bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Modification of Carter's Equation for Fracture Area
Authors: Pattillo Phillip D. 
Published: December 2007

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

Abstract
The classic equation developed by R. D. Carter for the area of a hydraulic fracture assumes the width of the fracture to be everywhere uniform. The present work represents a modification of Carter's equation for the case of non-uniform width that is a function of the time that the fracture reaches a given location. An assumed form of the width function is then employed to compare the results of this paper with Carter's original work. paper with Carter's original work

Introduction
In 1957, R. D. Carter derived the classic equation for the area of a hydraulic fracture as a function of a uniform average width, fluid injection rate at the wellbore, the fluid loss rate into the formation, and elapsed time. The explicit form of the solution of Carter's equation will depend on the functional representation of the fluid loss. Due to the complexity of solving Carter's equation for some functional forms of the fluid loss, other workers abandoned this more general relation in favor of methods whereby the fluid loss function is applied directly to a particular fracture geometry.
One parameter in Carter's equation that has received only minor attention is the width which is assumed to be uniform throughout the fracture. In general, the fracture width is a function of the fracture plane spacial coordinates and time. The purpose of this study is to investigate the consequences of assuming that the fracture width at a generic point in the fracture plane is a function of time only. This assumption results in a modified form of Carter's equation which will then be compared to the original work and two of its variations in the literature.

DERIVATION OF BALANCE EQUATION
Let the x-y plane be the fracture plane (Fig. 1-a). With respect to fracture geometry, assume thatThe fracture width is symmetric with respect to the x-y plane.Concerning the loss of fracturing fluid to the formation, the assumptions of this work are tantamount to the assumptions made by Carter.Fluid flow into the formation is linear and normal to the surface of the fracture at a generic point.
Huge Change in Deep Reservoirs Development Strategy using High Angle Wells. El Furrial Field. Venezuela.
Authors: Gil R Jose A. , Colombine Willie , Rodriguez Pavel 
Published: December 2007

Abstract
El Furrial field is located 18 miles west from Maturin city, in eastern Venezuela (Fig. 1). It was discovered in June 1986 by FUL-1 well which produced initially 7000 barrel/day 28°API oil. The El Furrial structure is a giant faulted anticline oriented NE-SW. The depositional sands of Cretaceous to Oligocene age which are 1500 feet thick were encountered below 12500 feet. The Naricual formation is the main reservoir in El Furrial field.
The STOOIP is 6880 MMBls. The reservoir has a porosity of 13 % and its permeability ranges from 100 md to 1300 md. The reservoir pressure declined rapidly during initial development. The lack of natural pressure support was due to the sealing by a Tarmat Layer underneath the Naricual formation. A pressure maintenance project using peripheral water injection was initiated in 1992 in order to keep the pressure above the asphaltene flocculation point, which is about 6500 psi. It would also increase the recovery factor from 13% under natural depletion to 27% under water injection. Crestal Miscible Gas injection started in August 1998 with the aim to further increase the oil recovery. Currently some 550 MBWD water and 300 MMCFD gas are being injected. Drilling and completion strategies have changed with time from vertical wells with dual completions to (highly) deviated wells completed with a single production string.
The new development strategy focused on drilling high angle wells as a way to maximize the oil recovery at reduced cost. An evaluation had shown that high angle wells could be capable of producing up to 20000 BOPD. These wells would delay water and gas breakthrough, increase cumulative reserves per well, reduce operating costs, avoid local pressure sinks and have a positive environmental impact. Four high angle wells have been drilled in the Naricual Formation up to now. The operational problems have been well studied and the learning curve has resulted in further optimization.
This paper describes the well planning, the optimum well design, the results and the experience gained in the drilling of four deep high angle wells in El Furrial field.
Laboratory Observations of Gravel Placement Techniques
Authors: Novonty Rudolf J. , Matson Ronald P. 
Published: December 2007

