bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reservoir Engineering Issues of Horizontal Hole Development
Authors: Niko H. 
Published: December 2007

ABSTRACT
This paper describes important reservoir engineering issues of horizontal hole drilling in primary field development, highlighting the areas of productivity Improvement In tight reservoirs and oil rim development. Factors influencing the productivity improvement over that of vertical wells In tight reservoirs are discussed, e.g. horizontal hole length, permeability anisotropy ratio, well location with respect to areal boundaries, hydraulic fracturing and mechanical skin factor. In the area of oil rim development, a discussion on critical rate models (including one which includes pressure losses In the borehole) Is given for gas/oil systems, whilst also showing how the critical rate concept can be used for production forecasting. Applications of numerical simulation are described for more complex geological models for oil rims with both gas cap and active water drive. Among the factors influencing the production performance of horizontal wells in oil rims, oil mobility, drainage area, vertical well position in the oil rim/strength of water drive, well length, permeability anisotropy ratio or the presence of dipping shale layers are described. Well testing is discussed next as a way of obtaining critical parameters such as permeability anisotropy ratio and mechanical skin. Finally a summary of field applications in areas where Shell has an interest is given.
Reservoir Evaluation of Horizontal Bakken Well Performance on the Southwestern Flank of the Williston Basin
Authors: Reisz M. R. 
Published: December 2007

ABSTRACT
This paper presents the results of a reservoir performance study for horizontal and vertical Bakken wells in the "Fairway" of the Williston Basin. A combination of forecasting methods were utilized, including decline curve analysis, material balance, analytical solutions, and empirical correlations.
The results indicate that recoverable reserves from horizontal wells in the "Fairway" are 2.5 to 3.0 times a vertical well for 1.5 to 2.0 times the cost. Simple theoretical calculations combined with field data are useful in making initial estimates of original oil in place, recoverable reserves, and drainage area.
Application of Foam Fluids To Minimize Damage During Fracturing
Authors: Harris P. C. 
Published: December 2007

ABSTRACT
High quality foam was developed as a premium cost fracturing fluid in the past decade, but many beneficial properties of foam may make it the fluid of choice for hydraulic fracturing in the 1990's.
Foam fluids were first applied to gas reservoirs having low pressure, since gas in the foam expanded after the treatment to remove the fracturing fluid from the well, minimizing damage to the formation. But foams have also been applied to all types of wells, low or high pressure, gas or oil, where it was important to minimize damage. The low liquid content of foams leaves less liquid to remove from the well.
Foam fluids have low fluid loss to the formation. In addition, the gel filtercake which is deposited on the formation face during fracturing is substantially thinner than filter cakes deposited by other fluid types such as crosslinked polymer fluids. Damage to fracture conductivity is minimized.
The two-phase structure of foam fluids allows the generation of high viscosity fluids for fracture propagation, and its yield point characteristics provide enhanced proppant transport. Mathematical relations can calculate the foam composition required for specific applications over a broad range of gas qualities, temperatures, and polymer concentrations.
The development and application of constant internal phase design concepts allow proppant to be added to a foam fluid while maintaining viscosity constant. High proppant concentrations can be carried with constant internal phase foams while minimizing frictional pressure losses.
This paper discusses the relationships of rheology, fluid loss, constant internal phase design, and fluid recovery in application of foam to hydraulic fracturing.
Increasing Arun Well Deliverability Through Effective Acid Fracturing
Authors: Cannan W. L. , Jennings A. R. , Huseini S. , Bordelon T. P. , Sardjono S. 
Published: December 2007

ABSTRACT
The prolific Arun Field in North Sumatra, Indonesia continues to produce substantial amounts of natural gas and condensate. The massive carbonate reef reservoir is beginning to require special measures to maintain deliverability to recover the large quantities of hydrocarbon remaining in the formation. Optimization of production from the Arun will demand combined efforts from Arun geologists, reservoir, production and operations personnel, as well as technical advisors.
Although Arun wells typically produce 40 to 100 MMSCFD/well, many of the wells have positive skins, indicative of near wellbore formation damage. In most of the field, the lower portion of the Arun has less effective permeability than the upper part. In other wells, high permeability zones are interspersed among more massive low permeability intervals. Well stimulation by acid fracturing can be effectively used to remove damage effects (induce a negative skin), provide highly conductive flow channel for improved flow from low permeability intervals and enhance flow from high permeability zones.
Six wells have been successfully stimulated by acid fracturing in the Arun Field. the stimulations and results will be discussed in detail.
Production Logging in a Rod-Pumped Well Using Coiled-Tubing-Conveyed Tools and Nitrogen Gas Lift
Authors: Mason D. L. 
Published: December 2007

