole Motors in West Texas
Authors: Weaver G. E. , Bunch W. D. 
Published: December 2007

ABSTRACT
The use of thermally stable polycrystalline (TSP) bits run on downhole motors has proven to be economical in some West Texas development oil fields. A significant increase in penetration rate and a corresponding decrease in cost-per-foot was achieved with TSP bits and downhole motors in comparison to conventional rock bit performance.
Three different designs of TSP bits were tested successfully at a cost-per-foot less than conventional rock bits. The most successful was a design incorporating a shallow cone profile with a short taper along with reinforced gage protection for motor application.
The TSP bits and motor were also utilized to drill out cement, float collars, and float shoes, thus generating additional savings. A total cost reduction of approximately $350,000 was realized through the use of TSP bits and downhole motors as compared to conventional rock bit drilling.
PDC Bit Development in the Kuparuk River Field, Alaska
Authors: Kappmeyer L. W. 
Published: December 2007

ABSTRACT
Polycrystalline Diamond Compact (PDC) bits have been under development and modification in the Kuparuk River Field since Kuparuk's first PDC run in September 1981. They are currently run in the soft to medium-hard clays and shales encountered between 3500′ and 7200′ MD. The first Kuparuk PDC bit was run at a cost of $59/ft. A typical PDC run for the same interval is currently $22/ft. This savings can be attributed to PDC bit development and other technological advancements.
This paper will document the evolution of the 8½″ PDC bit in the Kuparuk River Unit, including the results of a bit comparison test. This comparison involved six manufacturers and twelve Kuparuk River Unit wells with nearly identical conditions.
Permeability as a Function of Internal Surface of Cores
Authors: Greer F. Conrad , Beeson Carrol M. 
Published: December 2007

Abstract
The methods of Brunauer, Emmett and Teller are used to measure the internal surface area by isothermal nitrogen adsorption. The success of the surface area measurement is evaluated in terms of the criteria set up by these early experimenters. It is concluded that the methods used in the study are satisfactory for the measurement of the internal surface of the sandstone cores under observation.
A sufficient number of sandstone samples are tested to determine that there is a trend of permeability with porosity divided by the square of the surface area. The fact that the trend follows about a 45 degree angle on a log-log scale indicates that the exponents of the variables are approximately correct.

Introduction
The study of the surface properties of a substance is a relatively new concept in the field of chemico-physics, and the explanations for surface behavior are still in an unproved, conjectural stage. An understanding of many of the basic principles of surface chemistry, however, has been developed to the point where scientific applications can be made with considerable confidence. In the industrial field, dye adsorption and color removal, catalytic cracking of complex hydrocarbons, and other organic segregational processes are all phenomena of surface properties. The mechanics of fluid flow often involve the surface effects of conducting media, because resistance to flow is largely dependent on surface area. A particular branch of surface chemistry [or surface physics] which is especially pertinent is the adsorption of gases on solids. This paper is particularly concerned with that branch, and the following discussion deals with the adsorption of gases on solids for the purpose of measuring surface area.
Nitrided 410 Stainless Steel Valve Internals: Where They Are Acceptable for Use in the Oil Patch
Authors: Hartmann M. P. , Bednarowicz T. A. 
Published: December 2007

ABSTRACT
The performance of nitrided 410 stainless steel for oil patch corrosive service applications has been found to be dependent on the type of nitriding process employed and a function of test environment. In general, the nitriding of the 410 produces a metallurgical structure that is more susceptible than 410 to corrosive degradation.
Slant Drilling in the Morecambe Field, Irish Sea, U.K.
Authors: White S. M. , Barile M. F. 
Published: December 2007

Abstract
The Morecambe Gas Field was discovered by Hydrocarbons Great Britain Limited (HGB) following the re-evaluation of logs from two wells drilled in 1969 by a company who subsequently relinquished the acreage. The first well to test gas was drilled by HGB in 1974 and proved the presence of a major gas field in the Irish Sea.
The field consists of two reservoirs separated by a major fault running East/West. The development has been split into two phases with the first phase concerning only South Morecambe – (figure 1). This paper concerns the drilling operations conducted during Stage I, the development of the south eastern portion of South Morecambe.
South Morecambe is a shallow reservoir with minimum depth 2300 ft. and a gas column down to the Gas Water Contact at 3750 ft. This results in exposed reservoir intervals of in excess of 2000 ft. in deviated wells.
A Real-Time Normalized Rate of Penetration Aids in Lithology and Pore Pressure Prediction
Authors: Provost C. E. 
Published: December 2007

