bluuebunny/crossref_metadata_2025_split huggingface dataset:
Field Tests of a New 2 MHz Resistivituy Tool for Formation-Evaluation While Drilling
Authors: Heysse Dale R. , Jackson Charles E. , Merchant G. A. , Jerabek Alois , Beste Randy , Mumby Edward 
Published: December 2007

Abstract
A new 2 MHz resistivity tool for logging-while-drilling (LWD) in slim holes has been developed and field-tested. The Slim Compensated Wave Resistivity* (SCWR*) provides four formation-evaluation resistivity measurements in all mud types and in boreholes as small as 5-7/8 inches. Dual transmitter-receiver spacings measuring both phase and attenuation produce four resistivities, sufficient to determine formation resistivity and evaluate invasion. Since many slim holes are drilled in lower-porosity reservoirs, where pay-zone resistivities are often higher than 20 ohm-m, the SCWR tool was designed to provide improved measurement accuracy at these higher resistivities. Similarly, slim holes tend to be hotter than larger boreholes, and the symmetrical design of the SCWR antenna array provides excellent temperature stability. Finally, slim holes are often associated with medium-radius drilling, so the SCWR tool was designed to operate reliably in wells with bends as great as 19°/100ft (rotating) or 36°/100ft (sliding).
Field tests have been conducted in a wide range of formation types and drilling conditions. These tests have been used to refine the mechanical design and antenna array, and have confirmed both measurement quality and reliability. This paper describes the features and capabilities of the SCWR tool, and presents several log examples from the field tests.
The Use of NMR Core Analysis in the Interpretation of Downhole NMR Logs
Authors: Brancolini A. , Gossenberg P. , Lyne A. , Mackenzie I. S. , Radaelli F. 
Published: December 2007

Abstract
Laboratory NMR measurements on core are particularly important for understanding NMR downhole logs from formations which have no NMR logging history. We have used low frequency (2MHz) NMR relaxation measurements on core plugs from a gas well in Southern Italy both to acquire petrophysical data and to clarify the interpretation of the downhole log.
In the cored interval the lithology is divided into thin sand and shale beds (&lt;lm). Measurements on the core have provided the basis for extracting maximum useful information from the NMR downhole measurements which do not resolve the thin beds.
As part of a more general programme we have investigated the potential of NMR measurements on saturated core, from two wells in the field, as indirect predictors of other parameters of petrophysical interest such as irreducible water saturation and permeability.
Lithology-lndependent Gas Detection by Gradient-NMR Logging
Authors: Prammer M. G. , Mardon D. , Coates G. R. , Miller M. N. 
Published: December 2007

Abstract
It has been shown that the Magnetic Resonance Imaging Log (MRIL®) can detect hydrocarbon gases present in the near wellbore zone (approximately 10 cm from the borehole wall). By exploiting the T1- and diffusion-weighting capabilities of this tool, mineralogy-independent water and hydrocarbon saturations can be determined in this zone. Gas and oil saturations are used to correct the reduction in apparent NMR porosity, an effect due to reductions in hydrogen index and incomplete recovery of magnetization polarization.
The proposed method exploits the predictability of density, hydrogen index, T1 and diffusivity of the non-wetting phase from its bulk properties. Gas is always and oil is often non-wetting. The MRIL®/C’s multi-frequency capabilities are used to integrate changes in recovery time and/or echo spacing into a single logging pass. The resultant data streams are processed in the complex time-domain to extract signal components characteristic for hydrocarbons.
A Field Application of Multiple-Well Testing for Reservoir Characterization
Authors: Hallford Debora L. , Hegeman Peter S. 
Published: December 2007

Abstract
A multiple-well test was conducted in Oklahoma which enabled the identification of two separate reservoirs in a new field. Quantitative analysis of the test, including determination of well-to-well permeability and distances to reservoir boundaries, was done using an analytical multi-well reservoir simulator. The test results were used to help determine whether additional wells were needed to optimize primary recovery for the field.
High Resolution From a New Laterolog With Azimuthal Imaging
Authors: Smits J. W. , Benimeli D. , Dubourg I. , Faivre O. , Hoyle D. , Tourillon V. , Trouiller J-C. , Anderson B. I. 
Published: December 2007

