bluuebunny/crossref_metadata_2025_split huggingface dataset:
A New Conformance-Improvement-Treatment Chromium(lll) Gel Technology
Authors: Sydansk R. D. 
Published: December 2007

ABSTRACT
Laboratory testing and evaluation of a new chromium(III) [CrIII] acrylamide-polymer gel technology for conformance-improvement-treatment (CIT) use are reported. This paper is primarily limited to discussing the gel technology as applicable to fracture conformance problems.
Several notable features of the gel technology are as follows. The gels, as injected in the field, are a single fluid system. Gels are made by simply adding a single aqueous crosslinking-agent solution to the aqueous polymer solution. The base chemical of the crosslinking agent is a readily available and relatively inexpensive CrIII chemical. An entire family of CIT gels, ranging from highly flowing to rigid rubbery gels, can be produced by varying the formulation of the same chemical set. Thus, the new gel technology is applicable to a wide range of conformance problems. Highly controllable gel times, ranging from minutes to weeks, are possible and can be preselected. Gels have been shown to be stable for extended periods of time when aged at temperatures ranging from 55 to 255°F [13 to 124°C]. Over the same temperature range, the gels have been shown to possess exceptional yield strengths (resistance to flow) and to be effective plugging agents. The gels are relatively inexpensive because they typically contain 98 to 99.7% water, with the remainder being low cost chemicals. Gels of the new technology are insensitive to oilfield interferences and environments, including H2S. They are compatible with all tested oilfield fluids and equipment and with all tested reservoir rocks and minerals. The gels can be made over a polymer solution pH range of at least 4.0 to 12.5. Gels can be formulated with low-molecular-weight polyacrylamide polymers when low viscosity (watery) treatment fluids are required. The gels can be chemically degraded (reversed).
Laboratory studies are described which show the dependence of gelation rate and gel strength on the following parameters: 1) polymer type, concentration, molecular weight, and hydrolysis level; 2) polymer-to-chromium ratio; 3) temperature; 4) polymer solution pH; and 5) salinity. Gels are shown to exhibit favorable phase-stability, shear, and leakoff properties. A new bottle-testing scheme is described. Bottle testing is used to effectively, rapidly, and inexpensively monitor in a semi-quantitative manner gelation rate and gel strength as a function of time over a broad range of temperatures and gel parameters. Gel viscosities, as determined by dynamic oscillatory measurements, are used to substantiate bottle-testing findings and trends. For selected rigid gels, gel breakdown pressures in porous media and yield pressures are reported.
Weeks Island Bravity Stable CO2 Pilot
Authors: Johnston J. R. 
Published: December 2007

ABSTRACT
The Weeks Island S sand Reservoir B (S RB) gravity-stable CO2 field test is almost complete. Injection started in October 1978 and production began in January 1981 in this high-permeability, steeply dipping sandstone reservoir. Through 1987, about 261,000 barrels of oil or about 64 percent of the starting volume has been recovered. A 24-percent pore-volume slug of CO2 mixed with about six mole percent of natural gas (mostly methane) was injected at the start of the pilot. During 1983, when gas production rates started to increase, CO2 containing produced gas was reinjected. Through 1987, CO2 usage statistics are 7.90 MCF/B0 with recycle and 3.26 MCF/B0 based on purchased CO2.
This report is a review of early pilot history and a more detailed account of the post-June 1981 results. A reservoir-simulation history match of pilot performance plus core and log data from a 1983 swept-zone evaluation well are included.
Theories of Foam Mobilization Pressure Gradient
Authors: Rossen W. R. 
Published: December 2007