ABSTRACT
This paper describes the principles of coiled tubing production logging and describes the first application of this method - on Wytch Farm lA-01BP - and describes the results that were obtained. The well was successfully gas lifted using this method and the technique of coiled tubing production logging was successfully demonstrated.
Petroleum Engineering Teaching Effectiveness With Field Practitioners in Classrooms
Authors: Sharma M. P. , Harris H. G. 
Published: December 2007

Abstract
Engineering educational institutions have a dominant role to play in shaping the future course of energy and mineral industries. When researching and defining the needs for educating engineers for the next century, Gentry (1) has concluded, "we must develop and implement educational experiences, both in the classroom and the research laboratory, that enable students to keep pace with the world and the technological, social, political, and economic initiatives that drive it."
In its "University-Industry-Government (UIG) Partnership for Quality Engineering Personnel" program announcement (2) the National Science Foundation noted three major impediments to maximizing the quality of engineers produced by some of our academic institutions. "One of them being failure to incorporate major elements of engineering practice into engineering curricula". Apparently the incorporation of such a factor in classrooms has been a matter of high importance in the NSF Engineering Infrastructure Development Program office recently. This paper addresses and investigates some of the aspects of such a practice from teaching principles as well as methodology points of view.
There are many ways one can define "Teaching" and still not be satisfied with the completeness and certainty of these definitions. The reason lies in the fact that the process of teaching involves art, science and humans. Madeline Hunter (3) tries to explain nature of teaching very succintly: "Educators have finally arrived at the point that professionals in medicine achieved when the latter discovered that germs and not evil spirits were causing much of the problem. We now know many cause-effect relationships in teaching and learning. As a result, we can use those causal relationships to promote student learning in the same way the doctor uses his medical knowledge to promote health. In both education and medicine we are learning more each day even though there still remains much we don't know."
Development Planning of Seligi Field Offshore Pensinsular Malaysia
Authors: Yong T. O. Aw , Soffian R. M. 
Published: December 2007

ABSTRACT
The Seligi field is the largest oil field in Peninsular Malaysia. Its largest reservoir, the J-18/60 which contains about 47 percent of the field's total original oil-in-place, has a relatively thin oil column (19 to 36 meters) overlain by multiple large gas caps and underlain by an active aquifer system. The sandstone thickness and reservoir quality vary across the field. Three other major oil-bearing reservoirs also have thin oil columns and gas caps. The J-18/60 is being produced via a combination of gas cap expansion and waterdrive mechanisms. Optimum recovery will depend upon proper balancing of crude withdrawals and gas injection. The production strategy is also complicated by the fact that the aquifer underlying the major J-18/60 reservoir is common to other fields which have been on production for several years.
This paper discusses: 1) the reservoir development planning of Seligi, which involved the development of a very large computer simulation model to assist in addressing the numerous complex factors that influence oil recovery and hence development decisions, 2) evaluation of horizontal wells to optimize recovery from the thin oil column and experience in drilling the first horizontal well in the field, and 3) challenges in facilities planning for development of the field.
Comparison of Results From an Advanced Gas Kick Simulator With Surface and Downhole Data From Full Scale Gas Kick Experiments in an Inclined Well
Authors: Rommetveit R. , Vefring E. H. 
Published: December 2007

ABSTRACT
The RF kick simulator is a tool for well control engineering, study and training. The simulator accounts for all important physical effects related to a kick, and models kicks in both water based mud and oil based mud. In order to test the performance of the model, real gas kicks in both water based and oil based mud have been simulated. Surface and downhole data from full scale gas kick experiments have been used to verify the simulator. The data used are downhole annulus pressure data, surface pressures, mud flow rate out, pit gain and gas transport data. The measured gas influx rate into the well versus time has been used as input data to the gas kick simulations.
The conclusion of the comparisons is that the RF kick model reproduces real kick data with acceptable accuracy. This confirms the capability of the RF kick simulator to model gas kicks. The simulator can therefore be used with confidence for the design of well control procedures and the evaluation of kick situations.
Pressure Gauge Specification Considerations in Practical Well Testing
Authors: Veneruso A. F. , Erlig-Economides C. , Petitjean L. 
Published: December 2007

