bluuebunny/crossref_metadata_2025_split huggingface dataset:
3-D Reservoir Simulation Results of a 25-Square-Mile Study Area in the Kansas Hugoton Gas Field
Authors: Oberst R. J. , Bansal P. P. , Cohen M. F. , Ryan T. C. 
Published: December 2007

ABSTRACT
The Hugoton Gas Field is the largest gas field in the lower 48 states and represents a significant portion of the domestic gas production and reserve base in North America. The gas bearing Chase Group is characterized as a heterogeneous, multi-layered, no-crossflow system with over 5,925 producing wells in Kansas alone.
This paper reports the results of a three dimensional (3-D) reservoir simulation model that predicts the behavior of this multi-layered system under various producing scenarios. The 28 well pattern model covers a 25 square mile representative portion of the field called the "Nix area". The area was initially simulated in 1985 to primarily study the potential benefits of infill drilling. This earlier work is the fundamental blueprint from which today's current model is built. It was felt that by incorporating aspects of the previous study into the current model, it would provide a unique baseline to compare and contrast the earlier predictions against new data and our increased understanding of the Hugoton field, some seven years and approximately 1,660 infill wells later. The current model also contains two new replacement wells and an observation well that have been drilled since 1985. In addition, individual layer pressure data has been gathered along with the additional 10 years of production and pressure data which has occurred since the first study. Using the new model, various prediction runs were made to project each well's future deliverability, ultimate recovery and determine each individual layer's abandonment pressure, with or without infill drilling.
Results from the study indicate that the remaining life of the Kansas portion of the Hugoton field to be at least 40 to 50 years under existing producing conditions. The major gas producing layers will abandon at average bottomhole reservoir pressures ranging from 30-40 psia, while the tighter, less productive layers abandoning between 140–210 psia, regardless of infill drilling or. not. This will result in an expected ultimate recovery of between 90%–92% of the initial gas-in-place for the major producing layers, and between 58%–68% ultimate recovery in the tightest layers. The study also indicates that due to the laterally continuous nature of the geologic layers, infill drilling will result in only a period of reserve acceleration, with no significant, incremental reserves being developed.
Advances In Two Phase Flow Mechanistic Modeling
Authors: Taitel Yehuda 
Published: December 2007

Abstract
Rigorous exact solutions in engineering are essentially non existent. In all engineering problems one has to resort to some kind of approximations in which the physics of the problem is approximated and formulated in a format tractable by analytical or numerical means. This kind of approximation is termed MODELING.
In the quest for more accurate, but yet, sufficiently simple approaches to the solution of two phase flow problems MODELING is of utmost importance. The term "Mechanistic Modeling" was adopted for modeling where the physical phenomenon is approximated by taking into consideration the most important processes, neglect other less important effects that can complicate the problem but do not add considerably to the accuracy of the solution. "Mechanistic Modeling" should be sufficiently close to the natural phenomenon as the flow pattern involved should not be overlooked. Yet it will be sufficiently simple so that the solution is amenable with reasonable analytical or numerical efforts.
Specific examples which relate to recent developments in Mechanistic Models for two phase flow such as the prediction of flow pattern, stratified flow and the stability of stratified flow, slug behavior in pipes, slug length distribution, severe slugging phenomenon and splitting in a tee junction will be presented.
Consequence Analysis in the Production and Transportation of Oil and Gas
Authors: Norris H. L. , Hissong D. W. 
Published: December 2007

AbstractIn the event of a pipeline or vessel leak or rupture at an oil and gas production facility, understanding of vapor-liquid multiphase flows can be very helpful in mitigating the safety and environmental consequences. The relevant multiphase flow phenomena involve flows both internal and external to the pipe or vessel. They include the release rates of vapor and liquid hydrocarbons, the sonic flow region immediately downstream of the opening, possible generation of aerosols, and possible segregation of the efflux into a gas jet and a liquid pool. If the release does not ignite, it is important to be able to describe the dispersion of the heavy multiphase plume. If the release does ignite, the size, position, and luminosity of the resulting jet and pool fires are important. Many aspects of these flow phenomena are not well understood. A survey is made of the relevant issues, existing calculation methods, and suggested research initiatives.
Pressure Behavior of Horizontal Wells with Multiple Fractures
Authors: Kuchuk F. J. , Habusky T. M. 
Published: December 2007

