bluuebunny/crossref_metadata_2025_split huggingface dataset:
Modeling Thermal and Pressure Drops for Multiphase Flow in Thermal Horizontal Wells
Authors: Le Gallo Y. L. , Latil M. J. 
Published: December 2007

Abstract
Use of horizontal wells can improve the performance of thermal recovery by steam drive. In most common cases, flow in horizontal wells is turbulent due to high flow rates and thermal effects. The well behavior is then modified during hot water or steam injection and hot oil production. Therefore, accurate wellbore pressure and temperature drop computations are fundamental in the simulation of thermal recovery processes with horizontal wells.
To compute pressure and temperature profiles in horizontal wells, we use multiphase flow models for steam injection and oil production to account, for energy and momentum exchanges with the reservoir.
For steam injection, a two-phase flow model based on Beggs & Brill approach was implemented for pressure drop computations in horizontal wells. This steady state model uses empirical correlations and simplified physics to describe steam, gas and water flow in the well. It is valid over a wide range of temperature, pressure and steam quality conditions. For oil production, a blackoil model based on multiphase flow in pipes was used to compute the pressure profile in horizontal wells. This steady state model is valid for single and multiphase flow over a wide range of experimental conditions. Temperature profile computations in injection and production wells use the same thermal model based on steady stale energy balance for the wells which includes fluid friction energy losses and heat exchange with the reservoir. Pressure and temperature models were integrated to a. 3-D three-phase fully implicit, blackoil and compositional thermal reservoir simulator.
Temperature and pressure drops modify horizontal well performances when applied to a full-field scale steam flooding process. Oil production flowrates and pressure, steam injection flowrates and breakthrough time at production well are altered. A numerical sensitivity analysis presents the influence of the key parameters for horizontal wells.
Analytical Technique for Resolving Frontal Instability in Reservoir Simulation
Authors: Elemo R. O. , Lawal A. S. 
Published: December 2007

ABSTRACT
Frontal instability occurs in every phase of reservoir simulation (water flooding, steam flooding, chemical and carbon dioxide flooding) and in multiphase fluid flow. Whenever saturation front changes with time and spatial distribution, S(x, t), the key issue is usually the resolution of the changes of fractional flow curve with saturation (df/dS). That also implies evaluation of the derivative of relative permeability curves with saturation. An analytical technique is developed to evaluate the required derivatives and the results are used to estimate the recovery of gas displacing oil with changes in mobility ratio. The proposed technique can be accurately used to develop an algorithm for fractional flow curves. The technique is very attractive as a diagnostic tool for inquiring into the necessity for extensive reservoir simulation studies and should enjoy popularity with field engineers.
Bending and Fatigue Characteristics of Pipe Connections for Offshore Pipelines
Authors: Azar Jamal J. , Vincent Price , Ketcham Bruce V. 
Published: December 2007

Abstract
An experimental program has been performed to determine the suitability of various pipe connections for use in offshore pipelines and, more particularly, in lines placed by the controlled catenary method. The types of connections chosen were the welded, the full runout buttress, a special hydril and the 8-round API connections. Test data showed, both in the static and cyclic tests, that the welded connection is superior to the threaded connections; however, considering the severity of the tests, it can also be concluded that the full runout buttress thread is satisfactory for subsea pipeline service.
Introduction
A series of static and cyclic bending tests on four types of pipe connections were conducted to determine their suitability for use in offshore pipelines and, more particularly, in lines placed by the controlled particularly, in lines placed by the controlled catenary method. The pipe specimens chosen for the tests were eight 5/8-in., 0.593-in. wall, 50.87-lb/ft, Grade-B, seamless, schedule 100 line pipe. This particular pipe was selected since standard casing collars could be obtained and this was the size and grade of pipe used in some of the Cook Inlet pipelines. The types of threaded connections chosen were the full runout buttress, a special hydril, and the 8-round API. The standard for comparison purpose was the welded-type connection made according to the same standards as used in the Cook Inlet pipelines. pipelines. In the authors' opinions, the test results as presented in this paper are of significance in the design and selection of pipe connection configuration for use in pipe connection configuration for use in offshore drilling.
TEST DESCRIPTION AND OBJECTIVES
The static bending test was conducted to simulate the bending which might occur in laying pipe by the controlled catenary system should some degree of the tension control on the lines be lost in the laying operation. A test apparatus [Fig. 11 was chosen in which evenly distributed load could be applied to the pipe rather than the conventional system where pipe rather than the conventional system where the specimen supported at each end is bent by point loading at the midpoint. Uniform loading point loading at the midpoint. Uniform loading along the length of the specimen is more representative of the bending to which the pipe, normally, would be exposed in the laying operation.
Uniform loading was achieved by applying the same amount of bending moment to each end of the 20-ft section of pipe with the connection in the middle.
Infill Drilling in Gravity-Dominated WAG Floods, Prudhoe Bay Field, Alaska
Authors: Wilcox T. C. , Polzin M. W. , Kuo S. S. , Saidikowski R. M. , Humphrey K. J. 
Published: December 2007