Abstract
This paper addresses the characterization and consequences of non-ideal pressure gauge performance on pressure transient analysis. In practice, pressure measurement instruments can have response errors, including short and long term drift and anelastic relaxation, that can dramatically affect calculation of even the most basic reservoir and wellbore properties such as producibility, permeability, average reservoir pressure, and the wellbore skin factor. Best results are obtained when the pressure gauge is selected with an eye on the intended application because different types of instruments have different response characteristics.
To determine how the pressure gauge affects well test analysis, a transfer function approach is used to characterize the gauge response to changes in wellbore pressure. This model is based upon published specifications, measurement quality controls, and the fundamental physics of commonly-used transducers. This transfer function approach can also be generalized to include temperature response effects as well as the effects of noise and non-ideal gauge electronics and processing.
Specific field examples are given to illustrate how these gauge response errors affect the analysis of pressure buildup tests using the basic Homer approach as well as some of the latest computer regression techniques. Error bounds on the results of reservoir and wellbore parameter analysis are computed using a range of different gauge specifications.
The results of this approach are used to show how to optimize testing performance with cost-effective instrumentation.
Use of Radioactive Isotopes in Gas injection
Authors: Calhoun Tom G. , Tittle Robert M. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
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.

Introduction
Major advances in the measurement of extremely small amounts of radiation make the use of radioactive isotopes as a tracing material in petroleum reservoirs practical. Isotopes, Inc. has developed equipment capable of extremely low level techniques which, together with a number of low cost radioactive isotopes, make possible many useful applications in reservoir engineering.

RADIOISOTOPES AS TRACERS
By introducing radioisotopes in the injection wells with the injected gas it is possible to "tag" the injected gas and, by analyzing produced gas, to trace the movement of the injected fluid throughout the reservoir. Directional permeability may be identified early in the life of the project so that steps can be taken to maximize project so that steps can be taken to maximize recovery efficiency.
The use of tracers to follow movement of gas, oil, or water is not new. Underground tracer work has utilized many materials; among them certain dyes and chemical compounds, helium, and carbon monoxide. The problems are the same in every application:
To get the tracer to behave identically with the material traced To obtain adequate sensitivity To carry out the tracer project at reasonable cost
Differences in adsorption, absorption, wetting, precipitation etc., between the tracer and the precipitation etc., between the tracer and the fluid to be traced cast doubt on the results on many of the earlier tests. These tracers also lacked sufficient sensitivity. Such factors discouraged the use of tracing techniques, even though it has been obvious since the beginning of secondary recovery that an ideal tracer would be useful in almost every operation.
In principle, radioactive isotopes constitute ideal tracers; first, because the fluid itself may be made radioactive, or the tracer can be made a part of the fluid chemically. For instance, tritiated hydrogen acts the same as hydrogen because it is, in fact, a part of the hydrogen molecule. The only difference is that one of the hydrogen atoms in the H2 molecule has been replaced by a tritium atom. Tritium is an isotope of hydrogen, having two extra neutrons in the nucleus. Tritium has a half life of 12.5 years, and low level counting techniques make possible the detection of these isotopes through seven half lives or approximately 85 years. A number of other low cost radioisotopes are available for use in gas injection projects.
Pipe Coupling Techniques for Marine Pipelines
Authors: Thielhelm Harry W. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
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
Over 100 years ago, man conceived the idea of transporting petroleum liquids through pipe and petroleum liquids through pipe and successfully laid a 6 mile long line. Since that time he has solved problems of new materials, met many problems of new materials, met many challenges of terrain, and continually improved and expedited the process of joining two sections of pipe, installing connections and making repairs. Pipelines throughout the world are monuments to his success.
Now a new and difficult problem confronts the designer and pipeliner: the successful installation and operation of offshore pipelines in waters of ever-increasing depths
This paper presents a review of the methods and fittings developed for pipelines on land, discusses their suitability for underwater installations,, and reveals the new methods and fittings prepared specifically for underwater lines.

Introduction
Ever since man conceived the idea of transporting liquids through pipe, he has been confronted with the pipe, he has been confronted with the problems of changing materials and problems of changing materials and site environments, and challenged by pressures to improve and expedite the pressures to improve and expedite the process of joining two tubular process of joining two tubular sections, installing connections, and making repairs.
In 1865, the first petroleum pipeline was connected by screwed pipeline was connected by screwed joints and the general reaction was that a major advance had been made. It was a 2-inch cast iron line, six miles in length, not a big accomplishment by our present day standards but of utmost importance at that time. Since then many developments have been made in pipelaying connections that not only pipelaying connections that not only improved the speed of installation but also the quality, service life, maintenance and repair of completed lines.
Today there are few, if any, nations that are not spanned with a multitude of varied sized lines carrying numerous types of fluids.
An Investigation of the Damaged Zone Created by Perforating
Authors: Pucknell J. K. , Behrmann L. A. 
Published: December 2007

