bluuebunny/crossref_metadata_2025_split huggingface dataset:
Blast Furnace Slag Technology: Features, Limitations, and Practical Applications
Authors: Mueller D. T. , Dickerson J. P. 
Published: December 2007

Abstract
The use of blast furnace slag to convert drilling mud into a cementitious material has been the subject of much debate among cementing professionals. The conversion technology, recently introduced to the oil and gas industry, has been used in lieu of Portland cement in primary and remedial applications. The legitimacy of this technology has been challenged, however, by concerns over the mechanical integrity of the set product.
The purpose of this paper is to define the features and limitations of slag-converted drilling muds by investigating the physical and mechanical properties of the material. Alternative water-based designs using slag in lightweight and whipstock plug applications are also presented.
Test results indicate that the technical viability of slag-converted drilling mud designs are heavily influenced by factors such as the original density/dilute density/final density relationship and activator loadings. Proper consideration of these engineering elements is central to producing systems with predictable performance characteristics.
Additionally, the type and concentration of activator is shown to be the predominant factor influencing the brittleness and stress-cracking of slag-converted drilling muds.
The Kinetics of Hydrate Formation
Authors: Yousif M. H. 
Published: December 2007

Abstract
The kinetic and thermodynamic inhibition of gas hydrates occurs by disruption of the hydrogen bonding process that otherwise leads to clustering of water molecules as a solid lattice. Consequently, and in order to design better inhibitors for gas hydrates, it is of utmost importance to understand the mechanisms that lead to the formation of gas hydrates.
The interaction of the hydrate forming molecules with the water molecules at the onset of hydrate formation is re-examined in light of the results of NMR and X-ray diffraction data, and the statistical mechanics models. This re-examination shows that the large cages of structures I and II hydrates are almost always preferentially occupied regardless of the molecular size of the hydrate former. In other words, the large cages 512 62 and 512 64 of the hydrate structures, I and II, dominate the hydrate nucleation process.
Field Application of Static Tubing Pressure Data and On-Site Fracture Modeling
Authors: Cipolla C. L. , Meehan D. N. , Dunleavy J. R. , Stevens P. L. 
Published: December 2007

Abstract
This paper details the application of static tubing pressure measurements and on-site fracture modeling on over 70 wells in the Moxa Arch and Wamsutter areas in the Green River Basin, Wyoming. Specific examples illustrating the field procedures that evolved during a 2-year development program are presented, including on-site analysis of mini-fracture treatments, pad optimization, and treatment evaluation. Field applications include foamed and water based fluids in low and moderate permeability Frontier and Mesaverde gas sands. Bottom-hole pressure (BHP) measurements in all 70-plus treatments were obtained using a static tubing string, eliminating the inaccuracy of surface estimated BHP. Field data illustrate large variations in friction pressures that occur during many treatments which may lead to erroneous interpretations and premature job termination.
The quality of the data coupled with on-site three dimensional (3D) fracture modeling allowed field engineers to evaluate minifrac data and optimize pad volumes within 30 minutes. On-site modeling of the mini-frac data eliminated the need to measure fracture closure time which requires long shut-ins for many tight gas formations. This procedure includes the mini-frac volume in the pad volume, decreasing mini-frac costs and job delays.
Designing Oil and Gas Facilities for Russia
Authors: Kulish K. M. 
Published: December 2007

