bluuebunny/crossref_metadata_2025_split huggingface dataset:
Higher Order Flux Update Function Method for Reduction of Numerical Dispersion and Grid Orientation Effect in Reservoir Simulation
Authors: Shin D. , Merchant A. R. 
Published: June 2014

Abstract
Reservoir simulators have become one of the valuable tools which allow petroleum engineers to answer many important questions arising in the studies of petroleum recovery. They are the products of evolution over several decades and the technology is quite matured. There still exist some shortcomings, however. The most significant among them include:
1 In an unfavorable mobility ratio piston-type displacement, the oil recovery is dependent upon the grid system employed, 2 The error caused by the numerical dispersion inherent to low order numerical schemes can be significant in some cases.
Much work has been done in the past to alleviate these problems. Since the literature is quite extensive, we will not attempt to review all of it here.
The grid orientation effect was first reported by Todd et al.1 and confirmed later by Coats et al.2 Yanosik and McCracken3 proposed a nine-point scheme which has been proved to be effective in alleviating the grid orientation effect for some problems.
Temperature Distributions Along Propagating Leak-Off Dominated, Hot Water- or Steam-Induced Fractures
Authors: Boone Thomas J. , Bharatha S. 
Published: June 2014

ABSTRACT
Commonly in thermal operations, steam is injected into a reservoir at pressures which cause the formation to fracture. As steam flows along the fracture, heat is lost by conduction into the fracture walls which may cause the steam to condense. A portion of the injected mass leaks off to the formation which contributes to convective heat losses. The purpose of this paper is to provide new insight into the relationship between heat and fluid transport through steam-induced fractures when injecting into oil sands reservoirs.
The developments in this work build on the models of: (1) Carter for leak-off dominated fractures; and (2) Marx and Langenheim for steam injection into a reservoir. First, a solution is developed for the temperature profile along a leak-off dominated fracture with hot water being injected at a constant rate and temperature, assuming heat-loss by conduction only. The solution is self-similar in that it is referenced to the current fracture area and is, therefore, independent of time. The solution is then extended to show that the more realistic case which includes convective heat losses is bounded by two self-similar solutions. Finally, assumptions which allow extension of the model to steam injection are described.
It is shown that the material parameters, including the formation's permeability, pressure diffusivity, thermal conductivity and thermal diffusivity, combine in one parameter which characterizes the solution for the injection of hot water. In practice, variation in the permeability is probably the largest single variable. The results also demonstrate and quantify regimes where heat loss from the fracture is dominated by either conduction or convection, along with a transition region.
A Direct IMPES-type Volume Balance Technique for Adaptive Implicit Steam Models
Authors: Farkas Éva , Valkó Péter 
Published: June 2014

ABSTRACT
In this paper an IMPES-type thermal volume balance technique is presented applying a direct solution of the set of mass and energy conservation equations. The effect of the convective energy transport can be considered m the isothermal pressure (volume balance) equation by a modification of the coefficients. The solution yields the pressure implicitly, component masses and energy explicitly (IMPEME technique) while keeping the mass, and energy balances. The explicit treatment demands timestep limitation. Volume balance errors are used to control timesteps. Compared with the direct isothermal volume balance approach, significant volume balance errors occur only at the front and at well regions. This is the portion of the reservoir in an adaptive implicit method (AIM) where the fully implicit handling is used. The IMPEME method is proposed to be the explicit approximation of a thermal AIM. The method can also be incorporated in black oil or compositional isothermal volume balance models to include thermal effects.
Novel Approaches to the Determination of Archie Parameters II: Fuzzy Regression Analysis
Authors: Chen H. C. , Fang J. H. , Kortright M. E. , Chen D. S. 
Published: June 2014

SUMMARY
Fuzzy regression provides a means for fitting data when the relationship between the independent and dependent variables is vague, or data are imprecise, or the amount of data is insufficient. In this paper, we use it to determine the three parameters of the Archie equation from core resistivity measurements. First, we outline the methodology of fuzzy regression analysis. Next, we show the minimization of a fuzzy objective function by making use of the simplex method described in the previous paper. Last, we illustrate the approach with the same data sets used in the previous paper.
Development and Acceptance Testing of a Flush Joint Casing Connection with Improved Performance Properties
Authors: E. F. Klementich P. E. , Morey S. C. , Payne M. L. , Asbill W. T. , Banker E. , Bouche J. K. 
Published: June 2014