ABSTRACT
This paper presents theoretical models to predict the magnitude of the minimum pressure gradient (∇p)min to mobilize foam in two cases. In the first case, foam lamallae form by snap-off at pore throats during simultaneous flow of liquid and gas through the pore space. Percolation theory relates (∇p)min to the fraction of pore throats blocked by lamellae, the geometry of the pore throats, and the topology of the pore network. This theory indicates that in field application foam can begin to flow only at the relatively high ∇p found near the well. Effective reservoir sweep with foam therefore depends on the propagation of foam formed near the well.
In the second case a well-established foam flows as "bubble trains" through regions of trapped gas. Theory predicts that fine-textured foams then have substantial (∇p)min (tens of psi/.ft). If the reservoir ∇p cannot sustain (∇p)min from injection well to producer, flow stops and the foam plugs the zone. Thus some coalescence is necessary to avoid plugging and allow foam propagation deep into the formation.
Bubble compressibility increases (∇p)min because bubbles lodge at the pore throats, where capillary resistance is highest. Plateau borders, the rounded films were the lamellae contact the pore wall, reduce (∇p)min, especially for incompressible foams, At low capillary pressures, however, (∇p)min increases due to bubble separation at pore throats.
A New Formation Wettability Test: The Dynamic Wilhelmy Plate Wettability Technique
Authors: Andersen M. A. , Thomas D. C. 
Published: December 2007

ABSTRACT
This paper describes a technique for inferring formation wettability from measurement on crude oil/brine pairs. This dynamic Wilhelmy plate technique yields a quantitative measure of wettability in a form which is directly comparable to other forces in the reservoir. Exposure to air affects the measured wettability of crude oil, and a device is described for avoiding contamination.
Applied Geostatistical Analysis: Sage Spring Creek Unit "A", Natrona County, Wyoming
Authors: Russell T. L. , Bradley D. J. 
Published: December 2007

ABSTRACT
Geostatistical analysis is a useful tool for the petroleum engineer. The reservoir engineer can use such an analysis for determining grid block values for reservoir modeling; and the geologist and drilling engineer can use geostatistical analysis for determining development drilling spacing, and infill drilling spacing.
This paper describes the procedure necessary to perform a parametric geostatistical analysis, and uses thickness data from Sage Spring Creek, Unit "A" to illustrate the procedure.
Effects of Reservoir Heterogeneity and Fracture Azimuth on Optimization of Fracture Length and Well Spacing
Authors: Meehan D. N. , Horne R. N. , Aziz K. 
Published: December 2007

ABSTRACTOptimization of fracture length and well spacing can be critical to the economics of the exploitation of natural gas resources. If the fracture length is small compared to well spacing, then fracture azimuth will not affect interference between wells; many fields will be drilled to dense spacings and therefore require knowledge of the fracture azimuth to optimize the number of wells, the placement of the wells, and the length of the fractures. This is contrary to historical approaches to the optimization of ultimate recovery and net present value from tight gas fields, which are based on the idealization of homogenous, isotropic reservoirs and which neglect interwell interference.This paper reviews current technology for determining hydraulic fracture azimuth, and presents a solution for uniform flux fractures which accounts for fracture azimuth. It is shown that the uniform flux fracture model fails when interference between wells is significant. Numerical simulation of high conductivity fractures confirms that knowledge of fracture azimuth will be important for cases for which the ratio of interwell distance to fracture length is less than 2.0. Permeability anisotropies increase the importance of knowing fracture azimuth. A general procedure for optimization of fracture azimuth and well spacing is presented.
High Angle Development Wells in the N.W. Java Sea Bima Field: An Update
Authors: Barry P. M. , Troncoso J. C. , Sumantri A. N. E. 
Published: December 2007