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

Abstract
In order to better understand past problems and experiences in field applications of problems and experiences in field applications of gravel-packing treatments, a field-size acrylic well model was constructed. This model was used to examine visually the placement of gravel outside the perforations and inside the annulus between the liner and casing. The results and observations were correlated with previous field experience in Louisiana and previous field experience in Louisiana and California. These studies can be broken down into five major areas of interest.The effect of slurry density and viscosity on fluid displacement.Pad design.Sand transport through perforation tunnels.Sand dehydration and node formation.Rathole design.
Different treatment parameters were studied, including the effects of viscosity, sand concentration, method of application, hole condition, and deviation. Both low-viscosity fluids carrying low concentrations of gravel and high-viscosity fluids carrying high concentrations of gravel were evaluated. As a result of the observations presented in this paper, the engineer can gather new insights on paper, the engineer can gather new insights on treatment performance and pack stability. Therefore, these studies should lead to better future job designs and application techniques.

Introduction
The principles of gravel packing are based on the theory of sand bridging to create a highly permeable filter of gravel between the sand producing formation and production equipment. Gravel-placement techniques have evolved through the years from simply dumping gravel down the wellbore to pumping gravel through very sophisticated tools, port collars, and combination packers. Prior to the late 1960's, the fluids used for gravel placement were salt water, low-viscosity crudes, and muds. The use of low-viscosity fluids meant the placement of gravel had to be accomplished placement of gravel had to be accomplished using high pump rates (3 to 6 bbl/min) and low gravel concentrations (1/4 to 1/2 lb/gal). This combination was necessary to prevent the gravel from bridging in tubing or in gravel-packing tools. To improve the success and productivity of a gravel pack during this period, emphasis was placed on improved completion techniques, i.e., filtered fluids, perforating, and gravel sizing.
Alum-Non Ionic Surfactant Combination: an Effective Demulsifier
Authors: Bhattacharya S.N. , Ramana P.V. , Singh Kulwant 
Published: December 2007

Introduction
Oil field emulsions are a problem all over the world. It is well established that the stability of these emulsions depends upon the properties of the crude oil and water and production techniques employed. production techniques employed. The common methods in vague in petroleum industry for demulsification are thermal, chemical and electrical on their combinations. Though the literature on this subject refers to the use of inorganic salts like lime, calcium chloride, ferrous sulfate, etc., Kalichevsky and Kobe have indicated the futility of these compounds for demulsifications.
The present practice, however, is to use high molecular weight organic surface active agents of ionic or non-ionic nature for this purpose in conjunction with thermal and electrical methods. Stassner has reported the pH control as an effective aid in the process of demulsification.
Most of the emulsions usually respond to one of these methods or their combination. While working with one of the emulsions of North Gujarat (India) fields, it is observed that none of the above methods has been effective.
A Two-Phase Coning Model Using Alternating Direction Galerkin Procedure
Authors: Kebaili A.L. , Thomas G.W. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
THIS PAPER IS SUBJECT TO CORRECTION

Abstract
This study presents a development of an Alternating Direction Galerkin (ADG) method following some theoretical work of Douglas and Dupont. The technique is applied to the construction of a two-phase coning simulator in cylindrical coordinates. Solutions are approximated in smooth bicubic Hermite subspaces. The non-linear coefficients in the differential equations are interpolated into a Hermite subspace with a mesh three times finer than the solution mesh. This interpolation scheme provides an order of accuracy consistent with and as high as that of the method of solution. Also it makes a substantial reduction in computer time. A novel method has been devised to simplify the notation and programming effort compared to work previous done in this area. In addition, a permutation matrix is employed to bring the matrix problem for each sweep into a simpler consistent form such that a block solution technique can be readily applied.
Finally, some computational results for hypothetical coning problems are presented and discussed. These are compared to those problems are presented and discussed. These are compared to those obtained from a non-alternating Galerkin formulation and comparable finite difference model.