Abstract
Introduction
This extended abstract describes the use of infill drilling to improve solvent sweep efficiency and EOR recovery in a gravity dominated WAG flood.
Much of the incremental oil recovery in the Prudhoe Bay Miscible Gas Project (PBMGP) is displaced from a relatively small volume of swept reservoir surrounding each WAG injector. Solvent override occurs due to high vertical permeability and the large density difference between solvent and reservoir fluids. Solvent rises to the top of the reservoir or underneath shales, forming cone-shaped swept intervals around WAG injectors (Figure 1).
Vertical sweep by solvent in gravity dominated WAG floods can be improved by increasing the viscous-to-gravity ratio1,2. A higher viscous-to-gravity ratio (HVGR) expands the solvent swept areas around the injection wells before gravity segregation occurs. However, little can be done in the PBMGP to reduce gravity forces, and water and solvent injection rates are currently near the maximum attainable.
Reduced well spacing remains the only viable method to increase viscous-to-gravity ratio. Most of the benefit from reduced well spacing is due to displacing oil from new WAG cones around the new injectors.
A Boundary-Element Algorithm for Modeling 3D Horizontal Well Problems Using 2D Grids
Authors: Koh L. S. , Tiab Djebbar 
Published: December 2007

ABSTRACT
Three-dimensional fluid flow through porous media problems have assumed increased significance and complexity in recent years due to a growing interest in horizontal well applications. Various predictive tools based on analytical and numerical methods have emerged to address such problems. They have various drawbacks. A versatile boundary-element algorithm was developed in this work to provide a viable alternative.
The algorithm is capable of solving transient and steady-state problems in isotropic or anisotropic reservoirs and handling finite reservoirs and finite-radius well(s) of arbitrary geometry. It also allows the prescription of arbitrary combinations of the two common types of boundary conditions (Dirichlet and Neumann). It, can thus be used to solve a wide variety of three-dimensional horizontal well problems in relatively complex situations.
A major advantage is gained due to the need to discretize only the domain boundary and not the domain itself, thus effectively reducing the dimensionality of the problem by one and eliminating grid orientation effects and numerical dispersion. The reduction in problem dimensions allows three-dimensional problems to be modeled using two-dimensional grids.
This paper provides a summary description of the main features of the algorithm. The application of the algorithm is demonstrated using two examples involving horizontal wells.
Using Authoring Languages To Create Interactive Learning Environments
Authors: Walsh J. W. , Powell R. B. 
Published: December 2007

ABSTRACT
Providing technical training is necessary to all companies. Whether the training is for new employees or new material for established employees, the most effective training tools are those that provide "hands-on" experience and immediate feed back. Microcomputers have provided a platform for training programs which allow simulations of physical or mathematical problems. With video and sound capabilities these programs can include realistic pictures and entertaining segments. Programs can be designed primarily to be used by one person or by several people, each working on different aspects of a problem. These teaching tools can also be straight forward going directly through logical steps or be structured to provide decision branches to allow users to investigate how different paths solve a problem. The software can be designed to evaluate solutions by the "correctness" of the result obtained and resources (time and cost) to achieve the given result.
Authoring languages offer programmers an environment for developing a structure of paths for a learning program. Interactive screens are then defined and conditions set to take users along each path. Using an authoring language, programs can be quickly written.
This paper outlines how an authoring language can be used to develop teaching tools. An example is presented showing how a training need goes from suggestion to finished product. The example used is a training program for PLANIMETER, a software program for computing reserves from isopach maps. This program is designed for geologists, petroleum engineers, and technicians. The paper outlines how the learning goals are organized into a program structure. Screens can then be created by a variety of methods: scanning images, creating graphs, and displaying text. The example utilizes Quest, an authoring language from Allen Communications in Salt Lake City, Utah. Once screens aredefined the user response and interface are added. The example will outline the general procedure for developing a learning tool using an authoring language.
Automated Decline-Curve Analysis Using Robust (LAV) Nonlinear Parameter Estimation Under MS-Windows™ 3.X
Authors: Chen Jianping , Prouty J. L. 
Published: December 2007

