bluuebunny/crossref_metadata_2025_split huggingface dataset:
Analysis of Observed Friction Pressures Recorded While Fracturing in Highly Deviated Wellbores
Authors: Bilden D. M. , Spearman J. W. , Hudson H. G. 
Published: December 2007

ABSTRACT
In deviated wellbores, the relationship between friction pressure and hydrostatic pressure differs from that in vertical wellbores. The change in this relationship increases the need for accurate slurry friction pressure modeling. Because of deviation, incremental slurry friction pressure changes are more significant than incremental changes in hydrostatic pressures. Real-time calculation of an accurate bottomhole treating pressure in deviated wellbores is more difficult to achieve, than in vertical wells, because of the lack of accurate slurry friction models.
"Abnormal" surface treating pressures, which are caused by this change in relationship, were recorded while fracturing deviated wells in the Prudhoe Bay Field in Alaska. The significance of this relationship is presented along with observed slurry friction pressure data obtained through the use of bottomhole pressure recorders. A methodology and mathematical model for more accurate calculation of slurry friction pressure is presented for these conditions.
Automatic Type-Curve Matching for Horizontal Wells
Authors: Thompson L. G. , Temeng K. O. 
Published: December 2007

Abstract
This paper considers the design of an algorithm for analyzing multirate horizontal well pressure transient data using nonlinear regression techniques. Measured data is modeled using the analytical solution for a uniform-flux horizontal well in a rectangular parallelepiped reservoir. Parameter optimization is achieved using the public-domain Levenberg-Marquardt algorithm, LMDER, from Argonne national Laboratory.
We focus on efficient methods for calculation of analytical partial derivatives of the model pressure response which are required by the optimization routine. Complete expressions for all required partial derivatives are provided in Appendices, along with details on a method of evaluating these derivatives which requires minimal computational effort. We demonstrate the utility of the method by analyzing field buildup pressure data.
Through-Tubing Perforating With Pivoting Shaped Charges
Authors: Lopez-de-Cardenas J. E. , Brooks J. E. , Jensen Max 
Published: December 2007

Abstract
A new through-tubing gun with pivoting shaped charges, capable of going through narrow tubing restrictions but with performance comparable to the largest guns, is presented. Calculated production results show improvements of 20 to 100 percent over conventional through-tubing guns and results similar to the larger guns. Field results show significant increases in well production.
A New Correlation Developed Between Archie's Parameters and Continuous Phase Change Saturation Interval
Authors: Unalmiser Servet , Bova J. A. 
Published: December 2007

ABSTRACT
The establishment of correlations between the continuous phase change saturation interval (ds) and Archie variables "m" and "n" allow for a cost effective and quick method of obtaining critical data used in the formation evaluation of oil reservoirs. This is significant since the direct electrical measurements conventionally used to obtain these variables is both time consuming and expensive. Conventional mercury injection tests can be utilized to predict electrical parameters based on the porosity/permeability ratio of the rock sample.
The measurement of electrical properties were performed with a true four pole configuration at five different frequencies ranging from 0.5 kHz to 10 kHz. Continuous Resistivity and Capacitance Measurements have been accomplished under simulated net overburden pressure. Following the measurement of the fully brine saturated sample, the desaturation was initiated through a semi-permeable membrane without removing the sample. The Rock/Fluid equilibrium at each capillary pressure was determined based on a continuous resistance measurement and corresponding volume of expelled brine. Completing the resistivity measurements, samples were extracted and mercury was injected from low vacuum, 20 microns of mercury pressure, up to 4500 psi. Following the first injection cycle, mercury was ejected down to atmospheric pressure and then second injection cycle performed up to 4500 psi. The transient saturation between mercury and mercury vapor, where continuous phase changes take place, has been succesfully correlated with the electrical parameters.
The correlation developed between continuous phase change saturation interval (ds), and Archie's parameters exhibit two opposite trends based on the permeability/porosity ratio of the samples: (1) Both cementation factor and saturation exponent, for the group of samples with (k/ø) less than one are directly proportional with the continuous phase change saturation interval. (2) The group of samples having (k/ø) more than one display an inverse proportion between (ds) and Archie's Parameters.
Measurement of Composition of Drilling Mud by X-Ray Fluorescence
Authors: Houwen O. H. , Gilmour Alan , Sanders M. W. , Anderson D. R. , Prouvost Laurent , White D. B. 
Published: December 2007

