bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Results for Pressure Transient Behavior of Hydraulically Fractured Wells
Authors: Wilkinson D. J. 
Published: December 2007

Abstract
A number of new results for pressure transient behavior of hydraulically fractured wells are presented. The fracture is considered to be fully penetrating with the well located at its center, and to be of dimensionless conductivity FD. The solutions are obtained in the Laplace transform domain, and so may be easily combined with wellbore storage. For the case of an infinite conductivity fracture (FD → ∞), it is shown that the exact solution (exhibiting early time linear flow in the formation and late time radial flow) may be written in terms of so-called Painlevé functions; this representation is much more convenient than the Mathieu function solution given in the literature, because the Painlevé function may be easily computed as the solution to a (non-linear) ordinary differential equation. In the case of a low conductivity fracture (FD → 0) the fracture may considered to be infinite in length; in this limit it is shown that the exact solution (exhibiting early time linear flow in the fracture, intermediate time bilinear flow and late time radial flow) may be written in closed form in terms of elementary functions. It is observed that the early time part of this solution is valid even in the case of a high conductivity fracture. By use of the method of matched asymptotics, the above solutions are combined to obtain a new Laplace domain solution which works well for all values of FD and for all times. The solution compares well with numerical results given in the literature, exhibits all known flow regimes, and may be coded very efficiently on a computer.
Pressure Transient Behavior in Multilayer Vertically Fractured Gas Reservoir With Finite Conductivity
Authors: Okoye C. U. , Oshinuga A. D. , Ghalambor A. 
Published: December 2007

Abstract
This paper presents a new model for pressure transient in wells intercepted by finite-conductivity vertical fracture in closed square multilayer double porosity reservoirs. Analytical, semi-analytical and numerical solutions are given. The set of asymptotic analytical solutions are for early, intermediate and late times and can be used to analyze transient pressure data if the flow period is known or can be identified. The general semi-analytical solution is for all times and was used to generate type curves. The numerical solution was used to verify and validate the general purpose semi-analytical solution and vice versa. The two solutions agree within six percent.
The type curves were used to match a set of drawdown pressure data for a tight gas reservoir in order to determine fracture conductivity and fracture half-length. The results of the analysis are in good agreement with published results.
We believe that the model presented in this study may be more appropriate for expressing the pressure transient response in multilayer fractured tight gas reservoirs than the existing model particularly when the fracture conductivity is finite.
A Comparative Study of Future Possible Conventional and Unconventional Gas, Rocky Mountain Region
Authors: Nilson G. J. , Haas M. R. , Kelso B. S. 
Published: December 2007

Abstract
Many studies have been made relative to the gas resource potential of the Rocky Mountain region, but a search of the literature has revealed few forecasts as to what gas may be actually producible under a variety of wellhead price conditions. This study provides such forecasts and shows how the undedicated Rocky Mountain gas resources could compete with the Permian and Anadarko basins in the national gas market.
The principal analytic tool used in this study was a model developed by ICF-Lewin Energy, Inc. entitled "The Oil and Gas Replacement Cost Analysis Model" (REPCO).1 This system provides the user with a resource base that is disaggregated by geographic, depth, resource quality, and certainty that is served by a flexible decision oriented software package. The system was designed to assist producers, pipelines, distribution companies and large-volume industrial consumers to respond to the challenge of changes in the regulatory climate and falling product prices.
The largest single factor on the horizon for the realization of the Rocky's deliverability potential is the Thermal Enhanced Oil Recovery (EOR) market in California. The need there for long term, reliable supplies of natural gas has been the subject of great interest to pipeline companies who are competing for that market. The geographic proximity of the Rocky Mountain region together with the large resource base makes the area the prime candidate for providing that supply.
Innovative Techniques for Converting Old Waterflood Injectors to State-of-the-Art CO2 Injectors
Authors: Bowser P. D. , Corey J. D. , Darr C. D. K. , Caro D. A. 
Published: December 2007

ABSTRACT
The success of a CO2 flood largely depends on the quality of its injection wells. The wells must confine injection to the desired pay intervals and withstand the corrosive nature of CO2 for the life of the flood. These are difficult goals to achieve considering the primary candidates for CO2 flooding are mature waterfloods where the wells may have been in service for forty years or more. Casing and cementing practices of the past were often inadequate for a long waterflood life, and are certainly unacceptable for a long term tertiary recovery project.
This paper describes innovative techniques employed in the MCA Unit, located in southeast New Mexico, for converting old waterflood injection wells into state-of-the-art CO2 injection wells. The solutions developed for the MCA CO2 Project have considerable application to other CO2 projects and can be profitably employed to improve waterflood recovery as well.
New Cement System Improves Bonding in the Stony Creek Field, Williston Basin, North Dakota
Authors: Morris B. V. , Shumaker E. F. , Ramsey L. K. 
Published: December 2007