Introduction
For the past two decades reservoir engineers have been confronted with the problem of describing and predicting reservoir behavior. The lack of analytical solutions to the partial differential equations generated by such problems, along with recent advances in high speed electronic computers, has led to numerical methods using finite difference techniques. Despite the relative success of these methods, it was soon discovered that not all problems are adequately amenable to such treatment. Certain reservoir phenomena involving sudden changes in the dependent variables are poorly simulated by finite difference techniques. For example, to describe the zone of rapid change occurring in Buckley-Leverett type displacement, one must resort to excessive grid refinement. Computation of pressure and saturation distributions around wellbores must be approached in the same manner. The main drawback is that only discrete solutions in time and space are obtained by finite difference methods. Furthermore, these techniques are frequently limited by stability and convergence considerations.
Because of these problems attention has shifted to numerical methods which do not require spatial discretization of derivatives. Galerkin's method is one of these. Combined with piecewise polynomial approximations, Galerkin's process yields results polynomial approximations, Galerkin's process yields results superior, to those obtained by the finite difference technique.
Numerical Solution of Slightly Compressible Single Phase Transient Flow Problems by Spline Functions
Authors: Dogru A.H. , Alexander W.C. , Panton R.L. 
Published: December 2007

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

Abstract
Two dimensional spline functions were utilized in the solution of the linear diffusion equation both with and without a sink within the domain. A collocation method of solution was used and several types of spline representations were investigated. Results were compared with finite difference solutions and with the analytical solutions. B-splines with an extended region of definition were concluded to be superior. For problems with a sink the B-splines alone were not accurate, however, supplementing the splines with a log term produced very good results.

Introduction
In engineering design, ship builders and others often use a spline, an elastic ruler which can be bent so that it passes through a given set of points. Under certain assumptions the curve can be approximately described as being built up of different third degree polynomials (cubic polynomials) in such a way polynomials (cubic polynomials) in such a way that the function and its first two derivatives are everywhere continuous. The third derivative however, can have discontinuities at the given points. Such a function is called cubic spline.
In recent years, spline functions have found wide applications in approximation theory, data fitting, interpolation and so on 4, 9, 15, 16, 17. A smaller amount of work has been devoted to the solution of ordinary and partial differential equations. partial differential equations. Application of spline functions in reservoir problems was initiated by Culham and Varga. problems was initiated by Culham and Varga. These authors used spline functions to approximate the space derivative in a one dimensional nonlinear parabolic partial differential equation which describes the real gas flow in a porous media. The time derivative, however, was approximated by means of various finite difference schemes. They employed Galarkin's and some non-Galarkin type methods to obtain the solutions. Cubic spline basis functions were recommended as the optimum choice for a single-phase flow.
When a spline function is used to approximate the solution of a differential equation, two different methods may be used to eliminate the space dependency. These are namely, Galarkin's method (or Integral Methods) and collocation method. Comparisons of these two different solution methods were made by Panton and Salle on a one dimensional heat Panton and Salle on a one dimensional heat conduction equation. They reported that integral methods give higher accuracy in the solution but programming is quite laborous.
Numerical Simulation of Temperature Profiles and Oil Production During Dry or Wet In -Situ Combustion for an Inverted 5-Spot Pattern
Authors: Chien Sze-Foo , Shum Yick-Mow , Korstad Ralph J. 
Published: December 2007

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

Abstract
A numerical simulation is developed to determine the temperature profiles and oil production for an inverted 5-spot pattern subjected to dry or wet in situ combustion. The basic equations required for the simulation are derived and discussed. The simulation takes into consideration the heat of combustion, the reservoir heat capacity, the conduction and convection of heat through the reservoir, and the conduction of heat between the reservoir and the cap and base rocks. Oil production is calculated through the use of the temperature-oil saturation relationships, a production delay factor and a well-capturing factor.
Examples of temperature profiles and oil production for the dry and wet combustion processes are presented. The features of the temperature profiles produced from the simulation appear to produced from the simulation appear to be in agreement with those reported by others in the literature. For the same injection rate of steam or water simultaneously with air there is not much difference in the temperature profiles ahead of the combustion front. However, behind the front there is definitely a better utilization of heat (i.e., heat scavenging effect) in the case of water injection.