ABSTRACT
A new resistivity logging tool is described that improves the efficiency of drilling and logging operations by halving the length of traditional Dual Laterolog arrays to 16 ft. The reduced length and weight of the monolithic sonde lead to faster rig-up and can save several meters of rat-hole.
The array, based on the configuration of a Dual Laterolog and complemented by an azimuthal electrode array in the center, was designed for high vertical resolution and optimized for invasion response and borehole effect. The tool’s operation is based on a number of independent and simultaneous measurement modes that are combined by software to yield a series of resistivity measurements with different depths of investigation and resolutions.
The standard deep and shallow laterolog curves are output with improved resolution, but the flexible computed focusing also allows the substitution of different focusing conditions, which simultaneously yield deep and shallow resistivity curves with still higher resolutions of around 8 in. The passive azimuthal array at the center of the tool provides resistivity imaging of the formation in deep and shallow mode and an auxiliary ultra-shallow measurement sensitive to the radial distance from the borehole wall. An additional in-situ determination of the mud resistivity permits accurate realtime borehole corrections to be made.
Examples from recent field tests show the invasion and thin-bed response of the tool together with applications of the resistivity images.
Estimation of Producible and Remaining Oil Using High Frequency Dielectric Log in Carbonate Reservoirs
Authors: Chang D. , Myers M. T. 
Published: December 2007

Abstract
Producible and remaining oil volumes are essential for reservoir characterization and management We have used the EPT* (Electromagnetic Propagation Tool) to determine them. A dielectric dispersion model for carbonates based on laboratory measurements is introduced. The differences between this model which depends on pore geometry and previously published models are then demonstrated. EPT data is shown to be consistent with the pore geometry dependent dispersion implied by the model. Field applications of EPT logging to estimate remaining and producible oil saturations are shown for several West Texas carbonate reservoirs.
Correcting Measured Mechanical Properties for Size and Time Scale
Authors: Schatz J. F. , Truman R. B. , Schraufnagel R. A. 
Published: December 2007

Abstract
A model to correct for the size and time (frequency) scale variations of measured mechanical properties is presented. We show by comparing field data and laboratory data that large effects can occur. It follows that large errors can result from not making corrections to small size and/or high frequency measured values before using them in applications. The proposed model uses mathematically well-defined effective discontinuity distributions in the rock and a relatively small, measurable parameter set. The model does not use purely empirical correlatinns and therefore may be portable and accurate over larger extrapolation ranges. Log and core measurements for velocities and moduli should be adjusted before using them in applications such as in-situ stress estimation, hydraulic fracture design, wellbore stability or formation integrity calculations, and large-scale long-term formation deformation predictions.
In-Situ Residual Oil Saturation to Gas from Time-Lapse Borehole Gravity
Authors: Alixant Jean-Louis , Gabon Shell , Mann Ethan 
Published: December 2007