ABSTRACT
An evaluation is described of the concept of measuring solids in drilling fluids by X-Ray Fluorescence, which is illustrated for water base muds. The performance of the calibration model obtained was tested against a variety of fluid compositions.
The calibration was based on measurements of a learning set of muds in which barite content ranged up to 1550 kg/m3. Drilled solids were simulated by calcium carbonate in concentrations ranging up to 300 kg/m3. Potassium and sodium salts were present in concentrations of up to 200 kg/m3 KCl or 250 kg/m3 NaCl.
A standardized software package has been developed, which utilises some of the potential outputs from the XRF measurement. The algorithm implemented uses barium fluorescence and backscattering intensity together with fluid density to predict the concentration of barite and water. From these primary outputs, and the chloride content supplied from an external source, the concentration of Low Gravity Solids is also determined.
The accuracy of the predictions from the technique has been determined for muds in which compositions conformed to the bounds of the calibration fluids, and also for muds in which LGS were simulated by mixtures of kaolinite, illite, quartz and anhydrite, rather than by the calcium carbonate used in the calibration. It was found that the nature of the LGS has little or no influence on the predictions.
Effects of likely contaminants in water base muds were explored by adding realistic amounts of ferrochrome lignosulphonate, iron filings, pipe dope or oil. No significant influence on the predictions was found. No adverse effects from variation in particle size of LGS were observed in experiments in which sized fractions of ground illite were used, ranging from below 75 microns to larger than 4 mm.
To simulate a field situation, a base mud containing 3 vol.% LGS was contaminated with varying amounts of kaolinite, illite, quartz, anhydrite and dolomite, which in each case raised LGS content to 8 or 11 vol.%. No significant variation in results due to the different nature of these solids was seen. Analysis of the accuracy obtained in these experiments suggests that the resolution by which variations in LGS content can be detected is approximately 0.3 vol.% absolute. This contrasts favourably with the traditional mud retort technique, which is estimated to be some ten times less precise.
Increasing Drilling Instrumentation Demands: Integration and Ergonomic Studies
Authors: Knutson Michael , Weare Barry 
Published: December 2007

Abstract
Over the years, drillers worldwide have seen their duties and responsibilities escalate with increasing requirements for more sophisticated monitoring and control equipment. An abundance of these devices are flooding the driller's station. These demands are brought on by more stringent safety requirements and intense pressures of economically developing marginal oilfields.
The first attempts to cope with this influx of devices were to stack specific function consoles around the driller. This method is still used in some applications, creating an intensely cluttered and highly inefficient work area.
The solution to this problem is to combine the monitoring and control equipment into a custom-configured consolidated driller's console. Many considerations are undertaken in order to successfully design and manufacture an efficiently integrated console, which will become the driller's primary tool. Concerns of placing primary instrumentation in direct access to the driller, avoiding instrumentation duplication and maintaining sight of work area while monitoring instruments are considered. Another is logically grouping instruments for simplicity in use and proper interpretation. These concerns and many more have promoted the extensive ergonomic studies to develop today's strategic Driller's command console.
One highly efficient console design was accomplished through the collaboration of Shell UK with KCA Engineering and MartinDecker TOTCO.
Improving Marine Safety on Mobile Offshore Drilling Units
Authors: Vermersch J. A. , Day J. B. , Christman S. A. , Nolop N. C. 
Published: December 2007

Abstract
In 1982, Exxon initiated an enhanced worldwide marine safety program for mobile offshore drilling units (MODUs) operating for the corporation's affiliates. A task force was commissioned to survey, from a marine operations standpoint, selected MODUs to identify ways to maximize the effective use of existing marine safety equipment, practices, and training for emergencies including vessel abandonment. The effort resulted in specific goals to reduce the likelihood of serious mishaps and to improve the crew's chances of survival in the event rig abandonment were necessary. The goals were to (1) develop and implement a set of safety guidelines for MODUs operating for Exxon, (2) work to help upgrade industry standards and practices, (3) assess marine safety systems as part of the initial rig selection process, and (4) conduct effective, comprehensive structural inspections on selected rigs.
Marine safety guidelines were developed to address several main areas, including emergency response, rig abandonment, personnel qualifications, stability procedures, and fire protection. The guidelines have been used in over 90 marine safety surveys (assessments) to date. A comprehensive onboard safety school was developed emphasizing effective scenario emergency drills and offshore survival. Over 35 of these schools have been conducted in cooperation with the drilling contractors.
The content of the marine safety guidelines and the schools have been used in efforts to upgrade industry standards through the American Petroleum Institute (API), United Kingdom Offshore Operators Association (UKOOA), the Oil Industry International Exploration and Production Forum (E&P Forum), International Maritime Organization (IMO), and the U. S. Coast Guard (USCG).
Use of Time-Shared Computer Terminals for Quick Turn-Around Log Analysis
Authors: Shelby Bertram S. 
Published: December 2007