Abstract
This paper will describe Paragon Engineering Services’ past and current work in designing oil and gas facilities for Western joint ventures located in northwestern Russia in the Timan-Pechora basin. Also, this paper will further describe our current joint venture with a local Russian design institute, a comparison of Russian and Western design philosophies, and our observations and conclusions about work in Russia. The civil and mechanical designs have been influenced by the arctic environment, sourcing of materials and equipment, local environmental regulations, geotechnical considerations, and logistics. The civil design discussion centers on issues dealing with pile supported foundations, roads, and pads, performed in permafrost regions. The project’s civil design had to meet the goals of maintaining the thermal stability of the permafrost, minimizing physical damage to the tundra, and supporting equipment. The mechanical design discussion focuses on freeze protection, module sizing and configuration, and operating and maintenance practices for a development north of the Arctic Circle. Due to the high pour point of the crude oil, the mechanical design had to address the problem of a
flow stoppage at low ambient temperatures, along with the usual freezing problems due to the arctic climate. The basis for selecting the size and configuration of equipment modules was based on sourcing materials and equipment in the U.S., the logistics of transportation, and operations and maintenance. Paragon began performing joint work with a local Russian design institute located in the Komi Republic while working on a recent project. Paragon became familiar with the institute’s capabilities and gained greater understanding of the similarities and the differences between Russian and Western engineering firms. From past and ongoing work, we believe that to have a successful facilities project you must study the local logistics, consider environmental issues, gather geotechnical data, develop a plan of supply for equipment and materials, and involve a local Russian design institute as early as possible.
Control of Hydrate Formation by Surfactants and Polymers
Authors: Kelland M. A. , Svartaas T. M. , Dybvik L. A. 
Published: December 2007

Abstract
This paper describes new classes of chemical inhibitors that delay or interfere with the hydrate formation process that could be used to cost-effectively maintain produced gas/oil/water systems in readily transportable form. Our approach has been to look at the problem of hydrate formation on a molecular scale, and determine classes of so-called "kinetic inhibitors" that can act at much lower concentrations than anti-freezes.
Using experiments conducted in high pressure sapphire cells we have determined various classes of chemicals that affect the hydrate formation process. In particular, one class delays the growth of hydrate crystals for substantial periods but after a certain gas uptake this eventually leads to hydrate plugging. A second class of inhibitor prevents agglomeration of hydrate crystals so that a transportable slurry is maintained. A third class can incorporate both these inhibition properties to a limited extent.
A Simple Model for the Efficiency of Rotary Separators
Authors: Alhanati F. J. S. , Sambangi S. R. , Doty D. R. , Schmidt Z. 
Published: December 2007

Abstract
This paper presents, for the first time, a theoretical model for the bottomhole gas separation efficiency in Electrical Submersible Pump Installations. The model is based only on fundamental physical principles. New experimental data, collected in a field scale apparatus, and covering a wide range of liquid flow rates, GLRs, pressures and rotational speeds, are also presented. Predictions of the model are verified against the experimental data and limited published field data.
It was detected that, when rotary separators are used, two possible operating regions exist on a map of separation efficiency versus liquid flow rate and pressure. In one region the separator is quite effective and in the other the separator is not effective at all. The transition from the high efficiency zone to the low efficiency zone, in terms of liquid flow rate, is sharp. This behavior has never been reported in the literature before.
The model is simple enough that a small subroutine can be easily written, from the equations presented in the paper, to be included in design and troubleshooting programs for ESP installations. Overall agreement of the model’s predictions with the experimental and field data was good in both high and low efficiency zones.
ESP Gas Separator’s Affect on Run Life
Authors: Wilson B. L. 
Published: December 2007

ABSTRACT
This presentation examines the phenomena of ESP run life reduction that can occur when rotary gas separators are employed. This reduction can be severe enough that some producers have stopped using them all together1. This paper presents information for the need for rotary gas separators and some alternate production strategies that could be attempted. The ESP manufactures now offer equipment that can extend the run life of these units in the problem wells. Familiarity with some of the alternate strategies and the improved equipment available will aid the user in selecting the strategy and equipment to optimize the run-life/production in his particular situation.
Increasing the Run Life of ESP’s in High H2S Wells
Authors: Wilson B. L. , Comeau T. P. , Davis P. M. 
Published: December 2007

