bluuebunny/crossref_metadata_2025_split huggingface dataset:
Estimation of Distance to a Slanted Flow Barrier From Pressure Transient Test Data
Authors: Azari Mehdi , Ershaghi Iraj 
Published: December 2007

Abstract
The analytical solution of the wellbore pressure in a reservoir which is located near a slanted fault were derived using the method of images and by applying the principle of superposition to the Kelvin's point source solution. The solutions show that the inclination of the flow barrier causes additional pressure drop beyond what is usually considered in the concept of a single mirror image well. The extra pressure drop causes gradual changes on the slope of semi-log plots of pressure versus time. In many cases the behavior resembles that of wells in completely bounded systems. Using the general solution presented in graphical forms, one may estimate the distance to the fault.
Evaluation of the Use of High-Strength Crosslinked Hydrochloric Acid System for Mission Canyon Stimulation: SEM/EDS Analysis
Authors: McLane J. E. , Scott M. A. 
Published: December 2007

ABSTRACT
Core samples examined from the Mission Canyon Formation, McKenzie County, North Dakota were subjected to Scanning Electron Microscopy/Energy Dispersive Spectroscopy (SEM/EDS) analysis. The interval of the core samples studied from well "A" were 9122–9125 feet, 9140–9143 feet and 9171–9174 feet. Those samples studied from well "B" were taken from intervals 9471–9474 feet and 9556–9559 feet. This preliminary study was carried out to evaluate the Mission Canyon formation for a successful stimulation treatment.
The Mission Canyon formation is predominantly fractured dense carbonate of the lower middle Mississippian and a member of the Madison group, see fig. 1. Problems have been encountered in stimulating the Mission Canyon due to a variety of factors. Out of many, a few important ones are the release of fines and their migration due to acid reaction, the presence of clay minerals and the availability of various other acid insoluable mineral assemblages.
A limited number of Mission Canyon cores were available for this study. This paper will discuss the in depth SEM/EDS analysis. Information is now available to aid in the selection of a more effective system to stimulate the Mission Canyon Formation. The effectiveness of a high strength, crosslinked hydrochloric acid system in various counties namely, Billings, Williams and McKenzie in North Dakota has been studied. Scrutiny of the crosslinked acid jobs pumped indicates that small volume jobs (1000-5000 gallons) in the Dickinson area using high strength (15%–20%) crosslinked hydrochloric acid at low rates, (4 to 8 barrels per minute) have been more successful, wheras large volume jobs have not produced encouraging results.
This paper will provide insight for optimizing acidizing systems that suspends fines and prevents their migration thus making stimulation in the Mission Canyon Formation more successful.
Rate Gyro Surveying of Wellbores in the Rocky Mountains
Authors: Wright John 
Published: December 2007

ABSTRACT
The introduction of a rate gyro surveying system was made in the Rocky Mountain area in April 1982. This paper describes that system as well as its accuracy and durability.
It appears there has been a significant increase in accuracy and durability, with a decrease in survey time over conventional free gyro systems. This assessment is made from data accumulated over 100 field surveys, many runs in a 1400 foot test well and hundreds of hours on a laboratory test stand.
The Eastman Whipstock rate gyro system employs a single floated rate integrating gyroscope gimbled with a single precision accelerometer. This configuration is rotated about the tool axis 360° for every survey measurement. From this rotation the gyro measures a component of the earths horizontal spin vector, which by definition points true north, and the accelerometer measures a component of the earths gravity. The information is then processed to provide inclination, borehole azimuth and tool face. This method provides increased accuracy by producing readings which are independent of those taken previously and by eliminating C-independent sensor bias. Additionally this configuration allows a pressure barrel outside diameter of only 1 3/4″ (45.0mm).
The Application of Mud Motors for Surface Hole Drilling
Authors: Foret Gary , Kerr Jim 
Published: December 2007

ABSTRACT
Mud motor drilling with mill-tooth or insert-type bits in the surface upper hole can often result in increased rates of penetration and less hole deviation -- two factors that can often mean cost savings to the operator.
Most people associate mud motors with two different types of drilling -- controlled directional and long-interval straight-hole drilling. Using mud motors is now the norm rather than the exception in drilling a directional section, and in the last five years, mud motors, when used with diamond or PCD type bits, have gained wide acceptance in many long-interval drilling applications. The reasons for the increased use of mud motors in straight-hole drilling are higher rates of penetration (ROP) than traditional methods, less hole deviation, and much improved tool performance, resulting in savings for the operator.
Recent case histories in the Rocky Mountain Region show that these same reasons apply to a section of the hole not often associated with mud motors, but nevertheless where mud motors are now providing a viable alternative to rotary drilling -- the surface or upper hole. Drilling a large (12¼″, 17½″, 26″) surface hole with a mud motor and mill-tooth or insert-type bits can, in many cases, 1) increase ROP, and 2) maintain a straighter upper hole which helps minimize subsequent problems as the hole depth increases. In some cases, rates of penetration have been improved even when drilling single pass large diameter hole, thus also eliminating the need for hole opening operations, and adding to cost savings.
Positive Displacement Downhole Motors and Diamond Compact Bits Reduce Drilling Costs in Overthrust Wells
Authors: Wood J. E. 
Published: December 2007