Summary
Three time-lapse borehole gravity surveys were performed one year apart in the dedicated data gathering and monitoring well of the Rabi oil-rim. For the first time, time-lapse density logs derived from Borehole Gravity Meter (BHGM) runs are used to estimate residual oil saturation in-situ. This is also the first time that the BHGM is used to determine interval density at one meter spacing. This paper reviews the planning of the BHGM surveys, explains why it became necessary to reduce the survey intervals to one meter, highlights the enhancements that made such measurements possible, and presents the first residual oil saturation results.
BHGM density is derived from the gravity gradient measured between two survey depths. The accuracy of the BHGM density is therefore governed by the accuracy of both gravity and depth measurements. The uncertainty of the gravity difference between two survey depths was significantly reduced through sensor improvements and new processing techniques. Depth-related errors were practically eliminated using a "Shuttle Sonde" to accurately position the gravity sensor within intervals up to 2.5 m.
The time-lapse technique is immune to structural effects which can bias single BHGM surveys. In addition, the BHGM is latched into grooves built into the glass-reinforced Plexiglas (GRP) casing to ensure that the stationary tool is positioned exactly at the same depths from year to year.
The reproducibility of BHGM density measurements between different runs is ±0.015 g/cm3 (one-σ, i.e. one standard deviation confidence level) over one meter intervals. This level of accuracy had only been achieved over three meter intervals prior to the present survey, thereby suggesting a threefold increase in the vertical resolution of the BHGM density measurement. As a result, a first estimate of residual oil saturation to gas was determined from BHGM data after only two years to within ± 10 su (one-σ) on a one-meter survey interval. The remaining oil saturation to water estimate derived from time-lapse BHGM surveys is in close agreement with residual oil saturation to water interpreted from time-lapse PNC logs.
Multi-Step Geostatistical Modelling of a Complex Reservoir Based on Quantified Sedimentary Models and Characterization of Core Petrophysical Groups
Authors: Petit F. M. , Caline B. , Greder H. N. , Pellerin F. M. , Calatayud P. M. 
Published: December 2007

Abstract
This paper outlines a multi-step geostatistical methodology for constructing reservoir models using sedimentary data and the notion of Petrophysical Groups.
This method is illustrated through a case study of a mixed carbonate platform oil reservoir (a 20-meter thick sequence). Indeed the technique appears to be particularly suited for reservoirs with great variability of petrophysical properties characterized by a due to the combination of sedimentary and diagenetic effects.
The first stage is the construction of the sedimentary model, with a particular emphasis on the shapes, extents and vertical and areal development of sedimentary bodies.
The second stage consists in constructing Petrophysical Groups from core measurements through statistical clustering techniques. Each Petrophysical Group is a set of reservoir zones having similar porosity, permeability, grain density and capillary pressure curves. Water saturations and relative permeability functions can be assigned to Petrophysical Groups with good confidence.
In the third stage sedimentological and petrophysical data are reconciled in order to map reservoir properties. It appears that the organization of Petrophysical Groups within sedimentary bodies can be explained by depositional and post-depositional factors that may be assessed using well data and regional information. These relationships, once quantified, allow us to build the model of reservoir properties in three steps involving an object-modelling technique, the Sequential Indicator Simulation and Sequential Gaussian Simulation, respectively.
In this complex reservoir the method proves to be a powerful alternative to conventional approaches to the modelling of petrophysical heterogeneities which use lithofacies as a basis for the mapping of reservoir properties.
A Dynamic Simulator to Analyse and Remedy Gas Lift Problems
Authors: ter Avest D. , Oudeman P. 
Published: December 2007

Abstract
Gas lift efficiency is substantially affected by unstable behaviour of wells. Unstable production, or heading, results in prolonged periods of reduced or even vanishing production and therefore leads to significant oil deferment. Since heading can be caused by a large variety of factors, such as incorrect gas lift string design, improper valve setting, or valve leaking or plugging, it is often difficult to find the origin of the heading. To aid in the diagnosis of gas lift problems, a dynamic gas lift simulator was developed. The simulator computes the transient flow of gas and liquid through the production tubing. Valve models are used to calculate the passage of gas or workover fluid through the valves as a function of pressures local to the valves. The simulator is used to study poor lift gas performance, quantify the effect of remedial measures and optimise unloading procedures. Examples are given of field cases that were studied with the simulator.
Particulate Problem Solutions for Rod Pumped Producing Wells
Authors: Williams B. J. 
Published: December 2007