ABSTRACT
The type curves developed by Fetkovich1 are widely used tools for decline curve analysis. Fetkovich combined the analytical constant pressure infinite (early transient period for finite systems) solutions with the "empirical" exponential, hyperbolic, and harmonic decline curve equations developed by Arps2. There are software applications that have computerized this analysis technique; however, attempts to automate the matching process have been hindered by two problems: (1) a way to identify the transition from one flow period to the next, and (2) a way to minimize the adverse impact of oudiers, data considered to be bad observations. This paper presents methods to handle these issues.
Recognizing the point of transition between flow regimes is sometimes difficult, even when the matching process is done manually. If, however, the curves are regenerated using the proper derivatives of the production, the software can locate the transition simply by looking for a minimum. The process of estimating reservoir parameters is simplified as well.
To handle outliers, this paper proposes a robust algorithm consisting of a nonlinear parameter estimation using Least Absolute Value (LAV) as the criterion for minimization. One advantage of this approach is that it provides a smooth transition between full acceptance and total rejection of a given observation. Oudiers are systematically assigned less weight in the objection function. This method also avoids the computation of a second derivation of the model function. Most importandy, tests have shown that when outliers are introduced into the observations, the LAV algorithm still produces accurate parameter estimates.
The above techniques have been implemented in software that operates in the MS-Windows™ environment With its graphical user interface (GUI), this environment allows for clear visual displays of the matching process and the results. Moreover, it provides the user with many more options than the traditional, non-graphical operating systems. Because programming under MS-Windows is still relatively new to the industry, this paper also discusses some aspects of Windows programming, especially as it relates to petroleum applications.
Intelligent Approach of Rod Pumping Problems
Authors: Alegre Lideniro , Da Rocha A. F. , Morooka C. K. 
Published: December 2007

ABSTRACT
Identification problem (diagnosis) in rod-puinpimg involves both pattern recognition and symbolic reasoning, since dynamometer card provides important information but not all data required for decision making. A surface dynamometer card (SDC) is a record of the load vs. position of the polished rod in rod pumping units. Because of the rod stretch, the SDC cannot generally provide all information needed to understand how the pump is operating downhole. For this purpose, the engineer uses also information about the characteristics of the well, the type of oil being pumped, etc., besides taking into consideration the SDC shape, maximum and minimum load values, etc. A new type of neuron is used to built neural nets having powerful numeric and symbolic processing capabilities, besides permiling knowledge to be encoded not only on the wiring of the net. but also on the selection of the types of neurons and synapsis composing the net. This new type of neural nets was used to develop SICAD, a hierarchical neural system whose purpose is the intelligent control of rod-pumping. SICAD is composed by two famillies of neural nets specialized, respectively, in pattern recognition (PRN) and expert reasoning (ERN). Different modes of interactions between ERN and PRN define different pumping control strategies. The present paper analyses the roles played by PRN, ERN and their interactions. It also discusses the basic conditions under which SICAD may support different end products for an intelligent management of rod-pumping oil
The Development and Implementation of a Drilling Database: A Case Study
Authors: McCammon K. C. , MacKinlay W. M. , Yoder D. L. 
Published: December 2007

ABSTRACT
Conoco has been using a drilling database to track costs and optimize operations for the past 5 years. This paper discusses the evolution of the database, field and office implementation, system usage and features, and the current impressions and future plans for the system. It also provides recommended guidelines based on Conoco's experience.
Drilling cost reduction has become increasingly important in today's economy. Key factors in reducing drilling costs are optimizing operations, benchmarking, and utilizing manpower to its fullest potential. Before decisions affecting performance are made, information needs to be gathered and analyzed in an efficient manner. A database combined with engineering analysis programs can provide the tools necessary to quickly perform the advanced analysis that is vital to compete in the current economic environment.
To accomplish these objectives, Conoco has been using a drilling database system worldwide for several years. Work on the database system was initiated in 1988 as a joint development effort between Conoco and DRD Corporation. The system has developed into a database system that captures a broad scope of drilling information and generates a wide range of reports and graphics to assist in the optimization of drilling operations.
Downsizing the Safe System to the Client/Server Model
Authors: Crump J. J. , Hobi J. A. , Montgomery E. W. , O’Gorman T. P. 
Published: December 2007

ABSTRACT
Shell has successfully downsized a database that records and reports health and safety events for employees, moving it to a microcomputer-based client / server environment. It was enhanced to handle any kind of HS&E event involving employees, contractors, and other people. This paper highlights evaluation of alternative platforms, system development, and initial operations.
Optimal Scheduling for Cyclic Steam Injection Projects
Authors: Curry Guy L. , Chang Gordon Y.K. , Harper Ronald G. 
Published: December 2007