Abstract
Mobil Oil Canada’s Wimborne Producing Team identified an economic opportunity to increase production and reduce operating expenses in the Wimborne field by converting several gas lift wells to electric submersible pumps (ESP). The economic success of the project demands that a one year ESP run life be achievable in the Wimborne field’s high hydrogen sulfide (H2S) environment. This paper reports on work performed to increase the life of ESP’s in wells with high concentrations of H2S (20% + ). The field experience had shown corrosion could be severe enough to destroy any copper alloys and some stainless steel alloys despite their location in the unit. Research work and failure analysis led to the development of unique ESP equipment designed to maximize run life in the Wimborne field. The work represents a joint effort among a major oil company, a ESP manufacturer and an academic research institution to develop methods to eliminate the sources of failures.
Dynamic Fluid Loss in Hydraulic Fracturing Under Realistic Shear Conditions in High-Permeability Rocks
Authors: Navarrete R. C. , Cawiezel K. E. , Constien V. G. 
Published: December 2007

ABSTRACT
A study is presented of the dynamic fluid loss of hydraulic fracturing fluids under realistic shear conditions. During a hydraulic fracturing treatment, a polymeric solution is pumped under pressure down the well to create and propagate a fracture. Part of the fluid leaks into the rock formation, leaving a skin layer of polymer, or a polymer filter cake at the rock surface or in the pore space. The fluid-loss behavior depends on the extent to which the polymer invades the porous rock and the thickness of the polymer filter cake, which is limited by the shear stress that the flowing fracturing fluid exerts on it. In this paper the effect is studied of shear rate on the dynamic fluid-loss behavior of linear gels and crosslinked borate guars using cores of permeabilities ranging from 0.5 to 70 md, pressure drops of 1000 psi and temperatures between 75°F and 150°F. The effect of shear on the formation of external filter,cake and on the effectiveness of particulate fluid-loss additives was also studied. A shear rate history representative of that experienced by a rock segment in the fracture was used. In this history the shear rate drops from a very high rate of 380 s-1 down to 40 s-1 due to the widening of the fracture width as time advances.
Constant shear rate results show that high shear rates eliminate external filter cakes. In the absence of external cakes, the formation of internal filter cakes controls the fluid loss, especially in high-permeability cores. The effectiveness of particulate fluid-loss additives increases with the permeability of the rock and decreases with the shear rate and viscosity of the fluid. Shear history tests with high permeability cores show that the highest leakoff
rates and volumes occur during the first 10 min of leakoff, i.e., when the rock surface is exposed to high shear rates. Once the shear rate drops below a critical shear value, polymer filter-cake deposition begins and the leakoff rate slows down. To have a major effect of reducing fluid loss in this environment, the emphasis has to be placed on plugging the porethroats at the surface of the rock.
The Effect of Pressure on Two-Phase Zero-Net Liquid Flow in Inclined Pipes
Authors: Amaravadi Sridhar , Minami Kazuioshi , Shoham Ovadia 
Published: December 2007

ABSTRACT1
The effect of pressure on two-phase zero net liquid flow in upward inclined pipes has been studied experimentally and theoretically. Experimental data were acquired for four upward inclination angles, namely, 1°, 2°, 5°, and 9°, and for three system pressures of 14.7 psia, 44.7 psia and 64.7 psia. A sequence of flow configurations was observed with increasing gas flow rate, as follows: Slug flow for low superficial gas velocities, protoslug for medium velocities, and pulsating small amplitude waves or roll waves at high velocities. At a particular velocity of gas, termed the blowout velocity, all the liquid was blown out of the pipe. An analysis of equilibrium stratified flow at the limit of very low and zero liquid flow rates has been carried out. It was found that under these conditions, the flow is always unstable, resulting in intermittent or pulsating stratified flow. A model has been developed for the prediction of the blowout velocity, as well as average liquid holdup and pressure gradient under zero net liquid flow conditions. A very good agreement was observed between the prediction of the proposed model and the experimental data
TACITE: A Transient Tool for Multiphase Pipeline and Well Simulation
Authors: Pauchon C. L. , Dhulesia Hasmuekh , Cirlot Georges Binh , Fabre Jean 
Published: December 2007