ABSTRACT
Salt sequences that occur in the Williston Basin pose numerous drilling and completion problems. Probably the most severe of these is the collapse of the casing caused by the plastic flow of the salt. Over the years it has been observed that a high percentage of these collapse problems have occurred in the top part of the washed out salt section. In these cases, a typical bond log showed good-to-excellent bond across the salt with poor-to-no bonding at the top of the salt section where collapse occurred.
This paper describes work done in the Stony Creek Field of North Dakota with the objective of eliminating the area of poor bonding at the top of the washed out salt sections. The Stony Creek Field was discovered in 1987 with the Mission Canyon formation being the primary producing horizon. A new cement system is described which was placed across the primary sections of three wells. Bond logs were run comparing the results of the new cement system to that of a conventionally cemented well. The results showed the new system to be successful in eliminating the bonding problems in the top of the salt zone. To date, the wells have not experienced collapse problems.
Desorption of Hydrocarbons From an Unconsolidated Sand
Authors: Oxford Charles W. , Huntington R.L. 
Published: December 2007

Abstract
Both pressure depletion and constant pressure flow "sweep" methods have been studied for the recovery of some pure hydrocarbons by desorption from an unconsolidated sand.
Several factors which were thought to contribute to the desorption of hydrocarbons have been treated separately. They were [a] rate of gas flow, [b] original liquid saturation, [c] reservoir temperature, and [d] presence of water and brine.
The effect of pressure, size and shape of interfacial surface, presence of other components, and interfacial tension have been treated theoretically. Equations for the calculation of theoretical pressure-specific gravity curves and their limitations are presented.
Pure hydrocarbons, n-hexane and n-heptane, and a pure gas [nitrogen] were employed in most of the experiments. In addition, a run was made with a hydrocarbon condensate as the saturating liquid.
Data and graphs have been presented for desorption of pure hydrocarbons at pressures ranging from 50 psia to 4,000 psia, with liquid saturation of 5 to 25 per cent, water content of 5 to 25 per cent, and withdrawal rates of 0.034 to 0.900 reservoir volumes per minute. Theoretical curves have been shown with the experimentally determined points.
Data and graphs have also been presented for atmospheric sweep studies, together with curves based on equilibrium conditions. Hydrocarbon concentrations of 5.1 per cent to 34 per cent, and sweep velocities of 1.159 to 13.66 reservoir volumes per minute were employed.

Introduction
During the past 20 years, [1932–1952] many condensate reservoirs have been discovered in the United States, particularly in the Gulf Coast region. Most of these reservoirs have been produced by a combination of gas cycling and slow pressure depletion in order to recover the liquefiable components from the single-phase fluids originally existing within the reservoirs.
Although a record of the composition of the produced fluids has been kept on some of these reservoirs, very little laboratory work has been done on small scale replicas so as to obtain some idea of the effect of such variables as fluid flow withdrawal and cycling rates, pressure, temperature, percentage of liquid hydrocarbon and water saturation within the reservoir, etc.
Comparing Openhole Cavity and Cased Hole Hydraulic Fracture Completion Techniques, San Juan Basin, New Mexico
Authors: Logan T. L , Clark W. F. , McBane R. A. 
Published: December 2007

Abstract
Completion technology has evolved significantly since the first San Juan Basin coalbed methane wells drilled in the 1950's. Initially wells were completed openhole, however, hole stability was a major problem in addition to the inability to isolate different coal seams. A cased hole type completion was later adopted utilizing perforations and hydraulic fracture stimulations. Recently openhole type completions are again popular with some San Juan Basin operators, in which a large cavity is created in the coal seams of the openhole interval. The openhole section is then lined with pre-perforated uncemented casing. Both cased hole with fracture stimulations and openhole cavity completion techniques are currently being used in the San Juan Basin at the Northeast Blanco Unit operated by Blackwood and Nichols Company, Ltd. This provides a unique opportunity to compare the techniques to determine which technique is best.
Insights and Analysis From the Rock Creek Project: A Reservoir Engineering Approach
Authors: Zuber M. D. , Boyer C. M. , Schraufnagel R. A. , Saulsberry J. 
Published: December 2007