ABSTRACT
Mobil plots normalized rates of penetration in real-time using its Drilling Data Center. Field results indicate that this technique reveals changes in lithology and pore pressure. It illustrates one way that the Drilling Data Center integrates computer based drilling technology into field operations.
This technique differs from those previously reported in that: (1) A departmental computer collects, calculates, and displays real-time drilling information; (2) Normalized rate of penetration is correlated with conductivity for pore pressure prediction.
Prudent use of this tool directly reduces cost per foot. Confidence that pore pressure changes will be quickly noticed encourges the operator to drill near-balance, which yields faster rates of penetration. This tool also provides the geologist with an excellent correlation tool when wireline logs are not run.
This paper: (1) reviews normalized rate of penetration theory and its application with field results; (2) illustrates how the plot is obtained; (3) discusses predictions of lithology and pore pressure; and (4) discusses development plans.
Experience with CO2-Laden Fracturing Fluid for Stimulating Water-Sensitive Formations
Authors: Deysarkar A. K. , Dawson J. C. , Acharya A. R. 
Published: December 2007

ABSTRACT
Over the last two decades, liquid CO2 has been conmonly used in well stimulation, work over operations and enhanced oil recovery. There are several advantages for using CO2 in the recovery of hydrocarbons including: (i) minimizing damage of highly water sensitive, clay bearing formations, (ii) helping to clean up the well without swabbing, and thus, resulting in better recovery of fracturing fluids along with fines and silts lost during drilling and, (iii) providing a long sustained solution-gas drive due to high solubility of CO2 with reservoir fluids.
This paper will describe the properties of a unique cross-linked fracturing fluid containing up to 50% vol CO2 at surface conditions, up to 38% vol methanol – another component which minimizes damage to. water sensitive formations, and 12% vol water. The laboratory studies include rheological measurements of the CO2 laden fluids in a high pressure/high temperature rheometer and the measurement of fluid-loss coefficients. Data are also presented correlating the rheological behavior of the fluid to the CO2 concentration, the temperature of fluid, and to various mixing techniques of the fluid prior to measuring the rheological properties.
The other part of this paper will be devoted to actual case histories using the CO2 laden fracturing fluid. Several treatments were performed on both shallow gas wells in Canada and in deeper, hotter gas wells in south Texas. Production results indicate that the treatments have been successful. The fluid is designed to treat either low pressure formations or water sensitive formations with temperatures up to 280°F (138°C) and based on the case histories, it is concluded that this CO2 laden cross-linked fluid can be successfully pumped with up to 50% vol CO2 and contain a maximum sand concentration of 7.5 lb/gal (900 kg/m3).
Effects of a Cushioning Device on Dynamic Forces Exerted on Conventional Sucker Rod Pumping Systems
Authors: Tsuru F. D. 
Published: December 2007

ABSTRACT
A cushioning device composed of a series of synthetic elastomeric compounds will eliminate the metal to metal contact that exists between the pump and the surface pumping equipment. The installation of this cushioning device acts as a buffer in the rod string that suppresses the detrimental dynamic effects regularly experienced in a conventional rod pumping system.
Chemical Control of Biogenic H2S in Producing Formations
Authors: Littmann E. S. , McLean T. L. 
Published: December 2007

ABSTRACT
Waterflooding has presented many unique problems to oil producers since the practice was developed. One problem in many waterfloods has been that of increasing levels of hydrogen sulfide in produced fluids, where either none or only small amounts existed prior to waterflooding. The biogenic production of H2S is certainly a cause of this problem in many of these reservoirs. The problems associated with sour production are well known: corrosion, excess solids, emulsion and surface equipment problems, and the necessity to remove H2S from gas prior to sale.
Attempts to solve the problem at the source, i.e., bacteria in the reservoir, have usually failed. Conventional biocides that are effective when applied at the surface have various limitations and compromises when injected into a reservoir. A new biocide was introduced to the oil field in 1983 that was unique and had none of the limitations and compromises of conventional biocides. The new biocide possessed the necessary chemical properties to allow it to easily pass through a reservoir with the injected water. Case histories are provided that show the effectiveness of the new biocide in reducing biogenic H2S problems by treatment in the reservoir.
The Simultaneous Determination of Formation Compressibility and Gas-in-Place in Abnormally Pressured Reservoirs
Authors: Poston S. W. , Chen H. Y. 
Published: December 2007