Abstract
The paper presents the principal characteristics of the TACITE code which has been developed to simulate transient and steady state multiphase flows, for the design and control of oil and gas production networks.
The hydraulic model is presented briefly and the resulting flow regime prediction is compared with experimental data. The performance of the code is illustrated with respect to steady state and transient experimental and field data.
Optimum Injection Rate from Radial Acidizing Experiments
Authors: Mostofizadeh Behdokht , Economides M. J. 
Published: December 2007

ABSTRACT
The optimum injection rate for the matrix acidizing treatments of carbonate reservoirs has been the subject of debate and several recent experimental studies. Because acid attacks the rock in different modes depending on the injection rate (i.e., compact dissolution, dominant wormhole, leakoff-dominated wormholing and uniform dissolution), it is essential to identify the rate at which the transition between dominant wormholes and leakoff-dominated wormholing occurs. This is the optimum injection rate at which the greatest penetration is accomplished with the least volume of acid injected. Linear or radial laboratory experiments can be done from which field conditions can be extrapolated through dimensional analysis. This is the subject of this paper. Optimum HCl injection rates for a low- and a moderate-permeability limestone using radial cores have been determined. The effects of temperature and acid concentration have also been studied. Analysis of the results shows that the optimum injection rate depends greatly on the rock and reservoir conditions and can be determined from experiments.
Microseismic Monitoring of Hydraulic Fractures in Prudhoe Bay
Authors: Brady J. L. , Withers R. J. , Fairbanks T. D. , Dressen Don 
Published: December 2007

Abstract
Production stimulation is commonly performed on reservoirs by hydraulically fracturing the formation. Fracture geometry is controlled by the regional stress field, strength and contrast in local rock stress and fracture fluid properties. Computer models predict the length and height of the fracture as a function of injection volume, pressure and rate, and, fluid and rock properties. Until recently, these computations were unable to be verified except for the fracture half length with pressure transient analysis and through log interpretation in close proximity to the well. Direct confirmation of fracture geometry has been shown possible with availability of downhole geophysical monitoring of the seismicity associated with the fracture production. This paper presents results of a test to directly measure the height, length, and azimuth of a fracture generated in the Prudhoe Bay Field, Alaska.
Two triaxial geophone tools were deployed during August 1993 to monitor for microseismicity associated with a hydraulic fracture. One tool was deployed in an offsite monitoring well, and the second tool was deployed in the rathole of the fractured well. The objectives of the test were (1) to determine if seismicity existed and if it could be detected from within the fractured well and from the distant offsite monitoring well, (2) to evaluate techniques used to locate the fracture, and (3) provide guidance for the development of seismic recording systems used in fracture monitoring.
Current Drilling Practices, Gomez Field, Pecos County, Texas
Authors: Reddig L.W. 
Published: December 2007

Abstract
Many changes in drilling technique have been made during the development of the Gomez Field in Pecos County, Texas. These changes have reduced the time required to drill and complete a deep Ellenburger gas well to less than 50% of that required in the early development stage of this field. Detailed well planning, thorough supervision, and continual effort to improve each phase of the operations involved have been instrumental in creating these changes. Improved drilling fluids and bit designs have contributed significantly to the reduction in time and money necessary for such drilling.
Introduction
Since completion of the discovery well in the Gomez Field in October, 1963, a total of 50 wells have been completed and 14 wells were being drilled as of February 1, 1970. Not only is Gomez the world's deepest commercial production, it is by far the largest concentration of wells producing from below 20,000 feet. Although development is not yet complete, average well costs in excess of 1.5 million dollars represent an enormous investment by the operators in this field. Possibly of more interest to operating personnel are the improvements in techniques, tools, and materials that have evolved from this program. Substantial improvements in drilling techniques have been made during the development of this field. An average well is now drilled to total depth in 150 days, or less, as compared to 350 to 400 days required in the beginning of this development program. Well (costs have decreased in program. Well (costs have decreased in relation to the number of days required to drill.
CURRENT PRACTICES
Gulf is a major operator in the Gomez Field, and the following discussion pertains to Gulf's experience and present operating procedures which are present operating procedures which are not significantly different from those employed by other operators in the field.
Use of Partial Perforations in Oseberg Horizontal Wells
Authors: Søgnesand Sigmund , Skotner Peder , Hauge Jan 
Published: December 2007

