bluuebunny/crossref_metadata_2025_split huggingface dataset:
Electronic, Fiber-Optic Technology: Future Options for Permanent Reservoir Monitoring
Authors: Botto Giovanni , Maggioni Bruno , Schenato Adelmo 
Published: December 2007

Abstract
According to current trends, it is likely that in the near future the oil & gas industries will have to choose between electronic and fiber optic systems for the continuous measurement of down-hole pressure and temperature (permanent reservoir monitoring).
The aim of this paper is to give a view beyond the facade of the up-to-date electronic and fiber optic technology in order to provide a critical evaluation of the degree of maturity of both technologies from an operator’s point of view and to define some realistic prospects of application in the short/medium term period.
Flow in Horizontal Wellbores with Influx through Porous Walls
Authors: Ihara Masaru , Kikuyama Koji , Hasegawa Yutaka , Mizuguchi Keiichi 
Published: December 2007

Abstract
Experimental investigation is presented on the channel flow with mass transfer through porous walls, which has continuous influx into a horizontal wellbore configuration from the oil reservoir. This has been recognized as one of the unsolved, yet most important problems in the production operations because of the complicated interaction between the wellbore and the reservoir.
The pressure was measured along the test channel with rectangular cross section, when the turbulent single-phase liquid flow was introduced into the channel. The fluid velocity distribution in the rectangular cross section was also measured to investigate the effect of influx on the pressure drop.
From comparison with a one-dimensional momentum exchange model, the model agreed with the experimental data for relatively large Reynolds numbers and described reasonably the flow behavior in a horizontal wellbore configuration.
Tip Screenout Designs in Low Permeability North Sea Chalk Reservoirs
Authors: Ennis B. K. , Britt L. K. 
Published: December 2007

Abstract
The Valhall Field is located in the Norwegian Sector of the North Sea and produces from a series of low permeability chalk formations. The wells have historically been completed with a variety of stimulation techniques including propped hydraulic fractures to increase recovery and inhibit inflow of the unstable chalk formation.
This paper will review critical stimulation design considerations, treatment redesign and execution, and post appraisal of the fracture stimulations performed in three wells in the Valhall Field. In the stimulation design portion of the paper, the effects of proppant embedment on post fracture well performance is reviewed. In addition, fracture fluid and proppant selection is evaluated. During the execution phase, fracture stimulation design methodology is reviewed. This methodology includes the use of minifrac pressure decline analysis to redesign stimulations. Finally, post fracture well performance is evaluated and compared to analytical predictions.
A Field Demonstration of Hydraulic Fracturing for Solids Waste Injection with Real-Time Passive Seismic Monitoring
Authors: Keck R. G. , Withers R. J. 
Published: December 2007

Abstract
This paper documents the findings of the Deep Well Treatment and Injection (DWTI) field research project to demonstrate the use of hydraulic fracturing for non-exempt solids waste disposal. This test involved injection of a large quantity of simulated waste into a porous rock formation at a depth of 4500 feet. The inert material injected was designed to match appropriate properties of actual solid wastes. A total of 4 million pounds of sand and bentonite clay, plus 50,000 bbls of water, were pumped in four batch injection cycles spanning five days of operations.
Fracture diagnostic tools used to measure the created fracture geometry included temperature and R/A tracer logs, hydraulic impedance, tiltmeters, and a new real-time passive seismic monitoring and analysis system. Seismic data was measured in two dedicated monitor wells offseting the predicted fracture azimuth. Each well contained 75 geophones that provided 700’ of vertical coverage. Over 2000 seismic events were obtained and analyzed for fracture height; 250 of these were analyzed further for three-dimensional fracture location.
The fracture geometry was predicted in advance with a new computer model developed for this waste injection application. Results showed excellent agreement between the fracture height predicted and that measured by the seismic system, but that other diagnostic techniques were not sufficiently accurate. Good agreement between the maximum predicted fracture length and the length from the seismic system was also observed.
Completing Oilfield Projects in Arctic Russia: "Both Points of View"
Authors: Roobaert N. C. , Vladimirov Anatoly 
Published: December 2007