Abstract
A flush OD integral casing connector, with an 80% tension efficiency was successfully designed, developed, and laboratory tested to criteria generally accepted as an industry standard. The results show this connector approaches both geometric and performance transparency. Namely, it has the same OD and effective ID as the pipe body and the same pressure rating in burst and collapse as the API pipe body rating. Also, it is almost as strong in tension and compression as the pipe body. Connections with these characteristics permit the use of well plans which conserve hole diameter, thereby reducing drilling and pipe costs without compromising well integrity or safety.
Developing a Process Safety Management Plan for Production Facilities and Gas Plants
Authors: Arnold K. E. , Thro M. E. 
Published: June 2014

Abstract
The paper describes a Process Safety Management (PSM) Plan to satisfy the requirements of OSHA 1910.119 for onshore production facilities and proposed MMS requirements for offshore operations. The information presented will help operators better understand the requirements as they apply to producing facilities and gas plants, and develop a plan to meet these requirements.
Experimental Investigation of Cresting and Critical Flow Rate of Horizontal Wells
Authors: Aulie Tove , Grødal Evert , Asheim Harald , Oudeman Piet 
Published: June 2014

ABSTRACT
Cresting towards horizontal wells with bottom water drive and edge water drive has been experimentally investigated using a laboratory model. For bottom water drive the experimental results are compared with two models for transient crestal behavior. The range of applicability for critical rate estimates by the analytic model is found.
For edge water drive the model developed predicts the measured steady-state supercritical production performance over a wide range of flow rates. As a consequence of the model and experimental results follows that by increasing the total production, net oil rates much above the critical may be obtained.
The Approach to Passive Fire Protection Design for the North Everest and Lomond Platforms
Authors: Krisa T. E. , Cottingham O. F. , Medonos Sava , Prager Jacob , Yasseri S. F. 
Published: June 2014

Abstract
Traditional methods of determining the extent and thickness of passive fire protection (PFP) on offshore platform structures are simplistic and provide little opportunity for design optimization. This paper presents a review of alternative methods of determining the use of PFP which have been tried to overcome these disadvantages. The method progressed and used for North Everest and Lomond was based upon the modeling of credible fire scenarios, the calculation of steel temperatures and the progressive collapse analysis of topsides structure under rising temperature. The selected method allowed the design engineer to optimize the use of PFP while instilling confidence that the design met specified safety objectives.
Deriving Reservoir Pore-Volume Compressibility From Well Logs
Authors: Khatchikian Alberto 
Published: June 2014

Abstract
The bulk compressibility of porous rocks computed from the compressional and shear slowness and the bulk density from well logs using standard dynamic moduli formulas is not the equivalent of the static compressibility measured in the laboratory under hydrostatic load because of fluid stiffness effects predicted by the Biot-Gassman-Domenico model and the fact that the reservoir is under uniaxial rather than hydrostatic stress.
The method described in this paper derives a dry bulk compressibility from the "wet" dynamic value using the Gassman equation and reservoir parameters evaluated through log analysis. The pore-volume compressibility is then computed from the bulk and matrix compressibilities and the porosity. As this compressibility is obtained from sonic log velocities measured under uniaxial conditions of stress, field experience and laboratory measurements suggest that it is equivalent to the uniaxial compressibility, which is between one half and one-third of the hydrostatic-load value.
Application of this method to a consolidated sandstone and an unconsolidated sandstone/conglomerate compare favorably with pore compressibilities measured on cores, after conversion from hydrostatic to uniaxial stress conditions.
Modeling and Analyzing Pressure Buildup Data Affected by Phase Redistribution in the Weilbore
Authors: Xiao J. J. , Fuentes-N F. A. , Alhanati F. , Reynolds A. C. 
Published: June 2014

Abstract
This work describes the development of a simple mechanistic model to predict the effect that the transient two-phase flow of oil and gas has on pressure buildup data. Results from the model provide an improved physical understanding of the phase segregation process and how it influences buildup pressure data. The model is applied to obtain new physical insights into the variable wellbore storage models applied previously in pressure transient analysis.
Field Data Demonstrate Improved Mud Removal Techniques Lead to Successful Cement Jobs
Authors: Kelessidis V. C. , Guillot D. J. , Rafferty R. , Borriello G. , Merlo A. 
Published: June 2014

Abstract
Downhole zonal isolation requires the efficient removal of mud from the annulus and its replacement by competent cement. While good cementing practices have been developed over the years the results are not always satisfactory mainly because the techniques for mud removal are not optimized. Improved mud removal techniques have recently been developed which take into account quantitatively most of the parameters affecting mud displacement and cement placement. Application of these techniques has lead to considerable successes in the field. This paper provides further evidence of the effectiveness of these techniques by presenting the results of a field campaign.
The Influence of Heterogeneities on Well Test Pressure Response - A Sensitivity Analysis
Authors: Savioli G. B. , Bidner M. S. , Jacovkis P. M. 
Published: June 2014