Abstract
This paper describes the planning, implementation, and results of partial perforations in Oseberg horizontal wells completed with cemented liners. Partial perforations are used primarily to achieve sufficient areal sweep, drain multi-formation systems, delay gas and water breakthrough, and to control the watercut. The perforation strategies are determined utilizing simulation models. The well trajectory and the permeability variation are obtained from measurement-while-drilling logs. The effects of the horizontal well trajectory modelling, permeability, structural dip, interlayer permeability, and factional pressure drop on the inflow profiles are discussed in the paper.
Detailed well and reservoir modelling are necessary to arrive at a successful partial perforation strategy in horizontal wells. Incorrect parameters such as the permeability profile may result in selected perforation intervals that yield non-uniform inflow, lack of multi-formation drainage, and in some cases lift problems. This paper demonstrates the importance of knowing the permeability profile along the horizontal well section prior to determining the perforation intervals.
The influence of the factional pressure drop in the producing well section on the uniformity of the horizontal well inflow profile is important in highly-permeable formations. Matching of the actual inflow observed utilizing production logging allows for estimating the horizontal and vertical permeability profiles, and the permeability profiles determined from M WD logs and geological permeability maps appear to be confirmed. However, unique estimates of the permeabilities cannot be obtained.
Production logging in the Oseberg horizontal wells shows that the inflow profile can be controlled by use of selective perforations. The field data also indicate that the partial perforation strategies have provided acceptable results. The Oseberg field examples yield new and useful information regarding perforating horizontal wells completed with cemented liners.
Coalbed Methane - A Decade of Success
Authors: Schraufnagel R. A. , Hill D. G. , McBane R. A. 
Published: December 2007

Abstract
Between 1983 and 1993, the coalbed methane (CBM) industry changed from a high cost operation to a competitive main line gas resource. In 1983, there were approximately 165 coalbed methane wells in the United States with an estimated total annual production of 6 BCF. Between 1983 and 1993, industry drilled an estimated 6600 CBM wells that account for nearly 5% of domestic annual natural gas production. The rapid growth in production from this resource required technology advances in reservoir characterization, stimulation and production. These technology advances have reduced the cost of production from this resource, allowing production to expand from the sweet spots of two basins to multiple basins.
MOTHER: A Model for Interpreting Thermometries
Authors: Maubeuge Frederic , Didek Michel , Beardsell M. B. , Arquis Eric , Bertrand O. , Caltagirone J. P. 
Published: December 2007

ABSTRACT
Despite many attempts to develop quantitative interpretation methods, the interpretation of temperature profiles has remained mostly qualitative. Most temperature models have concentrated on the wellbore thermal exchanges due to conduction and convection and have assumed that the produced fluid enters the wellbore at the geothermal temperature. Some authors have recognized the importance of the heating or cooling of the produced fluid before it enters the wellbore and have developed models incorporating the Joule-Thomson coefficient to take this into account. Flow in a porous media however does not satisfy the precise definition of a Joule-Thomson isenthalpic process, due to heat transfer between formation and fluid and since the Joule-Thomson process is by definition steady state both in terms of pressure and temperature.
This paper describes an energy equation that takes into account the temperature effects due to the decompression of the fluid and the frictional heating that occurs in the formation, and how this equation is coupled with the pressure equations in a finite element numerical well model.
The application to temperature log interpretation is demonstrated on real data sets. The ultimate goal would be to use the thermometry model for multilayer interpretations that differs from conventionnal methods in that both rate temperature can be matched.