Abstract
The way that oil fields are developed in Russia and how western companies work with their Russian partners, Russian Institutes, and Russian contractors have been burning questions since Russia has been made open to Western participation. As Russian and Western companies continue to partner more is learned each day about how to work together. Naturally, some experiences are good and some are not so good. Each side has his own story as to why things went well or not so well. This paper presents both points of view and discusses a way of working together. The two views are presented by the Chief Engineer of a Russian Institute and by the President of an American Engineering Firm. These are individuals who have worked together over the past two years on projects in the Timan Pechora Basin. Although, these are thoughts and feelings of two people who have actual experience working together, by no means is this paper represented to be a general statement of every situation. No doubt, others have different experiences, thoughts and feelings.
The future of working relationships between Russian and Western companies is bright, but it does take work, nurturing, patience and an understanding of each other. The purpose of this paper is to add to that understanding. Both points of view are presented. The capabilities of, type of work best performed by, and advantages of working with a Russian Institute are discussed. It also presents the equipment and services that can best be supplied and performed by Russian companies now and in the future. Finally, it presents a way of best working together as partners.
This approach of presenting both points of view is unique as far as we know. Of major importance is the genuine response from the Russian point of view. These responses have not been altered. This will be apparent as one reads the paper, but it also represents some of the difficulties that must be worked through in building a relationship. In very few cases liberties have been taken in translation to clarify the meaning of comments by Mr. Vladimirov. These responses are important because not only is an assessment made of the subject under consideration by someone who has first hand knowledge, but we must also read carefully the comments of Mr. Vladimirov, particularly his understanding of the subject, the honesty of his answers and his ability to answer in such a way that it is understood by the readers of this paper.
Successful Gas Shutoff with Polymer Gel Using Temperature Modeling and Selective Placement in the Prudhoe Bay Field
Authors: Sanders G. S. , Chambers M. J. , Lane R. H. 
Published: December 2007

ABSTRACT
A combination of known crosslinked gel chemistry with careful problem diagnosis, wellbore and formation temperature modeling, and zone isolation techniques yields a high success rate for shutting off unwanted gas influx into production wells in the Prudhoe Bay Field of Alaska. The paper includes candidate selection criteria, methodology of temperature simulation, job design, field operations case histories, and pre- and post-job production data for evaluation of success. This approach has led to a 60% technical success rate, primarily on wells that had cement squeeze failures. Job costs are about 75% those of comparable cement squeezes.
A Gelation System for Conformance Technology
Authors: Dalrymple Dwyann , Tarkington John T. , Hallock James 
Published: December 2007

Abstract
This paper presents a technique to reduce or plug permeability to water in primary hydrocarbon production wells and secondary injection hydrocarbon wells without causing damage to the subsurface environment. The principle of the operation is to pump a water-thin monomer solution in a single stage into the formation. The monomer then forms a polymer through a process activated by well temperature. Relative solubility of the resulting gel is directly controlled by the concentration of monomer placed in the formation. The polymerized material (gel) plugs pore spaces and channels, thus limiting undesired fluid flow.
The ecologically friendly system (EFS) avoids use of metal crosslinkers and allows for extended and reproducible gel times; it is nontoxic and acid-resistant.
Treatment techniques described in this paper may be applied to correct numerous conformance problems, including those listed below: coning in production wellshigh-permeability streaksinterwell channelinginjection out of zone
Field Trials of Multiphase Metering Systems at Prudhoe Bay, Alaska
Authors: Priddy W. J. 
Published: December 2007

Abstract
A prototype Cl 1500 positive displacement multiphase metering system has been tested at Prudhoe Bay, Alaska. The trial, conducted during 1992-93, extends previous test experience, covering pressures of 200 to 2300 psig and gas void fractions of 62% to 95% These represent the most difficult multiphase flow conditions from the metering standpoint but are widely applicable. Reproducible phase flow rate measurements to within ±5% relative of the reference single phase measurements were achieved by the multiphase meter on the basis of a simple factory calibration using tap water. In combination with previous testing, the trial has given confidence in reliability and demonstrated resilience of the calibration. Water cut measurements required by the system were attempted using a capacitive phase fraction cell. This indicated that water cut can be measured in high gas fraction streams using a conditioned sampling signal analysis technique.
Status of Multiphase Flow Measurement Research
Authors: Williams Jane 
Published: December 2007

Abstract
Research in multiphase measurement has been accelerating over the last few years. The reasons for this interest level are primarily economic in nature. It has been estimated that more than 50% of the world’s proven reserves of oil and gas are located in water depths greater than 1000 feet.1 These water depths demand innovative and economical developments, in order for projects to be viable. Some of the more promising methods for economical production in deep water include multiphase measurement, especially in conjunction with multiphase pumping. Subsea production, measurement and transportation to shore or to an existing platform may allow more efficient and less costly processing, thus minimizing platform costs. On some projects, it may be possible to eliminate separation equipment and test lines which will result in tremendous economic savings. This paper will explore the advantages of multiphase measurement, methods utilized for multiphase measurement to date, research to date, and projected future research.
Hydrocarbon Blowdown from Vessels and Pipelines
Authors: Norris III H. L. 
Published: December 2007