Abstract
In this article, a well steam injection scheduling model which maximizes the profit per day for oil production leases is discussed. The model can be used to produce operating resteaming schedules and to evaluate the profitability for any number of steam profitability for any number of steam generators. There are no limitations on the size of the problem which can be handled by this approach exclusive of computer storage capability and run time.
The model consists of nonlinear regressing nonlinear optimization and a scheduling algorithm. Weekly well production data from a production reporting system is utilized to production reporting system is utilized to extend the system to a reporting, operating control and planning system that not only provides management with production history provides management with production history but analysis tools for better decisions as well.
Introduction
Within the past few years, there has been considerable interest shown in the application of thermal recovery processes. Cyclic steam injection has been the most frequent and successful process applied to thermal recovery programs. This process consists of injecting programs. This process consists of injecting varying quantities of steam into a well for varying periods of time. The object of the process is to increase the production rate of process is to increase the production rate of a well for a given time period, or to extend the total production life of the well. Either or both of these two activities can have a sizable impact upon the profitability of the lease.
In addition to the problem of determining the quantity and duration of steam injection, the engineer is concerned with calculating the optimal cycle schedule and number of steam generators required for a lease. This article discusses a method for optimizing the profit from cyclic steaming operations. The objective of the method is to develop a practical model which solves the scheduling problem with little effort, on the part of the engineer involved. The model combines an optimization procedure, a scheduling procedure and a curve-fitting program into a computerized system which produces program into a computerized system which produces the desired schedule without manual intervention. The model will curve fit and plot the well production response curves,, find the optimal production response curves,, find the optimal recycle times and produce a schedule for steaming all wells over a given planning horizon. The model can also be used to evaluate the optimal number of steamers for a given set of wells taking into consideration steamer utilization factors.
Regulations for the Control of NORM
Authors: Gray P. R. 
Published: December 2007

ABSTRACT
Responding to the public's concern over radioactive contamination, the perceived need to protect the health of employees, the public, and the environment, and the need to control the spread of contaminated materials into commerce and unrestricted areas, have led regulatory agencies, both state and federal, to develop regulations for the control of NORM.
As a result, regulations for the control of NORM are being developed at an increasing pace by the petroleum producing states. At the present time, Louisiana, Mississippi, and Arkansas are the only states with NORM regulations in effect, but several others, including Texas, Alabama, Kentucky, New Mexico, and Oklahoma could have their regulations in effect during 1993. It is expected that the majority of the petroleum producing states will have regulations within two to three years.
The federal government is also considering regulations for the control of NORM, and it is probable that the Environmental Protection Agency will develop federal regulations for NORM control. Some of the Canadian provinces, e.g., British Columbia, Alberta, and Saskatchewan, will also have NORM regulations shortly.
There is still some controversy over acceptable exemption levels for radium. More data, particularly accurate measurements of radon emanation rates and better risk assessments for NORM exposures, are needed. The impact of the regulations on the petroleum industry will be very costly and will require some changes in operating procedures.
In-Place Purchases Of Gas Reserves
Authors: Jacobs John C. 
Published: December 2007

1962 Economic and Valution Symposium, Dallas, March 15–16, 1962

Introduction
In this paper the term "in-place purchase" of natural gas shall mean the purchase of a developed natural gas productive property by a pipeline company for cash plus a series of installment payments. As such, in-place purchases are but one facet of the larger problem of obtaining a gas supply for interstate pipeline systems. This one facet represents a small but important part of obtaining gas supply, and a generally misunderstood part. This paper is designed to show what in-place purchases are, what in-place purchases are not, and the position of in-place purchases in the larger scheme which is our natural gas industry. This description will be oriented from the general point of view of the problem of obtaining gas supply for an interstate pipeline system, and the effect of the various solutions of this problem upon the parties involved. The paper emphasizes the practical experience gained from participating in the day-to-day gas buying market, as opposed to theories.*
First, what is the gas supply responsibility? Fig. 1 shows the reason for our interstate pipeline system. Gas reserves are concentrated in the Texas-Louisiana area, whereas markets are concentrated in the Northeastern, North Central and Pacific Coast States. The interstate gas pipeline industry has developed, in the large part during the last two decades, to provide a means of moving gas from the areas of concentrated reserves to the areas of concentrated markets as shown in Fig. 2. As shown in Fig. 3, which covers all gas marketed in the United States-intrastate as well as interstate-the gas industry is a sizeable industry; one with a rapid rate of growth; and one in which considerable future growth is expected. Note also that this is an industry of large numbers. For example, the 13 trillion cu ft of gas marketed in 1961 at an approximate average cost of 14 cents/Mcf in the field represents a dollar outlay of $1,820,000,-000. The reserves representing this annual sale, if a 20-year supply and the same unit cost is assumed, would represent a dollar value of $36,400,000,000. Consequently in discussing gas supply, we are at one place-in addition to the federal government-where it cannot be said that $1 billion is an impressively large number.
In this era of growth the obtaining of new gas supply is almost entirely for pipeline expansions. Not only are large quantities of gas required, as shown in Fig. 3, but the problem is complicated by competition, Federal Power Commission control of field prices, Natural Gas Act standards regarding the expansion of pipeline systems, and the large number of parties which must be satisfied in any practical solution to a gas supply problem.
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