Abstract
Drilling horizontal wells to accelerate production and increase recovery efficiency of oil and gas has now become common. With the increasing number of wells, transient well tests have been conducted in many wells with different geological settings. In this paper, we present a number of analytical models for horizontal wells with multiple fractures in homogeneous and laterally composite reservoirs. These solutions are applicable to finite-conductivity transverse fractures, and infinite-conductivity transverse and longitudinal fractures. They may also be used for the fractured reservoirs where the wellbore intersects with multiple fractures.
We examine the pressure behavior of horizontal wells with single and multiple fractures in homogeneous systems. It is shown that the wellbore cannot be neglected in the modeling of horizontal wells with fractures unless the fracture conductivity is high. If the fracture permeability (conductivity) variations in different zones are moderate, compared to the formation permeability, the multiple fractures have almost no effect on the pressure behavior of the system; the horizontal well dominates the system's pressure behavior. If the conductivities are high, the intersected fractures will dominate the behavior of the system at early times. It is also shown that multiple finite- and infinite-conductivity transverse fractures may exhibit multiple linear flow regimes before the onset of the first horizontal well radial flow regime.
Experiences With Combined Analyses of PLT and Pressure-Transient Data From Layered Reservoirs
Authors: Larsen Leif 
Published: December 2007

Abstract
Problems and possibilities with combined analyses of PLT and pressure-transient data from layered reservoirs are discussed, with standard single-layer methods used to estimate parameters, and model verification based on matches of available PLT and pressure-transient data used to complete analyses.
For commingled reservoirs it is shown that if the total flow capacity can be obtained from a direct analysis, then the flow capacity and skin of each layer from stable and short-time PLT profiles can also be obtained by simple two-rate methods. Assuming repeatability of the data, the PLT profile after shut-in can be determined from another test. Also, the rate of crossflow after shut-in relative to the production is shown not to be relevant for the success of this approach.
The main problem with layered-reservoir data is contrasts in skin values, both for commingled and crossflow reservoirs. With severe contrasts in skin values, analyses can become highly uncertain regardless of method used. This is shown by closedform approximations of infinite-acting solutions for commingled reservoirs and illustrated with synthetic data. A field case from the Norwegian sector of the North Sea has also been included to highlight the problems.
Fluid Placement and Diversion in Matrix Acidizing
Authors: Hill A. D. , Rossen W. R. 
Published: December 2007

Abstract
We compare four approaches for efficient placement of acid in matrix-acidization treatments: MAPDIR, particulate diverting agents, viscous acids, and foams. For each process, we develop analytical equations for flow into each reservoir interval and resulting skin factor. We consider treatments in reservoirs with two layers of different permeability but the same initial skin factor and with the same permeability but very different skin factor. MAPDIR reduces overall skin factor fastest but at the cost of injection of large volumes of acid into the higher-injectivity layer. Particulate diverting agents and foams can both effectively divert acid to the low-permeability or more-damaged layer but at the cost of lower injection rate. In our study, particulate diverters with the continuous addition of the diverting agent to the acid solution are most efficient. However, quantitative comparisons of foam with the other processes is difficult until more data are available for predicting foam performance in the field. The equations developed here can be applied to a wide variety of other field situations and process parameters.
Practical Pressure Loss Predictions in Realistic Annular Geometries
Authors: Haciislamoglu Mustafa , Cartalos Ulysse 
Published: December 2007

ABSTRACT
Frictional pressure loss calculations in narrow annuli of slim-hole and coiled tubing operations require more accuracy than before. The paper describes a method to calculate pressure losses that better represents actual annular configurations.
The skewed (vertical wells, varying eccentricity) and uniformly eccentric (deviated wells) geometries are addressed. Easy to use realistic correlations are obtained for laminar, transition and turbulent flow regimes. Experimental flow loop data validate model predictions. A step-by-step procedure is included for field calculations.
Dynamic Analysis Reveals Stability of Roller Cone Rock Bits
Authors: Kenner J. V. , Isbell M. R. 
Published: December 2007

ABSTRACT
The cutting structures of roller cone bits often experience catastrophic failures resulting from dynamic load variations beyond the capacity of the cutting elements. Continuous improvements to cutting structures have steadily increased penetration rates, but at the same time have elevated their sensitivity to these dynamic effects. Until recently, the causes of these failures were difficult to identify.
This paper details a series of roller cone bit tests that discovered a new explanation for cutting structure failure. In the tests, roller cone bits drilled Carthage marble under atmospheric pressure and the system response was monitored. Measurements were taken of new and dull bits, some of which incorporated unconventional cutting structures. Lateral movements of the bit included directional reversals and orbits about the hole center. Certain motions were identified that may result in cutting structure breakage. Included in the paper are examples from kinematic models that capture the essence of the motion and reveal its harmful effects.
A Magnetostatic Well Tracking Technique for Drilling of Horizontal Parallel Wells
Authors: Pratt C. K. , Hartmann R. A. 
Published: December 2007

