bluuebunny/crossref_metadata_2025_split huggingface dataset:
Determination of Basic Geometrical Characteristics of Fractured Porous Media by X-Ray Computerized Tomography and Digital Photography
Authors: Martinez-Angeles R. , Perez-Rosales C. 
Published: December 2007

Abstract
Computerized Tomography (CT) and Digital Photography (DP) are new naturally fractured reservoir engineering imaging techniques that measures density inside fractured cores and micromodels samples during laboratory experiments. An image processing method for determining, simultaneously, some of basic geometrical characteristics of homogeneous and fractured porous media such as porosity, specific surface, mean pore width, mean grain thickness, mean fracture width, and absolute permeability is presented. The proposed method is characterized by its simplicity and by use of a X-ray tomography equipment and a digital camera. The experimental procedure used to evaluate various geometrical characteristics is based upon the surface analysis of a sample for a digital camera and upon a cross-section of a core model for a X-ray CT. In view of this fact, the applicability of the method is extended for heterogeneous and anisotropic samples such as fractured and vugged cores and micromodels.
Four experimental cases, digital images included, are presented: homogenous, one fracture, one vug, and a combination matrix-fracture-vug. Finally, two experiments of imbibition in fractured systems of one and four blocks of Berea sandstone are presented, where digital image processin procedure has been applied in terms of water saturation.
Linearly Supported Radial Flow -- A New Flow Regime Identified in Dual-Porosity Reservoirs
Authors: Guo Boyun , Stewart George , Toro Mario 
Published: December 2007

Abstract
Modern welltest analysis and interpretation techniques are based on match between actual reservoir pressure response and analytical models. In most well and reservoir configurations the analytical techniques are sufficient. However, recent technology advances in drilling and completion, and reservoir heterogeneity detected by modern pressure gauge have identified complex well and reservoir configurations where existing analytical well test models are not adequate for retrieving reservoir properties. This paper presents case studies where a new flow regime was indicated in two hydrocarbon reservoirs when the two wells were tested.
Log-log plot of pressure derivative versus time is called diagnostic plot in welltest analysis. Special slope values of the derivative curve are usually used for identification of reservoir and boundary models. These slopes include 0-slope, ¼-slope, ½-slope, and unity slope, etc. However, in many cases the derivative curves do not exhibit slopes of these special values, and it can be assured that the non-special slopes reflect certain flow patterns in the reservoirs. One type of these reservoirs has been observed to be thick reservoirs with either bottom or down-dip water drive. The slopes of the pressure derivative curve for this type of reservoirs are normally below ½ and not equal to ¼. A slope of as low as 0.2 has been observed in a gas reservoir. This paper demonstrates that these low slopes can be attributed to a new flow regime namely Linearly Supported Radial Flow (LSRF). The LSRF may exist in the drainage area of a vertical well where a radial (normally horizontal) flow prevails in a high permeability layer and a linear (normally vertical) flow into the high permeability layer dominates in a low permeability layer. The LSRF may also exist in the drainage area of a horizontal well after pseudo radial flow in the high permeability layer is reached. The linear flow in the low permeability layer may be supported by an aquifer. Analyses using a numerical welltest simulator support this LSRF theory.
Dilute Surfactant IOR - Design Improvement for Massive, Fractured Carbonate Applications
Authors: Yang H. D. , Wadleigh E. E. 
Published: December 2007

Abstract
Surfactants may be one of the best options to improve recovery from geologically challenging reservoirs. For over forty years, concepts and results of surfactant applications have been published. During recent years, depressed oil prices have limited surfactant consideration. However, surfactant recovery can be economically attractive for reservoirs where recovery is dominated by gravity and imbibition processes. Massive and/or fractured formations of moderate 30-50% recovery may warrant consideration for surfactant processing. Applications must meet laboratory performance hurdles for high incremental recovery at relatively low surfactant concentrations (quantified wettability and bond number). Placement of chemical in the reservoir at optimum concentration is the next challenge. This paper presents analytical and simulation assessment of chemical placement within a massive fractured carbonate formation undergoing surfactant EOR field testing. Placement methods can range from continuous injection to interrupted "huff-n-puff' application. The gravity stabilized reservoir management process currently being applied in the reservoir avoids some of the chemical flood conformance challenges of classic applications.
Oil mobilization by surfactant huff-n-puff in a naturally fractured reservoir is a complex process. The success of the application depends not only on surfactant chemical and physical properties and surfactant concentration injected, but also on fracture surface area treated by chemical solution and penetration depth of surfactant into matrix rock. In order to optimize the design of a dilute surfactant treatment in the Yates Field, an analytical model was developed to investigate effects of various parameters on the fracture surface area treated and penetration depth of surfactant solution into matrix block. These parameters include surfactant injection rate, injection volume, chemical diffusion, convection and fracture properties. Results of the analytical application are compared to simulator solutions. Laboratory testing, formation target screening, and field application are also discussed.
The Reliability of Permeability-Anisotropy Estimation From Interference Testing of Naturally Fractured Reservoirs
Authors: Hidayati Dewi T. , Chen Her-Yuan , Teufel Lawrence W. 
Published: December 2007