SUMMARY
Geopressured gas reservoirs are commonly found along the Gulf Coast of the United States. The results of material balance, reserves calculations from these reservoir types is predicated on the accuracy of a single-valued formation compressibility function. This term in most cases is very difficult if not impossible to measure. A little used technique has been found in the literature which simultaneously determines the gas in place and formation compressibility.
Formation compressibility calculations during the analysis of available case histories disclose the presence of a low value at and near initial conditions and an increase to a constant and greater value at high to moderate pressure gradients. A final low compressibility value after a normal pressure gradient is again attained.
These variable compressibility phenomena may be readily explained by applying known geological concepts concerning the formation of geopressured oil and gas reservoirs.
Test and Evaluation Methodology for Scale Inhibitor Evaluations
Authors: Vetter O. J. , Kandarpa V. , Schaige A. L. , Stratton M. , Veith E. 
Published: December 2007

ABSTRACT
This paper deals with an evaluation of scale inhibitor test methods used in the oil, gas and geothermal industries. To our knowledge there exists no other publication dealing with this subject of evaluating and analyzing the various test methods related to scale inhibitor evaluations.
There are basically two different types of inhibitor test methods:
Test methods aimed at solving a scale problem for routine, day-to-day field operations. Test methods aimed at solving a scale problem for temporary or intermittent field operations.
Only the first type of test methods is described in this paper.
Laboratory test procedures are used to evaluate and to rank scale inhibitors for field operations. Many of the tests use arbitrarily selected test conditions and many are based on unvarying test conditions. Others evaluate only the inhibitor efficiency without regarding other and simultaneously occuring problems that may dictate the application and usefulness of scale inhibitors in the field. Slight changes in test conditions will usually result in significant changes in the subsequent rankings of scale inhibitors. Each "standard" test may yield inhibitor data and rankings that are completely different from the data and rankings based on other "standard" tests.
Any test procedure aimed at selecting an inhibitor for actual field use must consider actually encountered field conditions. Any test matrix should, as a minimum, include all the possible thermodynamic and at least some kinetic and hydro-dynamic conditions encountered by the inhibitor in an actual field.
The present paper discusses the advantages and disadvantages of the various scale inhibitor evaluation methodologies suited for the field operator. The relevancy of various evaluation methods for field applications is described. The paper is not oriented toward data obtained through previously or newly conducted inhibitor evaluations or evaluating of specific chemicals. The object is to evaluate and compare known or newly tried inhibitor test methods for field applications.
A Mathematical Model for Analysing Drilling Performance and Estimating Well Times
Authors: Thorogood J. L. 
Published: December 2007

Summary
Drilling progress rates for individual sections of hole were obtained from the depth-time curves of a number of deviated wells in the North Sea. Within each field there was seen to be a good correlation between drilling progress rate and the average inclination for the section. This observation forms the basis of a mathematical model for estimating drilling times of deviated wells. The method requires that a standard design can be specified for all wells in a field. Casing points are defined with respect to the Geology and the drilling programme is set up as a sequence of unit operations, casing jobs and drilling intervals. The model can be calibrated from wells already drilled to provide a yardstick against which future performance can be judged. Alternatively it can be initialised with the performance of exploration wells and then be used to estimate the drilling times for a field development. The model has been used routinely for three years and has proved to be a cheap but powerful tool. Furthermore, it has provided insights into the potential for computer applications in drilling operations performance analysis and simulation.
Single Cutter Testing – A Key for Pdc Bit Development
Authors: Zijsling D. H. 
Published: December 2007

Abstract
A description is given of a single-cutter tester for studying the cutting process of PDCs in rock under simulated downhole conditions. The use of the tester is illustrated by a study of the effect of downhole pressures on the cutting process in shales. Prior to the tests the Pierre shale and Mancos shale outcrop samples used for the study were conditioned to enable proper downhole pressures to be simulated during the tests.
The total bottomhole pressure only was found to govern the cutting process in Mancos shale, whereas both the pore pressure and the total bottomhole pressure govern the cutting process in Pierre shale. The dilatancy characteristics of the rocks are shown to be responsible for this behaviour. In addition the tests unveiled the balling mechanism of the outcrop shales in water-based and oil-based mud environments.
On the basis of the insight gained from single-cutter tests, the paper discusses drilling characteristics of PDC bits in shales and bit and cutter design aspects that facilitate mechanical bit cleaning as a means of improving PDC bit performance in various shales.