ABSTRACT
Atlantic Richfield Indonesia, Inc., brought five of seven platforms of the BIMA Field on stream in December, 1986. At the time of writing this paper, two additional platforms were being started up. Forty eight wells were drilled from the seven platforms, including sixteen horizontal (90°) and high angle (85°) wells drilled through the productive zone. All of the wells in the field were equipped with electric submersible pumps.
The early phase of the high angle well program was the subject of a paper presented to the 15th Annual Indonesian Petroleum Association in October, 1986(1). This update describes the transition from the original high angle well design to a horizontal well configuration and the use of downhole steering and directional control techniques to accomplish productive zone extended reach penetration lengths of up to 2175' with only a 19' TVD variation.
This paper also describes how measurement while drilling (MWD) technology was employed to obtain well directional and lithological data and also how MWD logs replaced drill pipe conveyed logging tools. The costs to drill and complete BIMA extended reach wells are shown to compare favorably with standard deviated holes.
Operating characteristics and problems encountered in the course of producing wells in the high angle and horizontal environment at BIMA are discussed. Early indications from production data analysis verify that high angle wells exhibit a reduced drawdown, as expected, meaning that reservoir management techniques to control water and gas coning can be applied without sacrificing oil rate.
Completions are described which illustrate how pump installations and wireline activities are limited to the upper sections of the high angle holes. Also described are techniques which will use novel workover engineering approaches in an attempt to control excessive water and gas influx in horizontal wells.
High angle wells have proven to be an economically practical approach in a complex reservoir such as the Batu Raja limestone in the BIMA Field. Atlantic Richfield Indonesia, Inc., has led the way in successfully drilling and operating these long reach wells in the Offshore N.W. Java contract area.
Sensitivity and Reliability of Commercial Drill-String Inspection Services
Authors: Dale B. A. , Moyer M. C. 
Published: December 2007

ABSTRACT
Drill-string failures continue to be a costly problem for the oil industry. To reduce the occurrence of these failures, operators and drilling contractors typically employ service companies to perform periodic nondestructive inspections to remove damaged tubulars from service. Nonetheless, drill-string failures continue to occur, most often as a result of some form of metal fatigue. This paper presents the results of several field evaluation programs which were conducted to assess the performance of commercial drill-string inspection services employing conventional nondestructive testing techniques. A practical estimate of the effectiveness of these commercial inspection services is made using modern fracture mechanics concepts and fatigue crack growth data obtained from full-scale testing. Based on the data presented in this paper, commercial drill-string inspection services are found to be statistically quantifiable, however their effectiveness is substantially less than optimum. Improved flaw detection technology is needed to most effectively reduce typical downhole fatigue failures.
High Temperature High Rate Gas Well Completions: A Learning Experience
Authors: Husein H. , Steel D. 
Published: December 2007

ABSTRACT
This paper reviews Mobil Oil Indonesia's experience in the completion o£ high temperature, high rate gas wells, gained during ten years as operator for the Arun Field.
Over 50 production and injection wells have been completed in the Arun Field, and some of these wells have been worked over once or even twice since their initial completion. Problems which have been encountered during the operation or workover of the wells have led to changes in completion practices and equipment design. These problems are described in detail as are the. subsequent completion changes and the results of these changes.
Quantitative Flood Monitoring Utilizing a New Pulsed Neutron Tool Modeling Concept
Authors: Smith M. P. , Wyatt D. F. , Nguyen C. 
Published: December 2007

ABSTRACT
A new flood monitoring technique is presented that models both the capture cross section (sigma) and ratio/porosity responses of a pulsed neutron logging tool using known reservoir, hydrocarbon and flood agent properties. Open hole logs and pulsed neutron logs acquired before, during and after flooding are combined to determine individual hydrocarbon, saltwater and flood agent saturations. This new model uses total neutron migration length and direct ratio computations1 to compute the flood agent volume fraction. Improved accuracy of the computed fluid saturations and the ability to handle specific flood agents are two enhancements to flood monitoring provided by this new approach. Accuracy is especially important because often the results from a limited number of monitor wells are used to project the sweep efficiency and economics of the flood process for an entire reservoir.
This new method is applied to a CO2 flood and the resulting fluid saturations for oil, saltwater and CO2 are analyzed and discussed. These results are compared with those based on the older excavation effect method.2,3,4
Completion Systems for Large Diameter Casing
Authors: Weirich J. B. , Lorenz M. , Leggett D. 
Published: December 2007