ABSTRACTSince 1984, the Gas Research Institute has been conducting field evaluations of coalbed methane technology at the Rock Creek Project site near Birmingham, Alabama. This paper presents and discusses preliminary conclusions based on initial reservoir engineering analysis of data gathered from field experiments performed at Rock Creek.Major conclusions from the analysis performed to date are 1) post shut-in methane production is not significantly reduced by water influx during normal shut-in periods, 2) long-term methane recovery from a well is not a function of initial water pumping rate, provided the initial rate is above the minimum required to initiate desorption, and 3) well-to-well interference is the primary mechanism for efficient recovery of coalbed methane.Ongoing reservoir engineering analysis will provide further insights toward characterizing methane production from multi-zone completion wells and establishing a rationale for dewatering coalbed methane wells.
Flow Analysis In Producing Wells
Authors: Curtis M.R. 
Published: December 2007

Curtis, M.R., Member AIME, Schlumberger Well Services, Houston, Texas
This paper was prepared for the 42nd Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held In Houston. Tex., Oct. 1–4, 1967. 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 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
Production Logs provide information for downhole flow analysis of producing wells. These flow analyses determine the various amounts, types, and depths of fluid entry into the casing. This information may be used to study a reservoir, to catalogue an initial completion, or to engineer remedial action.
Gradiomanometer and Flowmeter surveys are used to analyze two-phase, bubble-flow production. The average density of the flowing fluids is obtained from the Gradiomanometer; the total flow rate from the Flowmeter.
Two facts complicate mathematical flow analyses. First, the bubbles of the lighter phase travel upwards at a greater velocity than the continuous heavier phase. Second, the down-hole volumetric fractions of the phases are different from surface fractions. It is necessary to consider the slippage velocities and the phase holdups in analyzing the down-hole flow.
Charts have been prepared to provide a simple and fast graphical means of flow analysis. Each individual chart is prepared for a specific casing size, tool size, and slippage velocity. The latter can he estimated with reasonable accuracy from knowledge of the densities of fluids being produced. On the charts, Gradiomanometer and Flowmeter data are used to graphically compute a flow analysis.
The charts may also be used when only a Gradiomanometer is available. In this less accurate application it is assumed that only a single fluid phase enters at any given level, and that a zone without change on the Gradiomanometer is not producing any fluid.
The Gradiomanometer-Flowmeter method of analysis is effective in high-flow-rate oil wells producing gas or water, and in low-to medium-flow-rate gas wells producing oil or water.
Enhancing Borehole Image Data on a High-Resolution PC
Authors: Wong S. A. , Startzman R. A. , Kuo T-B. 
Published: December 2007

Abstract
Because most downhole reservoir evaluation tools are unable to successfully detect very thin bedding, it is difficult to evaluate the production potential of laminated formations and small natural fractures. The availability of logging tools that provide higher data sampling rates has made the study of in-situ, fine-scale formation features possible. Tools such as the Formation MicroScanner* (FMS), Borehole Televiewer (BHTV), and the High-Resolution Dipmeter are able to show images of borehole walls. However, the interpretation of borehole images relies on the quality of the image data presented. Fine-scale formation features such as bedding will not be recognized if the presentation of the images is unclear.
The purpose of this paper is to provide an inexpensive and intuitive way for enhancing and displaying borehole images. The advent of 32-bit microcomputers and windowing software on PC's makes the availability of inexpensive platforms for viewing, analyzing, and interpreting data possible. We have developed a prototype system for image analysis and image processing of FMS and BHTV field data. The software represents the first stage towards a borehole image understanding system.
PLATLOC: A Program for Optimizing Offshore Platform Locations
Authors: Watson W. S. , Mahaffey D. W. , Still J. P. , Taylor R. D. 
Published: December 2007

ABSTRACT
Platform site selection is one of the most important decisions made early in the life of an offshore lease development, impacting not only total cost but also hydrocarbon recovery. We developed a non–statistical computer model which focuses on the critical technical aspects of development optimization.
An Expert System Helps in Formation Recognition
Authors: Mabile C. M. , Hamelin J-P. A. , du Chaffaut B. Amaudric , La Fonta J-G. M. 
Published: December 2007

Abstract
An expert system has been developed to give the driller indications on formation changes by using downhole or surface measurements. In a "user friendly" environment the expert system includes a preprocessor to combine parameters and a 0+ inference engine. Results are displayed with standardized pattern and comments to describe the formation. The many tests performed with this expert system show that the rule base used to describe knowledge stays constant for an oil field.
Field Evaluation Results of New Clay Stabilizer in the Appalachian Area
Authors: Baltz T. H. , Himes R. E. , Dalrymple D. 
Published: December 2007