ABSTRACT
Recent technological advancements made in synthetic diamond bits, coupled with positive displacement downhole mud motor technology now enable operators to use these two products and technologies in deep overthrust wells to reach total depth in fewer days at lower cost per foot.
Straight-hole drilling programs using high speed, low torque motors and synthetic/natural diamond bits have been economically utilized in a number and variety of well types in the Overthrust belt.
One-Dimensional Modeling of Steam Injection in Tar Sands
Authors: Chen C. S. , Hutchinson H. L. 
Published: December 2007

ABSTRACT
A one-dimensional numerical model of steam injection was developed and used to simulate experimental steam and hot water injection in the Asphalt Ridge Tar Sands. The model described a three-phase flow system of water, steam and oil with interphase mass transfer of water. The mass and energy balance equations were solved simultaneously by a semi-implicit Sequential Solution method.
The results of the linear numerical simulator showed moderate agreement with the observed results from the steam and hot water injection experiments. The simulator predicted that (1) changes in relative permeability, thermal expansion coefficient of oil and oil viscosity are important factors affecting oil recovery from tar sands; (2) the oil response time is decreased with increasing steam injection rate and quality, and is decreased by reducing steam injection temperature.
Compressed Air and Foam, Cleanout Technique for Old Open Hole Completions
Authors: Dahlgaard C. C. 
Published: December 2007

ABSTRACT
Compressed air and drilling foam is being used successfully in circulating out mud, grit, cavings and spent acid from shallow(1700 ft.) open hole completions in the Kevin-Sunburst Field. Many of the wells cleaned out have shot holes and low bottom hole pressures. The technique is cost effective and usually prevents cleanout induced formation damage.
Procedures To Improve Pre-Frac Well Testing and Analysis
Authors: Branagan Paul , Cotner Gene 
Published: December 2007

ABSTRACT
This paper presents the results of a study designed to determine well testing procedures required to overcome the effects of formation damage from drilling, completion and other fluids in order to permit the derivation of realistic values of original formation permeability. A variety of possible drilling, completion and well testing conditions was modeled using a numerical multiphase reservoir simulator. Results indicate the possible lengths of the tests that may be required for various expected permeability ranges and how to allocate drawdown to buildup time for a fixed testing time to optimize results.
High-Volume Electrical Submersible Pumping in the Sulphate-Scaling Environment of the Piper Field
Authors: Macdonald B A , Engwall S J 
Published: December 2007

ABSTRACT
Electrical Submersible pumping is currently one of only three artificial-lift methods practicable in the North Sea production environment. The pump installations from multi-well platforms involve operating deep-set units in highly deviated wells with high rates of oil and water production. The majority of the fields in the North Sea employ deaerated seawater injection as a means of reservoir-pressure support. The resultant breakthrough of injection water in the producing well creates an environment for potential scale formation.
This paper presents the original design concepts and experience gained from the initial installation in Piper field well PO7. The use of a soft-start facility and the scale-inhibitor squeeze technique to extend pump life is discussed and conclusions drawn for future installations, which will total 12 units by 1986.
Small-Diameter Inertial-Grade Sensors Significantly Enhance Wellbore Survey Accuracy
Authors: Morgan D G , Uttecht G W 
Published: December 2007

ABSTRACT
Tests with a new directional-survey instrument show a significant enhancement in the accuracy of defining a wellbore trajectory. Several prototype systems developed over the previous two years by Gyrodata Inc., in conjunction with Incosym Inc., a developer of guidance systems and components for the aerospace industry, have successfully undergone tests in the laboratory and in the field. The testing period, which included both land and offshore operations, indicates that the original design objective for borehole position uncertainty less than 1.7 feet per 1,000 feet of hole has been met. Although prototype development has been completed to the extent that criteria for manufacturing have been established, an ongoing testing programme is in effect to verify field accuracies and system application in a wider range.
The Gyrodata Wellbore Surveyor employs an inertial grade-rate gyro adapted from the aerospace industry. In combination with its other sensors and electronics, the device can sense the orientation of the earth's spin vector at each independent survey station. As a result, the major systematic errors associated with conventional gyros-geographical reference and unaccountable drift - are eliminated. Other sources of inaccuracy are minimized by the system's measuring techniques and operational procedures, and additional benefits arise from faster survey speed and increased reliability. A true north reference device can also employ a small outside diameter since it requires only one gyro and one accelerometer.
Test Installation of Subsea Production System and Flowlines in Deep Water
Authors: Madsen T , Andersen S , Vetaas L 
Published: December 2007

PREFACE
The subject for discussion in this paper is the marine operations as they were performed during the research project:

CIB – DIVERLESS INSTALLATION AND MAINTENANCE OF SUBSEA PRODUCTION SYSTEMS IN DEEP WATER
The project commenced in January, 1981, with participation of six oil companies: AGIP, Chevron, Fina, Hispanoil, Norsk Hydro, and Total.