Abstract
Commercial Time Sharing Computer Services have been utilized by the headquarters staff of the author's company since November, 1967. The service has been by the General Electric Mark I and Mark II Information Processing Centers located in Dallas, Texas; Teaneck, New Jersey; and Cleveland, Ohio. Ready access to these computers by phone service through standard teletype terminals has allowed the continuous development of a fast and comprehensive group of programs for well log analysis. The ability to share the use of these programs with remote field office locations through common computer memory networks has allowed expanded application of these log analysis programs. The great flexibility and ease programs. The great flexibility and ease with which problem solutions can be programmed provides adaptability to programmed provides adaptability to unusual well log analysis problems and applications. Time shared computer programing has provided the remote user programing has provided the remote user with engineering analysis graphics with repeatable formatting, and has allowed, after the description of the program, non-technical and technical aids to accomplish well log analysis with unwavering reliability.
Time sharing computer analysis has decreased the time required to do detailed well log calculations and allowed the inclusion of additional reconnaissance parameters not normally calculated during parameters not normally calculated during quick-look manual calculations of logs. Time sharing has provided an excellent tool for the company log analysts to better and more quickly serve the needs of engineers and geologists.
LOG ANALYSIS BY COMPUTERS
The application of computers to the calculations of log analyses is not new to the oil industry. These analyses are commonly made at the site of the computing facility which is normally staffed by computer trained formation evaluation specialists.
Elimination of High Bit Noise Levels in the Kuparuk Field, Alaska
Authors: Fitzpatrick Ellen , Knowlton Helene , Green Randy 
Published: December 2007

Abstract
In the Kuparuk Field of Alaska a project was undertaken to drill the entire 8-1/2 in. hole interval with a single polycrystalline diamond compact (PDC) bit while achieving a substantial improvement in penetration rate and maintaining the directional control of the steerable turbine assembly. The baseline drillability of the formations ranged from instantaneous rates of 400 ft/hr in the soft shales to 30 ft/hr in the hard formation. Water-base mud was the drilling fluid used.
A very simple acoustic emissions monitoring technique was assembled to confirm that bit whirl was the mechanism causing premature bit failure. Surface measurements of acoustic emissions were correlated with downhole accelerometer, weight-on-bit and torque-on-bit data.
It was proved that the baseline bit was whirling. A new series of bits was designed to drill without the excessive vibrations caused by whirling and to complete the entire interval. Utilizing data from downhole sensors, directional drillers learned how to optimize drilling parameters. At the conclusion of a one-year test program, the average penetration rate of the 8-1/2 in. interval jumped from 135 ft/hr to 240 ft/hr. Drilling costs of the 8-1/2 in. section were cut in half.
Integrated Incentive Drilling Contracting: An Operator's View
Authors: Bartstra R. M. , Prifti P. J. , Fleck A. R. 
Published: December 2007

ABSTRACT
This paper describes the process by which one operating company within the Shell group constructed, tendered and negotiated a contract with a drilling contractor in line with the philosophy of Drilling in the Nineties. It highlights the shortcomings, achievements and qualifications that were encountered.
Field Tests of a Low-Cost Lateral Drilling Tool
Authors: Winters W. J. , Mount H. B. , DeNitto P. J. , Dykstra M. W. 
Published: December 2007

ABSTRACT
Field tests of a low-cost short radius lateral drilling system are described. The uniqueness of this system lies in its simplicity and the fact that it was used on workover rigs in West Texas to laterally recomplete 6 production and 2 injection wells for an average cost of $116,500 including plugback, drilling, and stimulation. The authors advocate using this type of tool to laterally recomplete the industry's large capital resource of existing wells. Unusual technical developments including a miniature electronic survey instrument, a simple mud-pulse directional orientation sensor, improvements to flexible drill pipe for short radius wells, and advances in logging and stimulating short radius wells are discussed.
Techniques for Successful Application of Dynamic Analysis in the Prevention of Field-Induced Vibration Damage in MWD Tools
Authors: Field D. J. , Swarbrick A. J. , Haduch G. A. 
Published: December 2007