ABSTRACT
Formation damage in the vicinity of the wellbore is a major cause of low productivity, and the difficulties involved in removing the damage translate into a significant number of wells that do not respond satisfactorily to remedial treatment. This damage is usually the result of fines migration which is triggered by the introduction of foreign water. The migrating fines tend to lodge in constrictions in the formation flow channels where they severely reduce production.
Clay stabilizers have been used to solve this problem for several decades. Cationic organic polymers (COPs) have been the most popular stabilizers because of treatment longevity and effectiveness in moderate to high permeability formations. Most producing formations in the United States, however, do not have moderate to high permeabilities but are classified instead as "low" permeability.
A new clay stabilizing additive has been developed specifically for low permeability formations typical in the Appalachian basin. This low molecular weight chemical is shown to be effective in rock matrices with permeabilities as low as 0.015 md. Other popular clay stabilizers with higher molecular weights are less effective in preventing swelling and migration of clay in formations having permeabilities below 30 md. Additionally, permeability damage can result when these relatively high molecular weight polymers are injected into low permeability formations.
Data are included from laboratory core tests using the low molecular weight clay stabilizer. The encouraging results of these laboratory tests is supported by field production results in the Appalachian basin. The field data include the results of fracturing, acidizing, and other operations, all of which are tabulated and discussed.
Application of Deep Diving Systems in Offshore Operations
Authors: Young K.G. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the 42nd Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Houston, Tex., Oct. 1–4, 1967. 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 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
This paper reviews current offshore operations around the world which involve the use of tethered, manned submersibles to support deep diving operations.
It discusses the evolution of simple underwater transport vehicles to the relatively sophisticated semi-mobile hydraulic tool equipped, life support capsules which have found applications in offshore petroleum, salvage and underwater construction. A variety of systems have been developed during the past few years to meet the many and various needs of the offshore diving industry.
The conclusions reached by this paper are that the current utilization of diving systems in the support of deepwater offshore work has resulted in increased efficiency, reduced costs and much safer operations.

Introduction
This paper provides a brief review of deep diving systems which have current applications in the support of offshore petroleum recovery, salvage operations and underwater construction. Its primary focus is on "tethered" or surface supported diving bell systems capable of "looking out" 1 / divers rather than submarines (with or without diver lockout capabilities), simple observation bells or open bottom decompression rest chambers. To date, the tethered diving bell systems with a diver lockout capability, have enjoyed a more active commercial offshore utilization than other types of submersibles, due to the nature of current offshore technical and economic requirements.
The tethered diving bell is an ancient invention.
Hydrodynamic Modeling of Wellbore Hydraulics in Air Drilling
Authors: Adewumi M. A. , Tian S. 
Published: December 2007

Abstract
Optimal design of any drilling program requires a good knowledge of the wellbore hydraulics. For conventional mud drilling, established techniques are available for formulating some understanding of the associated wellbore hydraulics but this is not the case for air drilling. It is a fact generally acknowledged that the wellbore hydraulics involved in air drilling presents a distinct problem from those associated with mud drilling. A systematic study of this problem especially utilizing fundamental approach is lacking. This study addresses this important problem using a fundamental hydrodynamic multiphase flow model. The model incorporates the fundamental physics involved in the pneumatic transportation of solid cuttings in the drill string-wellbore annulus. This model forms the basis for a predictive tool for the optimal lifting velocity, an essential ingredient in the optimal design of the air drilling program.
Air drilling program design must rely on the a priori knowledge of the basic design parameters such as how much air is required for optimal lifting of the drill cuttings, pressure drop as a function of drilling rate, etc. Drilling engineers often experience frustration due to lack of models with adequate predictive capability to help them answer these basic questions. Available correlations are, at best, gross approximation and more importantly, they fail woefully to account for the physical phenomena that are observed in pneumatic conveying involved in air drilling such as choking, clumping, etc.
We present a fundamental wellbore hydraulics model based on the understanding of the physics involved in the pneumatic transport of solid cuttings in the the drill-string/wellbore annulus. Extensive parametric analysis of the system is performed to validate the viability of the model as a predictive tool. Its capability as a design and scale-up tool is also investigated by simulating field conditions. The model is demonstrably capable of predicting the pressure drop profile in the annulus under various simulated drilling conditions. In addition, results demonstrate the capability of the model in being able to predict a number of phenomena that are associated with lifting cuttings out of the hole during air drilling. The model possesses scale-up capability.
Diamond-Enhanced Hammer Bits Reduce Costs-per-Foot and Directional Problems in Southwestern Pennsylvania Oriskany Wells
Authors: Weller T. F. , Baum G. A. , Muncy W. H. 
Published: December 2007

ABSTRACT
A case history of the drilling practices on southwestern Pennsylvania Oriskany wells demonstrates how the use of diamond-enhanced hammer bits have reduced costs per foot and directional control problems.