AbstractIn the last decade many efforts have been devoted to obtain a more reliable prediction of reservoir behavior by including in the numerical simulators a better characterization of rock heterogeneities. In this paper we study the influence of permeability and porosity spatial variations on well test pressure response. With this aim, a numerical simulator of the oil flow towards a well, which includes radial variations of both properties, is applied. Field and synthetic data are analyzed. Heterogeneities are statistically characterized. Besides, constant estimates of permeability and porosity from well test pressure data are determined by applying a non-linear regression technique. We conclude that porosity may be considered constant in well test analysis while permeability variations must be taken into account, because they strongly affect pressure response. Power transformed permeabilities do not always follow a normal behavior; in fact, our field permeability data are better represented by an exponential distribution function.
EOR Polymer Screening for an Oil Field With High Salinity Brines
Authors: Leveratto M. A. , Lauri J. , Sanz C. , Sigal J. , Ali S. M. Farouq 
Published: June 2014

Abstract
Ten Polyacrylamides of different molecular weight and in different forms (powder, broth, emulsions) and three biopolymers were tested in order to evaluate their suitability for a EOR project in Catriel Oeste oil field in Rio Neg4ro province, with very high water salinity.
Screening involved: a) Resistance (RF) and Residual Resistance Factor (RRF) through fritted glass filters and viscosity measurement of solutions with different polymer concentrations, b) RF and RRF in actual pay zones cores with the selected polymers, c) ageing test at reservoir temperature, d) and oil recovery flood tests with final selected poliacrylamide.
Laboratory tests allowed a suitable Polyacrylamide to be selected and an optimal concentration of the solutions to be injected in the field chosen, which have been used for pilot test simulation and detailed design.
RF in actual cores gave satisfactory results.
A General Formulation of Linearization Methods Used In Reservoir Simulation with Applications to Adaptive Implicit Methods
Authors: Rodriguez Fernando , Bonet-Cunha Luciane 
Published: June 2014

Abstract
A general method to solve the set of nonlinear difference equations for multiphase flow in a reservoir is presented in this paper. Newton's method, applied to the fully implicit, FI, flow difference equations, is considered the general method from which classical formulations, IMPES, SS, SEQ, LSI, SI, are obtained in a systematic approach.
It is demonstrated, by decomposing the Jacobian matrix of the Fully Implicit method into a summation of matrices, [J]FI = [T] + [T′]p,S + [Pc′]+ [γ]p,S + [q′]p,S + [(ϕbS′)], that the Jacobian matrix of any formulation is a particular form of [J]FI. The level of implicitness of each method becomes evident from its Jacobian matrix composition, IMPES method possess the lowest implicitness, [J]IMPES = [T] + [(ϕbS′)], and Jacobians for any other formulation can be obtained by adding to [J]IMPES proper matrices taken from [J]FI.
The general method here presented is used to formulate an Adaptive Implicit Method, AIM. Corrections for implicitness are applied locally, at a gridblock level. Details of this procedure are discussed, along with the main points to consider when developing an AIM simulator.
A Semi-Implicit Formulation for Compositional Reservoir Simulation
Authors: Branco Celso M. , Rodriguez Fernando 
Published: June 2014

AbstractA new semi-implicit formulation to solve the set of nonlinear difference equations that describe multiphase compositional flow in a reservoir is presented in this paper. Newton's method is applied on the nonlinear difference equations obtained after treating compositions in the flow terms explicitly, one iteration behind.The linearized system of equations generated from this treatment possess a peculiar matrix structure, that allows the reduction of the system, via matrix operations, to three equations in three unknowns per gridblock regardless of the number of components.The level of implicitness of the formulation presented in this paper is intermediate to IMPECS and Fully-Implicit methods and has a higher level of implicitness than a semi-implicit method previously proposed in the literature. It provides an attractive approach to solve problems where the rate of change of pressures, saturations and compositions in the reservoir are important, such that IMPECS method becomes impractical and the Fully-Implicit method becomes too expensive.Applications to the simulation of a well-test in a gas-condensate well and the natural depletion and gas-cycling of a volatile-oil reservoir are presented.
Hydrocarbon and Produced Water Contaminated Soil and Pit Waste Remediation
Authors: Holliday G. H. , Deuel Lloyd E. 
Published: June 2014