ABSTRACT
Completion operations, for oil and gas wells, arc usually performed in casing sizes not exceeding 13-3/8" (34.0 cm) with the majority of completions being performed in 9-5/8" (24.5 cm) and smaller. As such, the availability of completion equipment, for large diameter casings, becomes extremely limited or nonexistent. Occasionally, conditions may exist which require the completion to be designed in a casing size larger than 13-3/8" (34.0 cm). In order to complete in these casing sizes, special equipment must be designed.
This paper discusses the design criteria, development, and subsequent use of perforating and gravel pack equipment generated for use in 20" (50.8 cm) casing. The theoretical approach to the evolution of this equipment is applicable to the development of additional systems.
Oilfield Liquid Measurement for Sarawak Shell Bhd and Petronas Carigali in Baram Delta Area
Authors: Pushparatnam E. , Teo C. K. 
Published: December 2007

ABSTRACT
This paper describes the measurement of crude oil volume in an oil/water mixture that discharges from an oilfield. Measurement is carried out using a turbine meter, a densitometer and a flowcomputer. The system is capable of determining the volume of crude oil in a flowing stream of a crude oil/water mixture within 2% of the total liquid volume.
Production and Reserves Monitoring (PARM) System
Authors: Rennie R. G. , Senduk R. , Tabalujan H. 
Published: December 2007

ABSTRACT
Huffco Indonesia has developed and installed a computerized database system called PARM System - "Production and Reserves Monitoring System". This integrated database handles data that includes reservoir, geological, production, operations and mechanical well data. While the PARM System data are acquired and controlled from many technical and operations disciplines within the company it is always input as close to the original source as possible.
The PARM System, as an integrated production and reserves data source for Huffco Indonesia, has applications across a wide range of engineering and operations disciplines. Daily production and operations reports, monthly production allocation and product distribution reports, daily drilling reports and summary reports and many other necessary routine reports are generated by the PARM System. Benefits of analysis of large volumes of data, which were previously very cumbersome to attempt, are now being realized by engineering groups. Ad-hoc data retrievals provide consistent current and historical data for production and reservoir engineering applications.
An integrated computerized database system such as the PARM System, provides a cost and time efficient engineering and operations tool. It pro ides unparalleled accessibility to any data likely to affect or resulting from the oil and gas production of a well, zone or field. Accuracy of original data is improved due to multi-user review and built-in integrity checks. Development of a system, such as the PARM System, should be done on a prototype basis under direct engineering management.
Application of computer technology to the petroleum industry is manifested in the PARM System by virtue of capturing and handling of the basic oil and gas operations and engineering data. This paper describes the design and implementation concepts of the PARM System as well as engineering and operations applications ranging from simple reports and data retrievals to interfacing with reservoir simulation software.
Analyzing Dual Porosity Systems by Rectangular Hyperbolic Method
Authors: Mead H. N. 
Published: December 2007

ABSTRACT
The purpose of this paper is threefold:(1) to present a method of buildup analysis (RHM) that can determine the percentage of reservoir column open to the wellbore which is contributing reservoir fluid, (2) to determine the average permeability of the permeable portion of the reservoir open to the wellbore and (3) to determine the possible existence of a dual porosity system and the characteristics of the fracture or vugular system that might produce reservoir fluid into the wellbore. Since RHM is a relatively new concept, two appendices are attached to explain the general aspects of the RHM procedure. The writer presented a paper related to this one at the 1987 SPE Regional California Meeting in April, 1987, (see reference 4).
A Critical Evaluation of the Deviation Time Method to Calculate Discontinuity Radias From Well Tests in Composite Reservoirs
Authors: Ambastha A. K. , Ramey H. J. 
Published: December 2007