Abstract
In SPE 26565 presented at the 68th Annual Technical Conference in October, 1993, analysis and experimental results were presented for the blowdown of pipelines and vessels using air, carbon dioxide, and carbonated water. Since then further experiments have been carried out using several hydrocarbon gases including both methane and heavier mixes.
The pronounced difference in the blowdown behavior between pipelines and vessels noted in the earlier non-hydrocarbon experiments was confirmed for the hydrocarbon gases tested. In addition, for vessel blowdowns, the presence of condensed hydrocarbon liquid was shown to increase the mass efflux rate over an otherwise equivalent single-phase methane blowdown. By contrast, pipeline efflux rates were found to be virtually insensitive to gas composition over the range of hydrocarbon gases tested.
These experimental results were compared to the analytical methods described in the earlier paper, and initial efflux rates were found to agree with measured values within about 20%. In addition, the measured efflux rates can serve as test cases for comparison to other analytical methods.
Space Age Material Technology Extends Beam Lift Capacity
Authors: Lea J. F. , Hensley H. N. , Christian Jimmy , Hettinger Douglas , Meisner William , Anderson Howard 
Published: December 2007

Abstract
This paper describes the development and use of a Continuous Carbon Fiber Sucker Rod which is in the configuration of a reelable "tape" or "ribbon" with current dimensions of 1.45 in. x 0.212 in. It can be wound on a 10 ft diameter reel, 6 in. wide. It is designed to be run with some steel rods on the bottom similar to fiberglass rods. Its performance can be designed and analyzed using wave equation type mathematical models. This particular light weight material, for use as sucker rod replacement has been successfully tested in the lab and field over the past ten years. It was conceived as a method requiring no couplings, using a corrosion resistant, light weight material.
Performance of Hydraulic Fractures in High Permeability Formations
Authors: Hunt James L. , Chen Chih-Cheng , Soliman M. Y. 
Published: December 2007

Abstract
Fracpack is the hydraulic fracturing of high permeability (generally &gt; 10 md) formations to increase well productivity and control sand production. Fracturing aspects of the fracpack process have been discussed recently in the literature.1,2 However, the reservoir engineering aspects and justification for fracpack have not been extensively studied. The reservoir engineering aspects of fracturing low permeability formations have been widely documented throughout the petroleum literature.3 However, fracturing high permeability formations differs from fracturing low permeability formations. To ensure the success of a fracpack treatment, the candidate well needs to be chosen carefully with consideration given to rock mechanics, reservoir engineering and operational aspects of the fracpack process.
Generally, hydraulic fracturing is usually thought of as a technique to increase productivity or establish production in low permeability reservoirs. However, benefits can be realized by fracturing highly permeable formations that have formation damage and/or sand production tendencies. A well that has reduced permeability several feet or tens of feet away from the wellbore can be made more productive by fracturing through this damaged zone to contact undamaged reservoir. Reservoir fluids are thus provided an unrestricted pathway from undamaged reservoir to the wellbore. The conductivity within the fracture can be maximized so that pressure drop along the fracture itself can be held to a minimum. In the case of a well with sand production tendencies, a hydraulic fracture decreases the pressure drop necessary to produce the well at a given rate and changes the flow regime around the well such that sand production is minimized or eliminated. Thus the well may be produced at a rate higher than the unfractured critical sand producing rate.
Operationally, fracturing high permeability formations is different from fracturing low permeability formations due to the expected high leak-off rate, which influences fracturing pressure as a function of time. In addition, because of the desired high fracture conductivity, the concept of tip screen-out is applied. In tip screen-out, the fracture is designed in such a way that by the time the fracture reaches the desired length, the leading pad volume has leaked off into the formation. After the pad volume has leaked off, the presence of the proppant-laden-fluid at the leading edge of the fracture initiates the screen-out process. Continued injection of the proppant laden fluid causes the fracture to widen or balloon, reaching a greater than average width and high proppant concentration (a packed fracture). During the packing period, the fracturing pressure is expected to sharply increase.
Water/Oil Separation Characteristics of Daqing Oilfield Polymer Flooding Production Fluid
Authors: Jiachao Feng , Jiansen Zhao , Shaobing Chan , Chengjie Qu 
Published: December 2007

Abstract
As an effective EOR method, polymer flooding has been recognized all over the world for its excellent flooding effect under certain conditions, large scope of recovery percentage improvement and good economic benefit. However, because of the large quantity of polymer contained In the produced fluid from the polymer flooding areas, oil-water separation Is becoming more and more difficult. This article, based on the actural conditions of the polymer flooding pilots, and the data from the pilots, discuss the gravity settling separation characteristics and the characteristics of electro-chemical dehydration under the condition of produced fluid with various concentration of polymer, analyzing the effect of water phase viscosity increase of polymer onto the oil-water separation rate, oil-water emulslflcation intensity, water-cut varatlon of the produced fluid and the electrochemical dehydration. Some research directions and the problems which should be paid attention to are also put forward.
An Innovative Way to Produce and Transport Heavy Oil Through Dispersion in Water: Laboratory Study and Field Test Results
Authors: Bertero Luigi , DiLullo Alberto , Lentini Amelia , Terzi Luigi 
Published: December 2007