Introduction
In situ combustion is one of the promising techniques for the recovery of promising techniques for the recovery of heavy oil. With this process, air is injected into the formation to burn a part of the oil in-place. Heat part of the oil in-place. Heat generated by combustion is used to heat up the formation and its contents. The increase in temperature reduces the oil viscosity and thus increases its mobility. Ahead of the combustion front, the formation water is vaporized and together with water generated by combustion produces a steam zone. Further ahead, this steam condenses and produces a hot condensate zone. Hence, the in situ combustion process includes both steam and water flooding mechanisms.
Many processes for in situ combustion have been studied and reported in the literature. Among these are forward combustion, reverse combustions and wet combustion.
Land Subsidence as a Result of Natural Gas Extraction in the Province of Groningen
Authors: Schoonbeek J.B. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the SPE-European Spring Meeting 1976 of the Society of Petroleum Engineers of AIME, held in Amsterdam, The Netherlands, April 8–9, 1976. 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 publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor 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
When the size of the Groningen gas field was recognised, it was realised that substantial subsidence might occur at the surface. Intensive studies were initiated to predict future subsidence and measuring systems were developed. In 1971 N(ederlandse) A(ardolie) M(aatschappij) published subsidence prognoses up to the final production stage of the field, where a maximum subsidence of approximately 1 m was predicted. From the various measurements in and over the field it has been proved that subsidence indeed takes place, however, at a degree which is considerably less than predicted.
After refinement of the original mathematical model and incorporating the latest field information, such as updated geological interpretation and the pressure distribution in the reservoir rock, the calculated spatial distribution of subsidence has proved to correspond well with that obtained from actual levelling surveys.
Based on subsidence/pressure behaviour in time and on geological considerations it is concluded that the compaction measurements in the laboratory are not representative for the reservoir in-situ.
An excellent history match could be obtained for the subsidence behaviour so far. Prognoses based on this history match now Prognoses based on this history match now result in a figure of 30 cm for the final maximum subsidence.

Introduction
The Groningen gas field in the Netherlands was discovered in 1959, but its large size was not recognised until 1963. The field is now known to extend over an area of approximately 900 km2. The sandstone reservoir belongs to the Permian Rotliegend formation. Its depth of burial is approximately 2900 m. The gross thickness increases from 70 m in the south to 240 m at the northern boundary. The in-situ weighted average well porosity ranges from 16 to 20 percent, the permeability from 0, 1 mD to percent, the permeability from 0, 1 mD to a few Darcies.
Fluidization in Pipeline Burial
Authors: Boom J. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the SPE-European Spring Meeting 1976 of the Society of Petroleum Engineers of AIME, held in Amsterdam, The Netherlands, April 8–9, 1976. 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 publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor 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.
Content;AbstractIntroductionFluidisationExperiencesDevelopmentsConclusion

1. Abstract.
In recent years the application of high-pressure jets, sometimes used in conjunction with suction-dredging, has been developed into a useful tool for underwater trenching for pipeline burial. In soils with little or no cohesion the trench will be apt to fall in after passage of the apparatus. This prevents the pipe from reaching the desired depth, even after several runs over the pipeline. To overcome this difficulty, Shell have investigated the use of fluidisation in their Rijswijk laboratory. Hanab, a company of the Stevin Group, made the first experimental application of the principle in 1971. Since then approx. 60 km pipeline, ranging from 4" to 36", has been buried. The cover reached in one single run varies from 1 m to 4,5 m. The paper described the experience gained so far with this new method.

2. Introduction
In recent years equipment is being designed and built for the burial of pipelines lying under water. In general, pipelines lying under water. In general, these machines constist of a U-shaped frame hanging over the pipeline provided with mechanical means or high pressure water jets to cut the soil next to and under the pipeline.