Abstract
A directional surveying technique has been developed to monitor the directional drilling of two closely spaced, parallel horizontal wells. The well-tracking technique which is based on magnetostatic homing-in technology, uses the magnetic field of the casing in the first horizontal well as a reference for monitoring the drilling trajectory of the second horizontal well. For this purpose, the casing joints of the horizontal section of the first well are artificially magnetised prior to running in the hole, so that the unique magnetic field pattern can be detected in the second well with a conventional measurement-while-drilling tool. No additional tools nor acces to the first well while drilling the second well is required.
The well-tracking technique was sucessfully applied to the drilling of two horizontal wells as part of Shell Canada’s Horizontal Well Demonstration Project, of which the objective is to recover bitumen from tar sands in the Peace River Field, Alberta, Canada (See Reference 1 for definition of bitumen).
Nitrogen Drilling System for Gas Drilling Applications
Authors: Allan P. D. 
Published: December 2007

Abstract
This paper outlines the development of a nitrogen drilling system used by Meridian Oil on three nitrogen drilled horizontal wells in the San Juan Basin of New Mexico. The nitrogen drilling system eliminates the downhole fire risks associated with air drilling in hydrocarbon producing formations while significantly reducing costs as compared to pipeline gas (methane) drilling or trucked liquid nitrogen drilling. Typically, wells that must be gas drilled through productive intervals rely on pipeline gas, expensive trucked liquid nitrogen, or air-water injection (mist) systems. Water mist injection minimizes downhole fire potential but this method is unacceptable on horizontal wells as the extended drilling time in producing intervals greatly increases the probability of downhole fires. Data will be presented which outline the parameters for the nitrogen drilling system development including the required flowrates, the allowable oxygen concentrations, and economic analysis and justification. Actual field data will be presented, providing additional information relating to safety enhancements, cost reduction, and additional upside through the use of the nitrogen drilling system.
Slimhole Vibration Case Study
Authors: Murray P. J. , Kingman J. E. E. , Huddy R. L. , Leon J. G. 
Published: December 2007

Abstract
Drill string dynamics has become an important topic in recent times. This has proven to be particularly critical in slimhole drilling where the understanding and control of vibration has become essential. Conventional rigs have the strength and brawn to overcome most vibration problems and to get to TD even if not all that efficiently. In slimhole drilling, vibration can destroy the string. This paper is a case study into the experience of a major drilling contractor with severe vibration problems on their newly built slimhole rig, at the start of a multi-well contract with a major operating company to drill exploration wells in Venezuela.
The bottom hole assembly (BHA) was catastrophically damaged as a result of vibration, culminating in a number of fishing jobs and extensive repair work to the drill string and BHA. The postmortem on the damaged components and other wear indications on the string confirmed that the string had been rotating, at high speed, in a buckled mode.
This paper describes the various solutions considered and the actions taken. Particular focus is placed on the analysis of the BHA employed and the development of a new BHA design using the experience of a slimhole drilling consultant with the help of available modeling technology and how the limits to the operating parameters were set. With only theory as a guide, we needed reassurance that what had been done was the answer. What was actually going on down hole and what were the implications of our actions at the surface?
Technology currently available to measure vibration offered us the opportunity to see what was going on down hole in real time, giving us immediate feedback on the effects of our actions on surface. The standard vibration sensing equipment available consists of an instrumented tool installed in the string at surface. Unfortunately this was too big to fit under the top drive of the little slimhole rig and another approach was heeded.
The paper describes how the team from the vibration monitoring service company came up with the innovative idea of instrumenting the top drive itself to act as the tool and how they managed to achieve their objectives of providing a reduced level of their standard service to focus on the specific problem.
The paper concludes with some examples of how the monitoring system was able to tell us what the acceptable operating limits for weight-on-bit (WOB) were, by observing the growth of axial strain energy at specified frequencies. Some other valuable spin-offs have been seen and are highlighted in the paper.
BHA Design and Steerability Optimization for Extended Reach Drilling
Authors: Agawani M. M. , Maidla E. E. , Rahman S. S. 
Published: December 2007

Abstract
An algorithm, based on the steerability of a bottom hole assembly (BHA), has been developed which can predict the complete geometry of the most suitable BHA to drill a given section of a directional well.
The model is particularly versatile because it is applicable to rotary mode extended reach drilling, can be used to compare various BHA configurations to that predicted by the algorithm and can take full advantage of the steerability of variable gauge stabilizers.
A field case study is presented to illustrate its usefulness.
Probability Ranges for Reserve Estimates From Decline Curve Analysis
Authors: Huffman C. H. , Thompson R. S. 
Published: December 2007