Abstract
Exploration and Production [E&P] operations, worldwide, generate more soils and pit wastes contaminated with hydrocarbons, metals and chlorides than any other wastes, except produced waters. Transporting these contaminated wastes offsite results in operators losing control of the wastes. Additionally, transporting the wastes offsite consumes landfill capacity.
Field experience during the past 8–10 years demonstrates contaminated soils and pit wastes can be bioremediated onsite at low cost while retaining control of the waste. Moreover, bioremediation results in reducing hydrocarbon content to acceptable safe levels. Also, soil amendments convert sodic soils to calcium base soils encouraging leaching of the chlorides and revegetation of the affected area.
This paper presents remediation theory, amendments, limiting constituent criteria and mixing calculation techniques applicable to E&P operations. The authors illustrate land treatment and bioremediation technologies by providing a scenario detailing necessary data, calculations and limiting constituents required for successful remediation of crude oil and produced water contaminated soil.
Riser Gas Eliminators Reduce Wellhead Pressures on Offshore Satellite Platforms
Authors: Conner Stephen L. 
Published: June 2014

E&P Exchange
Riser gas eliminators installed on the liquid export risers of five Gulf of Mexico platforms have significantly reduced wellhead pressure by releasing trapped gas. Wellhead pressures on the platforms have been reduced an average of 50 psi. The gas eliminators have been installed on lines in which the oil has undergone primary separation (gas/liquid) only and is being transported to another platform with separator pressure. Gas eliminators should be effective on other liquid lines in water depths of 50 ft or more, especially those with low velocities. The riser gas eliminator is an inverted steam trap installed at the top of the riser. The inverted steam trap has an internal float that allows the gas to vent through an orifice. The vented gas can be used for fuel supply or routed through the vent system.
Without a gas eliminator, abnormally high pressure in liquid lines can be caused by accumulated flash gas trapped in the export riser of the producing platform. Flash gas breaks out of the oil when it undergoes a pressure drop after leaving the separator. Under some conditions, this flash gas is not flushed out of the export riser and accumulates to fill the riser. This column of gas in the export riser must support the hydrostatic head of the liquid column of the receiving riser. Because the gas column has comparatively little density, the liquid pressure on the bottom of the receiving riser is transmitted to the top of the export riser, unnecessarily increasing separator and wellhead pressures. The abnormal pressure differential caused by the trapped gas is proportional to the height of the riser and the liquid density, and in some cases is greater than 100 psi.
Conditions under which the gas accumulates are controlled by a number of factors, including the amount of dissolved gas in the oil, the riser 10, the residence time in the riser, and the fluid velocity during the separator dumpcycle. Good candidates for gas eliminator installations are satellite platforms that export gas and liquid in separate lines, with the liquid line having the higher pressure. Actual pressure drops that are significantly greater than calculated frictional pressure drops are an excellent indicator of trapped gas.
Downhole Chemical Addition Owing to Convection in Annular Liquid
Authors: Babu D. Ram , Dhodapkar P.K. , Pradhan S.P. , Sharma A.N. 
Published: June 2014

E&P Exchange
Production of waxy crude oils normally is associated with such operational problems as wax deposition in the tubulars and gelling of flowlines. In pumping wells, deposited wax restricts rod movement, leading to frequent breakdowns and production loss. Different methods are available to control wax deposition. Continuous addition of certain chemicals at low dosages to the well is popular because it reduces oil viscosity and other downstream problems. These chemicals, known as pour-point depressants (PPD's), remain in semisolid state at ambient temperatures. Pumping wells are treated by pumping a dilute solution of chemical and a solvent continuously into the casing through a macaroni line with the help of a dosing pump and a storage tank. During winter, the chemical solution needs more expensive solvents or heating to maintain its fluidity. To avoid the costs involved in the surface setup and its maintenance and monitoring, we tried a simple method in a few pumping wells with satisfactory results.
In this method, the oil column in the casing above the pump suction depth is replaced with a chemical solution. Density of the solution is maintained below that of the produced liquid. This prevents gravity swapping and ensures the presence of a chemical "reservoir" within the wellbore. The chemical batch is prepared by mixing PPD with heated lease oil of lower density and is displaced (Fig. 1a) into the casing/tubing annulus during the final stages of a hot-oil circulation operation.
When the pump is in operation, the temperature of the tubing's outer surface is a few degrees higher than that of the casing's inner surface. Natural convection currents occur in the liquid trapped between the two surfaces. The liquid rises along the tubing and moves in the opposite direction near the casing. Near the pump suction level, a constant exchange of mass between the crude entering the pump and the chemical reservoir takes place. With time, the concentration of chemical in the reservoir decreases and the density becomes equal to that of the produced liquid. The usual practice of venting the annular gas does not significantly affect this mechanism.