Abstract
Naturally fractured reservoirs normally exhibit high horizontal permeability anisotropy. Orientation of anisotropy, degree of anisotropy, and maximum/minimum permeabilities are required to describe the reservoir flow anisotropy. These parameters are normally obtained from interference testing. A series of sensitivity study was conducted to investigate the reliability of these estimated parameters from an interference analysis. The results show that interference test analysis gives reliable estimate of the orientation of anisotropy. However, the degree of anisotropy, maximum/minimum permeabilities, and total compressibility are very sensitive if the degree of permeability anisotropy is high and if the well configuration is unfavorable. Among the above parameters, the degree of anisotropy is the least reliable.
Test of Hydraulic Jet Pump in the Balam 91 Well
Authors: Morales H. Ramos , Castro H. Salgado , Maldonado O. Ruiz , Munive A. Salazar 
Published: December 2007

Abstract
When the natural energy of a reservoir is not enough in order to elevate the oil to the surface, it is necessary to use an artificial lift system that supply the additional energy required to continue the exploitation of the reservoir. Likewise, the artificial lift system is installed to increment the production in flowing wells. This is achieved by the energy that is added to fluids in the bottom of the well.
The hydraulic pumping, is an artificial lift system that transmits energy in the bottom of the well by a power fluid that flow through a pump.
There are two types of hydraulic pumping; the denominated piston type, that consists in a pair of reciprocating pistons, where one of them is driven by the power fluid and the other pumping the well fluids. And the hydraulic pumping jet type, which converts the pressurized power fluid to a high velocity jet that is mixed directly with the well fluids.
A description is presented and the result reached in a pilot test of hydraulic jet pump, effected in the Balam 91 well of the Ek-Balam field.
Genetic Algorithms Applied to the Optimum Design of Gas Transmission Networks
Authors: Montoya-O. S. J. , Jovel-T. W. A. , Hernández-R. J. A. , González-R. C. 
Published: December 2007

Abstract
This paper describes the application of a modified genetic algorithm (GA) to optimize the design of gas transmission networks operating under steady-stable conditions.
The gas-network optimization system is implemented by means of a genetic algorithm that executes an "intelligent search" in a "gas transmission networks" space.
It obtains automatically and with a low computational work a distribution of pipeline segment diameters for a minimum investment cost, accomplishing some restrictions initially fixed.
Anagas 2000: A Powerful Tool to Analize Orifice Metering Systems Used for Flow Measurement of Natural Gas
Authors: Santamaria N. E. , Mancilla S. F. 
Published: December 2007

Abstract
Orifice plate technology represents one of the most accepted and versatile methods for measuring flow; however, to achieve the full performance of this technology, a considerable amount of details must be attended to. This paper describes the development and the applications of a computer program denominated ANAGAS 2000, which allows in quick and reliable form to analyze or select an orifice metering system. Their use helps to identify operative problems, and to define quickly what a modifications it is necessary to carry out to optimize the operation of these metering systems Among other options, it can be used for the following purposes: (1) to calculate the flow rate delivered with a meter in operation; (2) to determine the maximun and minimun flow rate that can be handled with a meter tube installed, using different orifice plate bore diameters and pressure ranges of a mechanical chart recorder; (3) to define the physical arrangement that must have an orifice metering system to install, to quantify a well-known flow rate fulfilling the applicable recommendations strictly. The computer program was developed with base in the rigorous procedure that the latest editions of the API and the AGA recommend to calculate the gas flow rate measured with orifice plate, and considering also the applicable recommendations for its operation.
JU2000 - Efficiency by Design
Authors: Day Howard , Williams Mike 
Published: December 2007