Abstract
Underbalance perforation flow experiments were performed on reservoir and outcrop sandstones to investigate the perforation damaged zone. Cores from several different formations were perforated under reservoir conditions. After perforating, the cores were examined using CAT scans (Computer Aided tomography), thin sections and mercury porosimetry. In conjunction with these measurements, permeabilities in the damaged zone were measured using a mini-permeameter and radial flow permeameter or were estimated from pore size distribution.
The density and porosity of the damaged zone (at least for saturated rocks) is essentially the same as that in the undamaged rock. The damaged zone is not compacted, contrary to suggestions made in earlier work. However, the creation of this zone involves the destruction of large pores. The volume lost from these pores is replaced by microfractures created when rock grains are fractured by penetration of the shaped charge jet. This reduction in the average pore size causes a reduction in the permeability within the damaged zone. Although direct measurement of this permeability was made difficult by naturally occurring permeability variations, unambiguous measurements were obtained.
Based on this work an understanding of the factors which control the permeability in the perforation damaged zone is advanced.
Petrophysical Evaluation Of The Smackover Formation In East Texas
Authors: Ritch H.J. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
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
Significant amounts of hydrocarbons are produced from dolomite and limestone reservoirs produced from dolomite and limestone reservoirs in the Smackover formation in East Texas. The major contributor of these produced volumes and reserves are the dolomites consisting primarily of oomoldic and sucrosic rock types. The oomoldic rock type is the most significant. Predominant limestone rock type is oolitic Predominant limestone rock type is oolitic grainstone. Porosity development is mainly secondary for all rock types. Electrical and acoustical properties are different for the dolomite and limestone lithologies. The residue hydrocarbon trapping characteristics of reservoir quality rock are high as determined by various techniques.

Introduction
The hydrocarbon productive Smackover formation of Jurassic age in East Texas has been and will be a prime exploratory objective for a number of years. The geographical area covered by this paper is shown in Figure 1. The Smackover formation is overlain by the Buckner and underlain by the Norphlet, all of Jurassic age. The Smackover pinches out updip to the north and west of the Talco-Mexia Fault line. Hydrocarbon accumulations appear to be limited downdip by the absence of porosity development. Numerous gas-condensate and oil fields have been discovered with the larger being Bryans Mill, New Hope, Como and Northeast Edgewood. The larger fields have been found in a band almost midway between the updip porosity pinchout and downdip limit of porosity development.
The standard open hole logging program consists of running the induction-electrical and the acoustical velocity surveys. Additional surveys often utilized are natural gamma-ray, gamma-gamma density, neutron (conventional and contact) and microlog surveys. It has been found that for wells drilled with normal water base muds (density 10.0–10.5 pounds per gallon, 8–10 cc fluid loss and 40–50 pounds per gallon, 8–10 cc fluid loss and 40–50 seconds viscosity), filtrate invasion is quite shallow, usually less than two hole diameters.
The first porosity development below the top of the Smackover is normally open hole drill stem tested, particularly in exploratory wells. The objectives of drill stem testing are (1) determine fluid content and (2) rate of fluid production.
In order to efficiently exploit these accumulations, the amount and distribution of the hydrocarbons initially present as well as the most efficient method of recovering these hydrocarbons needs to be known. This paper defines some of the petrophysical parameters used to evaluate the Smackover and points out difficulties not yet resolved.
Heterogeneity in a Complex Turbiditic Reservoir: Impact on Field Development
Authors: Alabert F. G. , Corre B. 
Published: December 2007

ABSTRACT
In a previous paper [1], a geological/geostatistical methodology has been presented to model heterogeneity in a complex turbiditic formation. The methodology is based on geostatistical conditional simulation techniques that allow building 3D models of geological heterogeneity. The next step consists in translating such stochastic models of heterogeneity into models of flow properties for reservoir simulations. The present paper describes the approach that has been followed to achieve that goal. It includes two steps: a first one, to translate the fine grid geological models of heterogeneity generated in [1] into fine grid petrophysical models,a second one, to upscale the fine grid petrophysical models into coarser grids of effective flow parameters for full-field simulations.
The procedure requires precise methods for averaging absolute and relative permeabilities. A new technique for averaging relative permeabilities and capillary pressures is presented.
The procedure is validated by the available dynamical data (well tests and a 25 years production history).
The integrated geological-geostatistical-upscaling strategy described in [1] and in the present paper is shown to be particularly useful to reservoir history matching and monitoring, as well as to evaluate uncertainties on reservoir performances in undrilled areas of the field.