Abstract
Sand and other fluid entrained particulates can cause substantial operational problems for rod pumped producing wells. These problems take the form of down-hole pump wear, plunger sticking, and/or catastrophic breakage of pump components.
A six year study of 600+ pump investigations shows that problems with particulates account for a substantial number of the total barrel and plunger failures. Many of these failures could have been avoided through the proper application of API and special pump designs as well as certain choices of pump variables. These pump variables and designs will be addressed along with operating parameters.
How hard is sand? How large is it? Should plunger and barrel choices take these variables into account? Also, metal plungers must "slip" fluid for proper lubrication. Too much slippage leads to pump inefficiencies. However, down-hole pump efficiencies based on slippage need to be balanced against pump longevity due to proper selection for particulate production. Some time-proven roles of thumb can be applied to make these choices, and an included chart will make plunger slippage calculations simple and straightforward.
Scale which sticks to pump surfaces dictates the choice of a different style down-hole pump. A straightforward modification of an RH style API pump has proved successful in these conditions.
Fluid and particulate production with and without attendant gas production requires a different approach to down-hole pump selection. Several successful older pump designs as well as some recently proven new designs will be described.
A test program has been completed and actual applications have shown that an API Tubing Pump derivative can pump large volumes of particulate laden fluid without characteristic sticking of the plunger.
Experience from Topside and Subsea Use of the Erosion Based Sand Monitoring System
Authors: Braaten Nils A. , Blakset Terje J. , Morton Derek 
Published: December 2007

Abstract
This paper describes the use of an erosion based on-line sand monitoring system, both for topside and subsea applications. It shows the practical use of the system, both from a safety point of view, with the probe giving early warning of sand production/erosion, in addition to being a tool for optimizing the production from the oil/gas wells. The probe works equally well in all flow regimes, single or multiphase flow.
Forecasting Petroleum Drilling Outcomes for Firms of Different Sizes Operating in the Gulf of Mexico OCS Region
Authors: Declare Omowumi O. , Pulsipher Allan G. 
Published: December 2007

Abstract
The purpose of this paper is to forecast petroleum drilling activity and outcomes for firms of different sizes using a model of hydrocarbon reserve additions developed for the Gulf of Mexico OCS region. Our empirical results provide evidence of statistically significant diminishing returns on drilling effectiveness with the growing maturity of the OCS region, but are inconclusive, statistically, as to whether technological change boosts drilling effectiveness differently among firms of different sizes. The response of drilling to economic incentives is inelastic among the independents but nearly unitary-elastic for the majors. Overall, there is no persuasive evidence to suggest a less aggressive drilling pace or less efficient hydrocarbon resource development on the Gulf OCS because of an increasing role of independents in the region.
Asphaltene and Other Heavy-Organic Particle Deposition During Transfer and Production Operations
Authors: Escobedo Joel , Mansoori G. Ali 
Published: December 2007

ABSTRACT
The production and transportation of petroleum fluids could be severely affected by deposition of suspended particles (i.e. asphaltene, paraffin/wax, sand, and/or diamondoid) in the production wells and/or transfer pipelines. In many instances the amount of precipitation is rather large causing complete plugging of these conduits. Therefore, it is important to understand the behavior of suspended particles during flow conditions.
In this paper we present an overview of the heavy organic deposition problem, its causes, effects and preventive techniques. We also present an analysis of the diffusional effects on the rate of solid particle deposition during turbulent flow conditions (crude oil production generally falls within this regime). We utilize the turbulent boundary layer theory and the concepts of mass transfer to explain the particle deposition rates on the walls of the flowing conduits. The developed model accounts for the Brownian and eddy diffusivities as well as for inertial effects and other forces acting acting upon the particles.
The analysis presented in this paper shows that rates of particle deposition (asphaltene, paraffin/wax, sand, and/or diamondoid) on the walls of the flowing channel, due solely to diffusional effects, are negligible. It is also shown that deposition rates decrease with with increasing particle size. However, when the deposition process is momentum controlled (large particles) higher deposition rates are predicted. It is shown a decrease in deposition rates with increasing crude oil kinematic viscosity. An increase in deposition rates with increasing production rates is also observed.
The Design and Testing of Subsea Production Equipment: Current Practice and Potential for the Future
Authors: Cort A. J. C. , Ford J. T. 
Published: December 2007