Abstract
An estimate of the production expected from a property is frequently accomplished by extrapolating historic production data to a minimum economic flow rate. For a particular analyst, deterministic reserve estimates from decline curve analysis gives a specific answer or value for a given production data set. A method has been developed which yields probable production rates and volumes based on the analyst’s deterministic estimate of the future well performance. The objective is to quantify the uncertainty in reserve estimates from production decline curve data.
The statistical concepts of linear regression and prediction limits have been incorporated in a method which utilizes the analyst’s decline exponent (b), decline rate (Di), and production rate (qi) estimates. The method is flexible in that any portion of the historic production data may be utilized if the analyst believes the production parameters of the well have changed over the life of the well. The prediction limits yielded by the method are analogous to probability values and could be used in property value comparisons.
The method was applied to the deterministic reserve estimates made by seven practicing engineers in SPE paper 26388, "A Comparison of Probabilistic and Deterministic Reserve Estimates: A Case Study,"1 The results of this approach will be compared to the subjective probabilistic reserve estimates made by the engineers in the study by Hefner.
Reservoir Optimization in the Nineties: Is Your Company Doing an Effective Job?
Authors: Beatty T. A. , Karlen G. R. , Brown K. R. , Van’t Bosch A. L. , Grant Neal , Burkett Dan , Kissinger Tim 
Published: December 2007

Abstract
PanCanadian’s extensive land holdings and attractive financial position results in work efforts being generally capital related (seismic, drilling, and facilities). As. a result of this focus, Senior Management was concerned that optimization was not being given a high priority and initiated a study in June 1992 to evaluate the process within the company.
PanCanadian has undergone major structural and cultural changes in the past three years and has used process re-engineering to implement changes and increase efficiency. A product of this change is PanCanadian’s unique method of managing people functionally and managing work cross-functionally. This organizational structure is applicable to any company considering restructuring to achieve the gains associated with business units yet want to avoid their common downfalls.
A Reservoir Management Process Study was initiated with a team of seven people from various departments within the company. The study took approximately one year to complete and included over 30 interviews within PanCanadian. Twelve companies in Canada and the United States were benchmarked based on recommendations of superiority in the areas of reservoir optimization.
This paper will detail the methodology of conducting the study, the findings of the study, and will describe the major structural changes that PanCanadian is undertaking to do a more effective job of reservoir optimization.
Fate of Waste Petroleum Refinery Sludge After Deep Well Injection
Authors: Charbeneau R. J. , Ogintz Joanna , Aubert W. G. 
Published: December 2007

Abstract
Application of existing hydraulic fracturing technology to deep well injection of exempt and non-exempt wastes has been investigated. This new application involves disposal of wastes by controlled hydraulic fracturing of suitable deep geologic formations. The proposed process is similar to the widely accepted Class I injection, but allows subsurface placement of waste solids-bearing slurries. Subsurface slurry injection causes fracturing of injection zone rocks because solids-laden fluids (slurries) form relatively impermeable filter cakes when pumped under pressure. Reliable information on hydraulic fracture geometry and propagation has historically been lacking, and current methods of deep well disposal exclude fracture injection. For fracture injection to be accepted, a demonstration is necessary that migration of contaminants is limited to specific geologic formations or zones, or that injected materials undergo chemical transformation into non-toxic forms. This is a "no migration" demonstration, and is done by mathematically simulating transport of injected materials.
The present research involves mathematical simulation, or modeling, of deep well fracture injection of solids-bearing waste slurries. Basic analytical and numerical models were formulated for estimation of injected waste migration from a fracture system. Parameters are in ranges expected of realistic disposal conditions. Analytical and SWIFT II models address regional fluid gradients, reservoir permeability, and fracture orientation.
The Conversion to Team Based Organizations
Authors: Hagist Peter W. 
Published: December 2007

Abstract
Changes in technology and market conditions are driving companies to redesign their businesses from traditional functional based organizations to team based organizations that are focused on core business processes. The advantages of teams have long been recognized, but it is only now that economic forces are driving companies to make teams an integral part of the organization. The change is allowing business to work more efficiently and produce higher quality products at a lower price. For the Oil and Gas industry, team based organizations are a way to develop difficult reserves that otherwise would not be economic to exploit. Important considerations when implementing team based organizations include: J) Defining the core business processes, 2) Establishing roles and responsibilities, 3) Defining the organization, 4) Developing process measurements, 5) Development and cultivation of leadership over management or supervision, 6) Cross-training, and 7) Effective communication.