ABSTRACT
A single-well Subsea Production System (SPS) was installed in 300m of water depth for test purposes in the Onarheimsfjord on the west coast of Norway in the autumn of 1982. Two different ways of connecting flowlines to the SPS were tested; a remote off-bottom pull-in operation featuring the "J"-method.
All operations were performed diverless, a remotely operated observation vehicle (ROV) and an Atmospheric Diving Suit (ADS) beingused for general assistance and back-up.
In order to optimise the operations, extensive analyses had been performed on the equipment and on the operational plan. These analyses included a failure mode and effect analysis (FMEA) on equipment and operations in general as well as computer simulations of the flow line operations.
The objective of the test was to gain experience related to operations in deep water, state limitations in today's level of technology.
The paper gives a review of the test and planning phase. The problems related to deep waters are pin-pointed, and some results are given.
Flexible Dynamic Riser for Floating Production Facility in The North Sea
Authors: Pettenati C , Dumay J M 
Published: December 2007

Abstract
For several fundamental reasons such as growing economical constraints, decreasing size of discoveries, deeper-water exploration, improvement of subsea technology, the trend for future offshore developments has recently been very much in favour of the floating-production facility concept.
This type of development has been for several years successfully implemented in various parts of the world where weather conditions are favourable, for both early-and permanent-production applications (Brazil, Mediterranean Sea etc….).
So far in a more hostile environment such as the North Sea, only two producing fields have been developed using this approach : Argyll (1975), Buchan (1980).
A Case History of Polycrystalline Diamond Compact Bit Performance in the Tuscaloosa Trend
Authors: Moore S. O. , Lynch B. W. , Talbot K. J. 
Published: December 2007

ABSTRACT
This case history documents the performance of Polycrystalline Diamond Compact (PDC) bits relative to conventional roller cone and natural diamond bits in drilling a deep (14,500 ft – 18,000 ft) shale-chalk sequence in 65 wells in the Tuscaloosa Trend of South Louisiana. PDC bits were used on rotary for drilling this sequence with varying degrees of success in conjunction with four different drilling programs. Included are discussions on variables which affected the performance of the PDC bits studied. Data presented originates from company bit records and photographs compiled during normal field operations.
Effect of Pattern Configuration on Oil Recovery by In-Situ Combustion
Authors: Huang Kuo-Lon , Aziz Khalid 
Published: December 2007

ABSTRACT
A numerical investigation of the effect of pattern configuration on oil recovery by in situ combustion is presented. The patterns considered were inverted 5, 7, 9 and 13 spot. The data used for the base case were typical of the Athabasca area of Alberta, Canada. The sensitivity results are presented for changes in well density, pay thickness, initial oil saturation, oil viscosity, absolute permeability, water-oil ratio and air injectivity. All results are compared at the time of steam breakthrough.
The numerical results presented in this paper show that hexagonal (7 and 13 spot) patterns perform better than square (5 and 9 spot) patterns for most situations. As the oil mobility is reduced, the relative performance of square patterns tends to improve.
The results presented should be of value in the design of in situ combustion projects.
In-Situ Combustion Pilot Operations in the Wabasca Heavy Oil Sands Deposit of North Central Alberta, Canada
Authors: Alderman J. H. , Fox R. L. , Antonation R. G. 
Published: December 2007

ABSTRACT
General American Oils, Ltd. conducted a wet institu combustion pilot in the Wabiskaw Formation of the Wabasca Heavy Oil Sands Deposit from February, 1981 until February, 1983. The purpose of this test was to assist in determining if this process would be economically feasible in the Wabiskaw Formation.
A single 20 acre (8.09 hectare) inverted seven spot was chosen as the pattern for the pilot. The operational concept was that the producing wells would be cyclic steamed to stimulate them at the same time that the wet insitu combustion process was being conducted. To monitor the movement of the combustion front, a series of 3-D seismic surveys were scheduled. The initial survey was conducted prior to air injection and was used as a reference to compare to the surveys conducted after ignition of the pilot.
The pilot performance using cyclic steam and wet insitu combustion as well as the results of the 3-D seismic monitoring are discussed in this paper. The well completions and surface facilities design as well as operational concepts to allow year round operation in a muskeg environment are also discussed.
Additional information was also gathered on the rock and fluid properties of the Wabiskaw. Even though the project was terminated after two years of the planned five year program because of the poor performance exhibited using air injection, the information gathered will help in the design of future Wabiskaw pilots.
Well Test Interpretation in Heterogeneous Reservoirs With Skin and Afterflow: Some New Theoretical Solutions and General Field Experience
Authors: Niko Helmut 
Published: December 2007