Abstract
A drilling rig, either fixed or mobile, can be described as a factory that digs a hole. The purpose of this paper is to examine the fundamentals of the well bore construction process and how this has traditionally influenced rig design. By using an economic justification analysis to evaluate the tubular handling processes, a step change in performance and a breakthrough in rig design will be achieved.
This paper will outline the developmental steps taken by the rig designer, and in parallel, the technological development of tubular handling systems, that contribute to this step change in performance. Actual field performance for the pipe handling systems will be presented, including the innovative process that allows casing to be assembled in stands and racked back in doubles in preparation for casing the well.
Additionally, the handling of single 80' or 90' joints of casing and/or drill pipe is considered under parameters such as eliminating couplings and the subsequent reductions in make up and break out time, tool joint maintenance, and casing wear that can be attributed to tool joint hard banding.
The innovative use of both an automated vertical and horizontal pipe racking system, potentially providing the rig design with a smaller, lighter derrick structure and increased efficiency, will be illustrated. An example of the computer modeling system will be used to present an animation of the tubular handling process.
The resultant benefits of this combined approach can yield overall performance advantages of up to 20%, with associated up front economical benefits, over traditional jack up designs.
Advanced Hydraulics Analysis Optimizes Performance of Roller Cone Drill Bits
Authors: Ledgerwood L. W. , Wells M. R. , Wiesner B. C. , Harris T. M. 
Published: December 2007

Abstract
For nearly 30 years after the introduction of jet bits, all tricone bits had virtually identical nozzle systems. Nozzles were aimed toward the corner of the borehole bottom, more or less equidistant between the cones. More recently, tricone bits with unique patented nozzle systems have appeared and today drillers can choose between at least five different nozzle configurations. It is recognized that cone cleaning nozzle systems perform best in bit balling environments and borehole cleaning nozzle systems perform best in bottom balling environments. Another characteristic of bit hydraulics, which has not received much attention in the literature, is the ability of a bit to evacuate cuttings. Since one bit may encounter both bit and bottom balling environments during its life and all bits must evacuate cuttings, it is most ideal if one nozzle system can be developed which performs well in all three of these aspects.
A bit with a new nozzle system, described in this paper, has been shown to achieve superior rates of penetration to all other nozzle systems currently available in both laboratory and field tests. Three dimensional Computational Fluid Dynamics (CFD) models of the flow field between tricone bits and boreholes have been used to quantify the bit cleaning, bottom cleaning and cutting evacuation characteristics of this new bit and two other tricone nozzle designs.
Cone cleaning is not the only factor to be considered in designing a nozzle system for bit balling environments. Today's rock bit is expected to drill long intervals and therefore must drill through several different types of rock, which can often mean the bit may encounter several different drilling environments in its lifetime. Furthermore, nozzle systems that clean the cones may erode the cones in abrasive environments. CFD models have also been used to quantify and minimize the potential for erosive wear of the cone shell.
Removing Subjective Judgment From Wettability Analysis Aids Displacement
Authors: Heathman James , Wilson J. Michael , Cantrell James H. , Gardner Craig 
Published: December 2007

Abstract
This paper demonstrates how simple instrumentation can be used for evaluating the wettability of cementing spacers and preflushes in a laboratory. With detailed knowledge of a solution's "apparent" wettability, service companies and operators can more effectively choose the surfactants required for displacing nonaqueous drilling fluids and leaving the casing "water-wet." Water-wet casing allows the cement to adhere more easily to the surface, reducing the potential for remedial zonal isolation treatments.
A new laboratory device has been developed that more precisely assesses wettability. This device indicates "apparent" wettability by measuring the electrical activity in the test fluid during the water-wetting process. Oil-external drilling fluids do not conduct electricity; water-external spacers do. As the oil-wet surface of the test container becomes water-wet, the device registers electrical activity and a meter displays the "apparent" wettability in dimensionless units called Hogans (Hn).
Success with Electronic IADC Report
Authors: Opsal C. M. , Johnson S. E. , Holmberg C. J. 
Published: December 2007

Abstract
IADC, recognizing the need for operators and contractors to gather and disseminate drilling data electronically, while still maintaining the industry standards for format and content, issued license requirements for software to meet this need. How these requirements are met and how industry is accepting this new product is discussed. Field tests on drilling rigs show how electronically capturing and disseminating daily drilling information in the industry accepted method and format saves hundreds of dollars per day, and avail additional information and savings to the Operator and Contractor. Meeting IADC license requirements for an exact replication of the Time-tested IADC DDR insures ease of input, accuracy, reliability, consistency, and legality of the data and the format. By creatively utilizing new computer technology, additional information can be captured, processed, stored, and disseminated more accurately and quickly than with the current multi-part paper forms. This paper discusses the development of the electronic IADC report, utilizes field test results to illustrate the implementation, and demonstrates how the much needed new technology is cost effective and enables significant future efficiencies for Contractors and Operators. Creative data capture methods are detailed and field tests illustrate the cost savings, as well as the acceptance level of the new technology. Field tests results are used to quantify specific time and money savings both on the rig and in the office—how repetitive data entries are minimized, how handwriting is converted to accurate data, how the electronic DDR can be integrated into other systems, such as, accounting and engineering programs, and how secure the reports are. Field tests also illustrate the acceptability of the new technology on the rig, and define the basic training required. Additionally, this paper discusses how and why the IADC paper format has become accepted as a legal document and how the same legal status occurs with the electronic/computer form.
Overcoming Hard Rock Drilling Challenges
Authors: Santos H. , Placido J. C. R. , Oliveira J. E. , Gamboa L. 
Published: December 2007