Abstract
A patented innovative system to produce and transport heavy and very viscous oils was developed in the laboratory and tested in the field. Results show a remarkable improvement comparing this system to the traditional ones based on the injection of a hydrocarbon diluent or of a surfactant solution to produce an oil-in-water emulsion.
The system is based on the injection of a water stream, to which a dispersing agent has been added, into the well without any modification of the existing completion. Field tests show that, as soon as the water solution comes into contact with the crude, an oil in water dispersion (70/30 oil-water ratio) is created with a viscosity 30-50 times lower than the viscosity of the diluted crude. A fourfold increase in oil production was also achieved compared to normal production with the injection of diluent.
The produced dispersion was pumped to the oil collection centre, 1 Km from the well, showing a decrease of friction losses along the pipe of six times that of the diluted crude. Temperature variation down to 5 °C does not affect viscosity while the diluted crude viscosity shows an increase by a factor of ten compared to the viscosity at normal ambient temperature (20-25 °C).
Separation of the dispersion depends on the dispersing agent concentration and on the degree of mixing of the dispersion itself.
Gravity separation produces a crude oil with a 6-8% water-cut. This was achieved without the addition of any demulsifier and using the same settling time normally used in the field facilities to separate the water-diluted crude mixtures. The residual water can then be separated with a traditional electrostatic separator.
Sensitivity Study of Foam Diversion Processes for Matrix Acidization
Authors: Kibodeaux K. R. , Zeilinger S. C. , Rossen W. R. 
Published: December 2007

ABSTRACT
Factors key to the success of foam diversion processes for matrix acidization were measured in Berea cores. Foam mobility was low in high-permeability (847-md) Berea and higher in low-permeability (92 md) Berea, suggesting effective foam diversion. Injection of surfactant solution, emulating foam-compatible acid injected following foam, trapped some of the foam in place, but imputed diversion of acid was not as complete as diversion of foam itself. After a period of injection of liquid, more gas was displaced, starting from the core inlet, and mobility rose further. Using these coreflood results, fractional-flow methods predict effective acid diversion between layers differing in permeability in field application. A sensitivity study indicates that the size of the preflush and the propagation rates of foam within rock are secondary factors in the success of foam diversion in the field. Foam strength and especially gas trapping following foam injection are the keys to successful application. In a process in which gas trapping following foam injection is ineffective, or is less effective in high-permeability layers, a continuous-injection foamed-acid process would outperform a process of alternating slugs of foam and acid. Further data, especially in field cores, are needed to confirm these conclusions.
How Effective is In-Situ Crosslinked Gelled Acid in Remedial Fracture-Acidizing Treatments?
Authors: Cramer D. D. 
Published: December 2007

Abstract
A study of remedial fracture-acidizing treatments in the Little Knife field indicates that treatments using in situ crosslinked gelled acid und er-performed treatments using a standard copolymer gelled acid system. This finding contradicts previous studies that claimed in situ crosslinked gelled acid treatments yielded a five-fold productivity improvement over ‘conventional" acid treatments in the same field.
Measuring Diffusion Coefficients in Acid Fracturing Fluids and Their Application to Gelled and Emulsified Acids
Authors: de Rozieres John , Chang F. F. , Sullivan R. B. 
Published: December 2007

ABSTRACT
To predict the length obtained from an acid fracturing treatment, acid fracturing models require that diffusion coefficients values be included in the equations describing the transport of the acid to the surface of the rock.
Numerous data have already been published for hydrochloric acid, but very often these data were not generated under conditions representative of the field. For instance, values for diffusion coefficients in straight acid are only available at low normality. In reality, acid fracturing models should use diffusion values for spent acid at a higher concentration.
Gelled and emulsified acids are also widely used in acid fracturing treatments leading to increased fracture length and conductivity due to decreased leakoff and a "retardation effect." Unfortunately, very few diffusion data are available for these fluids.
The diffusion coefficient of an ion in a fluid is a physical property which can be obtained from direct measurement. This paper presents measured diffusion coefficients for straight and gelled acids using both a diaphragm diffusion cell and a rotating disk apparatus. In addition, diffusion coefficients for emulsified acids, as obtained from the rotating disk apparatus, are also presented.