ABSTRACT
Some new analytical solutions for dimensionless pressure vs. dimensionless time are presented. It is deomonstrated how these new solutions, together with existing ones, can be used for unravelling reservoir heterogeneity patterns, quantitative interpretation of selected field tests, and well test design. The field tests cover both naturally fractured carbonates and layered sandstones.
Two examples of well test interpretation in naturally fractured formations reinforce the conclusions of other authors, namely that well test interpretation based only on 2 parallel semi-log straight lines is questionable in cases with afterflow.
The new analytical solutions refer to stratified and heterogeneous systems with interlayer cross-flow. In both cases after-flow and skin factor are included. It is shown how the type curve can be used in certain long pressure build-ups to gain information on the average reservoir pressure in a stratified system. In the pressure behaviour of a heterogeneous system with interlayer cross-flow, there is often quite a long transition zone before the system behaves like a single reservoir. This requires careful planning of test duration. In particular, the early part of the transition zone, looked at in isolation, may give a false impression of pressure stabilisation, which could lead to the interpretation of small drainage areas or a gross over-estimation of the system permeability.
Porosity Reduction in Sandstone
Authors: Dibble W. E. , Nur Amos , Potter J. M. 
Published: December 2007

ABSTRACT
Porosity reduction in siliceous sedimentary rocks is worthy of detailed study because the processes involved control the final porosity and permeability observed in all oil and gas reservoirs. In addition, porosity reduction and petroleum generation and migration may also be related.
The effects on porosity reduction of the major porosity-controlling variables are virtually unknown and have been the subject of new experimental studies. Cores of St. Peter Sandstone have been subjected to high effective stress at room temperature and with fluid flow occurring at various rates. Relatively rapid pressure solution occurs even at room temperature in a flowing system.
A Graphical Approach to the Quantitative Analysis of Porous Rock and Oil Recoveries Using Capillary Pressure Data
Authors: Vo T. 
Published: December 2007

ABSTRACT
Collection of rock and fluid data in the early stage of development of many oil fields, especially the larger ones, is often considered good practice. In most cases, the collected information is essential for immediate or future applications in various calculations. However, there are times when costly data were acquired with little forethought because the data would not be truly utilized in future field development plans. Typical of these are many capillary pressure reports that were filed years ago, but only used occasionally in the calculation of information such as height above water table and pore radius. The practical values of these terms are so insignificant that they can hardly provide any economic or engineering justification for the collection of the reports.
The lack of usage of these capillary data must have come from the fact that, despite the tremendous amount of literature on the subject, there was not any technique capillary properties to reservoir future performances, under various operational techniques and conditions.
This simple reason has inspired this author's study and, as a result, the proposed method. It is hoped that application of this method could retroactively justify the existence of these "old" capillary reports, and would be used in the future as basis of many more capillary studies.
A Successful Gas-Injection Project in a Heavy Oil Reservoir
Authors: Garcia F. M. 
Published: December 2007

ABSTRACT
Meneven, an affiliate of Petroleos de Venezuela, S.A., has been conducting since 1963 a natural-gas-injection project in a heavy-oil reservoir (14–20 °API), located in Eastern Venezuela, immediately north of the Orinoco Oil Belt.
Laboratory tests were made to investigate recovery mechanisms, and a black-oil simulator was used to match performance history and predict future performance under continued gas injection.
According to the results obtained, the high viscosity (low API gravity) of a reservoir crude is not necessarily a limiting factor in the successful applica tion of conventional gas injection. This unorthodox scheme has proven to be quite successful even in a relatively high oil-gas viscosity ratio reservoir, where cumulative recovery has been 32% of 00IP, and final recovery is estimated at 45% of OOIP.
A Producer's View: If the Investment Climate is Right, Why is Oil Activity Depressed?
Authors: McCall Robert R. 
Published: December 2007

Abstract
Thank you. I'm greatly honored to have this opportunity to speak with fellow engineers at this 58th annual meeting of the S.P.E.
Today, I'd like to discuss three things with you: the outlook for exploration and producing in the United States during the 1980's, the things that we should be doing to shake off the present depressed conditions in the industry, and the role petroleum engineers will play in this scenario.
If the recent past history of drilling rig activity is any indication of the upper and lower limits of enthusiasm within the industry, Any success in forecasting the near term outlook for the exploration and producing side of our business will require as much luck as skill.