Abstract
Drilling through hard rock has been a limiting factor to economically develop significant hydrocarbon reserves in several areas. The high cost to explore and develop an oil/gas accumulation is the key factor to be overcome. This paper describes a Joint Industry Project (JIP) that has been started to select and field test the most promising technologies under development that will allow a significant reduction on well cost. Problems faced while drilling hard rocks are not only restricted to slow penetration rate, but also the non-productive time associated to drill string failure, wellbores out of gauge, stuck pipe associated to block instability that falls into the well, and fluid losses due to fractures.
PCD Technology Advances Sidetracking Capabilities
Authors: Childers Ronald D. , Miller Gregory C. 
Published: December 2007

Abstract
Innovative materials technology advances sidetracking capabilities and offers a cost-effective approach to creating multiple laterals from the same mother bore. The key component to this sidetracking system is a mill designed with polycrystalline diamond (PCD) inserts. Current technology dictates that sidetrack milling be performed with mills dressed with crushed or pre-formed tungsten carbide that is manually applied. Regardless of technology, the success of the sidetrack is dependent upon on the skill and experience of the welder to properly dress the mill. The PCD mill eliminates the dressing process and the related performance uncertainties.
This paper discusses how PCD cutters, which are commonly used in drilling, were modified and applied to a casing-sidetracking mill. The mill design capitalizes on their ability to effectively and swiftly cut a window in the casing and drill a rat hole in formations with compressive strengths of up to 40,000 psi.
The benefits of such a mill are: 1) using the same cutting element for both steel and hard formations, 2) substantial cost savings when constructing multiple laterals from the same mother bore, 3) increased consistency in mill manufacture, 4) reliable milling performance and 5) improved efficiency in the sidetracking operation.
This paper profiles the development and testing from concept to a field-proven tool. The paper details: 1) laboratory-milling tests that identify the best material for cutting steels, 2) Oklahoma field tests in 9-5/8 in. casing to verify the feasibility of PCD casing milling and formation drilling, 3) West Texas and Colombia field runs in operators'
7 and 9-5/8 in. casing to mill a window and drill hard formations. Additionally, the paper will elaborate on the future potential of integrating this technology to a directional drilling assembly to drill laterals with the same equipment and preferably in the same trip for short laterals.
Gravity Azimuth: A New Technique To Determine Your Well Path
Authors: McElhinney G. A. , Margeirsson A. , Hamlin K. , Blok I. 
Published: December 2007

Abstract
Hot Holes with a geothermal gradient over 7 Degrees Fahrenheit per 100ft, high levels of magnetic interference and no returns. In this environment drilling deviated holes to a confined target can tax today's technology.
This paper describes the use of a new and novel technique that uses the Earth's Gravity field to determine the direction of a well. Direction from Gravity may normally, not be considered technically possible. However measuring the difference in the spatial position between two sets of accelerometers 30m apart gives the change in azimuth over this interval. These changes accumulate to show the well path trajectory.
The use of the Gravity Azimuth technique may help solve the problems associated with magnetic interference when surveying with magnetic survey instruments. The wider application of this technology into areas with localized magnetic interference, like drilling out of Casing Windows, Multi Well Avoidance, Casing drilling, 3D rotary steering devices and Multi Laterals is discussed. The paper compares the Gravity results to Gyroscopic and Magnetic instruments and discusses the operational consequences of the different methods.
Drilling The Limit*- A Practical Approach to Breakthrough Performance
Authors: Jones J. Adrian , Poupet Pascal. 
Published: December 2007

Abstract
"If you always do what you have always done, you will always get what you have always got". After 5 wells drilled recently in the South Halibut Basin, Central North Sea and with considerably more offset experience gained through other partners, Shell Expro embarked on the Drilling The Limit* philosophy for the Goldeneye E&A well.
The result was significantly above expectations, with a 20% improvement on the best previous offset well and a 30% improvement on the planned 50:50 AFE time. This translated into a cost reduction of 25% from the original AFE. It validated the hope that a true step change in performance in the North Sea is possible, even for a one-off well. By fully involving the lead drilling contractor and making the most of internal and external learning a "Best-in-Class" performance was achieved and demonstrated Shell Expros' ability to be a Low-cost operator.
In mature areas, where marginal developments depend on performance, DTL* is a worthwhile alternative to compromising the workscope and the well objectives in order to reduce expenses. It is a robust way to unlock opportunities and to contribute positively to the business.