Abstract
This paper presents an analysis of the current approach to the design and testing of equipment used in subsea developments. The paper critically assesses the current equipment specification, design, manufacture and testing process. An essential part of the analysis is a review of the standards used by the industry and statutory regulations which impact on this process.
It raises significant questions about the efficacy of the design and testing procedures and the role of the regulating bodies in that process. It discusses the impact of poor specification and design procedures, and inadequate testing, of the safety and reliability of the equipment. As a consequence of the analysis it is suggested that the manner in which equipment is specified, designed and tested may need to be changed in order to meet future needs.
The above issues are focused, by considering the production of a subsea wellhead, from specification by the operator to delivery by the manufacturer.
Incident Investigations - A Total Quality Management (TQM) Method
Authors: Fitts Travis G. 
Published: December 2007

Abstract
The typical incident investigation does not produce optimal results. Investigations have historically created barriers for safety improvement and exposed companies to unnecessary financial liability. The objective of this poster session is to introduce a process that will: Improve the reliability of reporting, tracking, and statistical analysis.Increase the effectiveness of corrective actions.Strengthen an organization’s ability to defend itself should litigation arise.
Remediation of Normally Occurring Radioactive Material (N.O.R.M.): A Field Trial
Authors: Orum J. D. , Baudoin D. , Briscoe O. 
Published: December 2007

Abstract
This paper describes a case history where 200 barrels of NORM contaminated sands and sludges were remediated to below regulatory limits and subsequently disposed as Non-hazardous Oilfield Waste (NOW.). The material treated initially registered as high as 180 pCi/gram of Radium 226. Upon completion of the remediation process, all materials were reduced to below 30 pCi/gram with some samples registering as low as 3 pCi/gram (background). The lower levels of radiation registered were a direct result of treating time. As a result of this process, no by-products were generated which fall under NORM regulated levels. The resulting data from this remediation of NORM waste were scrutinized by applicable regulatory agencies and found to be an acceptable method of remediation.
Oil and Grease Discharge Regulations in the United States and Equipment Capabilities
Authors: Otto G. H. , Arnold K. E. 
Published: December 2007

Abstract
This paper traces the history of Gulf of Mexico statistical studies of oil and grease removal capability for produced water treating system from the 1974 Brown and Root study through the 1993 survey of 292 platforms. The changing EPA policy of regulation based upon process capability to one of selective analysis and policy driven regulations is explained. Over 3,000 observations from the 1993 study were used to analyze the ability of existing systems to meet the 42/29 mg/1 discharge limits promulgated in 1994. In addition, the data was reviewed to see if conclusions could be reached on actual field performance of the full range of water treating equipment and system configurations including skimmers, hydraulic flotation units, mechanical flotation units, hydrocyclones and filters.
Successful History Matching of Chaunoy Field Reservoir Behavior Using Geostatistical Modeling
Authors: Lemouzy P. M. , Parpant J. , Eschard R. , Bacchiana C. , Morelon I. , Smart B. 
Published: December 2007

Abstract
An integrated study combining sedimentological and sequence stratigraphy analysis, geostatistical simulations and validation by production history simulation has been performed in the Chaunoy field reservoir. The reservoir is a part of a distal alluvial fan system, in the Keuper series of the Paris Basin (France). RFT surveys suggest a layered behavior. Nevertheless, the low extension of reservoir bodies (small ribbon channels interbedded with flood-plain and lacustrine mudstones) made it difficult to set ut a satisfactory correlation scheme in the past studies, resulting in difficulties in matching the production history.
Core and log analysis yielded the conceptual geological model. Geostatistical analysis enabled to its validation and quantification. Inside each genetic unit, repartition of lithotypes and of petrophysical properties were modelled by geostatistical simulations. As the horizontal variogram ranges proved to be below the average well spacing, three high resolution models were built, with different horizontal variogram ranges, all smaller than well-spacing (1/8, 1/2 or 1 times the well spacing). After scaling-up of the resulting petrophysical models, simulations of the ten-year production history were performed in each model. By comparing the simulated production data with the field production history, the characterization study was validated. A satisfactory match was obtained on the main zone of the reservoir, validating the correlation scheme and explaining the observed layered behavior.