ABSTRACT
Reservoirs with a fluid bank, or a buming front, reservoirs with a reduced or an increased permeability region around the wellbore, and geothermal reservoirs are often modeled as composite reservoirs. Reservoirs with a fluid bank include reservoirs undergoing waterflood, chemical flood, polymer flood, C02 flood, and steam injection. Eight well tests reported in the literature exhibiting composite reservoir behavior have been analyzed using the deviation time method. The dimensionless deviation times obtained from pressure and pressure derivative responses for a well in a composite reservoir have been used for analyzing the well tests. Analysis shows the estimate of discontinuity radius to be sensitive to both the real and the dimensionless deviation times used. The estimated discontinuity radius from the deviation time method may represent a lower bound for discontinuity radius, if the swept region is not cylindrical Also, obtaining an accurate deviation time for small mobility contrasts may be difficult.
Limitations on the deviation time method due to wellbore storage effects have been quantified indicating a need to minimize wellbore storage in composite reservoir well tests. The effects of a transition region on the dimensionless deviation time have been studied using an analytical solution for a three-region reservoir.
The Oilfield Microbiology Assistance System (OMAS)
Authors: Horacek G. L. 
Published: December 2007

ABSTRACT
An artificial intelligence knowledge base (expert system) has been developed to assist oilfield personnel in analyzing for bacterial involvement in water-related field problems. The expert system also advises on the probability that bacterial contamination is involved in corrosion and can make biocide recommendations for several common bacteria-mediated field problems. The new expert system, Oilfield Microbiology Assistance System (OMAS), is a floppy-disc-based computer program that runs on most IBM and IBM - compatible personal computers. On-line help is included with the program diskette. The expert system was developed using INSIGHT 2+ software and is distributed to company personnel in a "read-only" format. The expert system covers situations encountered in the oilfield environment but can be tailored for other specific applications.
Experience Gained in the Monitoring of the Das Island LNG Installation in Sour Gas Service
Authors: Pattinson J. 
Published: December 2007

Abstract
The Das Island Gas Liquefaction plant accepts a range of feed gases. The different streams are listed in Table 1. As can be seen from this table, many of the gas streams are sour, containing significantly more H2S than the 0.05 psia given by NACE standard MR-01-75 in its definition of sour service. These incoming gases are also damp and so corrosion and consequent hydrogen damage will occur unless remedial action is taken. Aqueous corrosion has two components; an oxidising or anodic reaction such as Fe→Fe2++2e
and a reducing or cathodic reaction, which, in the case of damp H2S, is 2H++2e→2H→H2
The second stage of this latter reaction is poisoned by the presence of sulphide ions and the hydrogen atoms, instead of combining to produce hydrogen molecules, are taken up into nearby steel. Thus atomic hydrogen dissolves in the steel structure and can cause a decrease in the metal's toughness. However, if the steel contains inclusions then these hydrogen atoms combine at the inclusion/metal interfaces and the resulting pressure of hydrogen gas leads to delamination and cracking – known as hydrogen induced cracking (HIC).
The first step of liquefaction is the compression of the various gas streams in four stages until a single stream of gas is produced at 780 psi which goes on to be scrubbed of H2S and CO2. The gas liquefaction plant is split into two identical trains with the first stage compression being common to both. The schematic of the compression process is shown in Figure 1. The design process conditions are given in Table 2.
Preliminary Investigation Into the Utilization of Gas Containing 21% H2S in Oilfield Gas Turbines
Authors: Rabbo M. F. Abd 
Published: December 2007

ABSTRACT
Oil fields electrical power generation is commonly dependent on separated sweet gas for fuel in typical turbine/generators set up. As discoveries and subsequent development of sour oil and gas fields are becoming common place, either the produced sour gas is sweetened or diesel is used for fue-lling the gas turbine/generators. However, due to the high cost of diesel fuel, most operating companies opt for sweetening the gas for fuelling gas turbines. Sour gas of hydrogen sulphide (H2S) content above 2% was always discarded as fuel for fear of hot corrosion (sulphodation) of the hot section of the gas turbine would lead to catastrophic failure. This paper is set out to investigate possible modifications to a typical oil field gas turbine in order to economically allow for burning sour gas without the onset of hot corrosion. The study looked at a typical example of an oil field gas turbine generator currently being operated by diesel fuel and discussed the necessary modifications to operate the turbine on sour gas containing upto 21% H2S by volume. The economies of diesel, sour and sweetened gas operations were highlighted.