Abstract
This paper describes a set of analysis techniques which have successfully reduced vibration damage to MWD tools and their associated down hole assemblies. Owing to the sensitive nature of MWD tools and the instruments which they contain, the use of such equipment demands that conditions which lead to severe and damaging vibrations be identified and avoided. With careful consideration of input parameters, judicious "post processing" of results, and continuous correlation with field data, the authors are able to demonstrate a method which fosters improved drillstring design decisions while mitigating vibration damage and associated failures.
The routine utilisation of this method provides three significant benefits. First, avoidance of potentially damaging operating conditions results in documented savings in time and cost. Secondly, the accumulated database of field cases provides historical information which results in improved design decisions and fewer problems on future wells. Finally, the database of field results defines a reference point for continual refinement and enhancement of the methodology. Field cases are presented which illuminate these benefits.
The dynamic analysis procedure used in this work identifies the critical speeds for a given down hole assembly by determining the three dimensional vibrational response due to a selected excitation. Although the analysis techniques described herein were developed specifically for this appli cation, these guidelines are generally applicable to other types of dynamic down hole assembly analysis.
Current Investment Practices and Procedures: Results of a Survey of U.S. Oil and Gas Producers and Petroleum Consultants
Authors: Dougherty E. L. , Sarkar Jayati 
Published: December 2007

Abstract
Based on a survey of investment practices of U.S. oil and gas companies, this paper assesses investment techniques in current use and the impact of environmental and tax regulations. Questionnaires sent to selected oil and gas companies, professional consultants, and bank engineers concentrated on seven major areas: capital availability, investment analysis techniques, cost of capital, risk analysis, impact of environmental regulations, valuation of property acquisitions and miscellaneous investment considerations. Replies were analyzed to obtain the distribution of responses for each question, and cross-correlations between size of capital budget and responses in the major areas.
In the areas of capital rationing, impact of environmental regulations and investment evaluation methods, significant differences in the responses across firm size or between firms and consultants are not apparent. Differences are apparent for determination of discount rates, causes of capital limitations, value of nominal discount rates and effect of AMT.
The average nominal aftertax discount rates reported by firms and consultants are 14% and 13%, respectively. A little over half of our responding firms report that AMT has had a negative impact on investment. Results are compared to those of a similar study [1], showing the trend in investment analysis and the broadening scope of concerns in picking good investments.
Risk Analysis as Applied to Drilling and Developing an Exploration Prospect
Authors: Cowan J.V. 
Published: December 2007

This paper was prepared for the 44th Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Denver, Colo., September, 28-October 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 publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor 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
Measuring the effects of uncertainties on the financial outcome of proposed hydrocarbon exploration ventures is a common necessity in the petroleum industry. To perform such measurements a risk analysis perform such measurements a risk analysis model has been constructed and computerized. Cumulative probability distributions of basic financial indices are developed by repeatedly solving the model using input variables sampled at random. Fundamental statistical measurements which further describe these distributions are also computed. The scope of the analysis begins with the exploration phase and ends w hen the producing rate reaches phase and ends w hen the producing rate reaches an economic limit. During each simulation of exploiting the prospect many checks are made to verify the economic feasibility of continuing capital expenditures. The model defines the probabilities of an acceptable monetary return while the financial outlay is still minimal.

Introduction
Significant amount of risk capital must be committed to initiate most hydrocarbon exploration plays. As reserve potentials dwindle, and costs increase, management must carefully pre-judge the economics of each possibly exploration venture. Also, they must possibly exploration venture. Also, they must somehow judge the odds of attaining the necessary economic incentive to justify these expenditures.
It is the nature of hydrocarbon exploration to be laden with uncertainties. These uncertainties present a series of fundamental questions which must be answered sequentially before risk capital is exposed:
Will geophysical/geological studies locate a prospective anomaly on openacreage? If so, will a wildcat well drilled into the prospect find hydrocarbons that can be produced at commercialrates? Given a successful wildcat, will the delineation of the find prove the reserves necessary to justify expenditures for production facilities and the development of the discovery?
An Alternative Approach to Modeling Uncertainty in Hydrocarbon Economic Analysis
Authors: Behrens A. M. , Choobineh F. F. 
Published: December 2007

ABSTRACT
Probability has been the traditional approach for representing uncertainty in hydrocarbon economic analyses. Probability, however, often cannot sufficiently represent the type of uncertainty commonly encountered in practice, since the prevalent uncertainty is frequently a result of the inherent vagueness of parameters values rather than randomness of the parameters.
An alternative approach to probability that provides a better representation of economic uncertainty is possibility distributions or fuzzy numbers. The theoretical requirements of possibility distributions are less stringent than those of probability, making them easier to apply in many economic analysis situations. This paper advocates the use of possibility distributions in oil and gas economic analysis.