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IOR 1991 - 6th European Symposium on Improved Oil Recovery
- Conference date: 21 May 1991 - 23 May 1991
- Location: Stavanger, Norway
- ISBN: 978-94-6282-133-0
- Published: 21 May 1991
21 - 40 of 100 results
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The representation of thermally fractured water injection wells in black-oil simulators
Authors P. Fjerstad and P. CliffordIt is widely recognized that the cooling of the reservoir rock by cold water injection changes the rock stresses around the welIbore and in the immediate surroundings of the injection well. The cooling of tbe rock causes the rock fracture pressure to decrease and the possibility of fracturing the formation might occur.
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Pendant drop interfacial tension measurements using image processing techniques
Authors R. J. M. Huygens, H. Ronde and J. HagoortInterfacial tensions are important parameters in recovery processes, particularly in Enhanced Oil Recovery processes. Hence for the evaluation of these processes reliable and accurate measurement techniques for interfacial tensions are indispensable.
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The influence of the oil composition on the phase behavior and properties of surfactant/brine/crude oil-systems
Authors G. Hoffmann and D. KesselFor the better understanding of crude oil mobilization process with surfactant flooding, the effects of ethoxylated sulfonates and salinity on some crude oil/- surfactantlbrine systems were investigated. The results clearly show that for fixed temperature salinity and surfactant are mainly responsible for the formation of three-phase-systems and for the distribution of the different components of the crude oil in the different phases of these systems. When aqueous solutions of ethoxylated sulfonates with a distinct degree of ethoxylation are equilibrated with an equal volume of crude oil, a middle-phase microemulsion (ME phase) will be formed in aspecific salinity range. It could be shown that the solubilized crude oil in the middle phase consists of a wide range of components, such as alkanes, alkylated cyclohexanes, alkylated benzenes, isoprenoids, alkylated phenanthrenes, and aromatic steroids.
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Supercritical fluids for enhancing recovery in a gas condensate reservoir lab experiments and field test
More LessMiscibility between LPG mixtures at supercritical conditions with both liquid hydrocarbons resulted from retrograde condensation in a gas condensate reservoir and the reservoir gas was proved by lab experiments. A field test partially confirmed the possibility of increasing the productivity of some wells blocked by liquid hydrocarbons deposits around the wells
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Increase of formations oil recovery by application of polymerdispersive systems
More LessSeams with low collecting properties remain unexhausted during oil-fields exploitation by means of water flooding as a result of a complex structure of productive formations. To solve this problem a technology of influencing on oil-and- water-saturated formations based on the increase of the filtration resistance of oil collector flooded zones by means of dispersive systems (PDS), consisting of polymers and dispersive particles of rocks, is worked out.
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Operation experience obtained by production facilities of the Nagylengyel CO2 gas cap recovery
Authors D. Magyary and G. UdvardiNagylengyel Field is the second and largest oil field in Hungary. bearing formations can be found in Cretaceous limestones and Triassic do lomites. According to the developed karsttype reservoir model, oil reserves are located in caverns. Unrestricted influx is mainly provided by the water in the karst facies formations. During primary recovery operation, the produced oil oil contained only little dissolved gas if any.
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Optimization of a surfactant flooding process by core flood experiments
Authors A. Skauge, J. M. Garnes, O. J. Morner and L. TorskeAs a part of the preparation for a surfactant flooding pilot in a North Sea oil reservoir, several hundred core flood experiments have been performed. This paper summarizes the experience obtained from these core floods.
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lOR Resource potential of Norwegian North Sea sandstone reservoirs
Authors L. Hinderaker, J. Bygdevoll, T. Bu, G. Nybraten and O. S. KrakstadThe potential for improved oil recovery by surfactant flooding and by water alternating gas injection (WAG) in Norwegian North Sea sandstone reservoirs has been evaluated. 15 fields containing various formations and reservoirs have been studied, some very roughly and some in more detail. Reservoir types that seem to be suitable for surfactant flooding or for WAG have been identified. The volume of remaining oil after waterftood has been taken as a starting point in these fields to obtain a range for the potential increase in oil reserves. Other IOR-methods with a possible recovery potential are discussed briefly. Finally some attention is given to the timing of EOR projects from a national perspective.
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How reservoir characterization can help to improve production forecasts
Authors D. R. Guérillot, P. M. Lemouzy and C. RavenneGeological models using statistical concepts bring a new horizon for reservoir engineering studies. This article discusses some of the questions raised by the introduction of these geological models, and a methodology is proposed to account for the heterogeneities in the reservoir production, based on a specific software. A link between the detailed reservoir images generated by the probabilistic geological models, and the well-known flow simulators is established through the selection of these images, and the averaging of the petrophysical data. The use of stochastic partial derivative equations is investigated as another way of dealing with uncertainty. After a description of the main steps of the integrated software, applications of the methodology to major events of a reservoir development, i.e. appraisal phase, and change of development scheme, are presented. Advantages of the stochastic approach are underlined.
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Relevant reservoir characterisation: Recovery process, geometry and scale
Authors P. S. Ringrose, K. S. Sorbie, F. Feghi, G. E. Pickup and J. L. JensenIn this paper, we consider the role of reservoir description in the context of the specific improved oil recovery process which is of interest. Three types of representation of reservoir structure are considered - stochastic correlated fields, stratified layer-cake, and deterministic structured bedforms. The relevance of different features of these representations are then considered for a variety of secondary and tertiary recovery fluid displacement processes. In some processes, detailed structure is insignificant. In others, it is more important than hitherto supposed. There is no panacea for reservoir characterisation and the critical reservoir properties must be determinedby considering both the fluid recovery mechanism and the interaction of this mechanism with the specific type of model representation of the reservoir system.
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Moheres, a program system for simulation of reservoir architecture and properties
Authors L. M. Fält, A. Henriquez, L. Holden and H. TjelmelandThe design and choice of a reservoir management strategy depends on an appropriate geological reservoir characterization, i.e. the geometrical distribution of the sedimentological architectural units, their position with respect to each other and the heterogeneities in each of these bodies.
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Stochastic flow unit modelling of a North Sea coastal-deltaic reservoir
Authors A. C. MacDonald, T. H. Høye, P. Lowry, T. Jacobsen, J. O. Aasen and A. O. GrindheimThe main theme of this paper is to illustrate that stochastic heterogeneity simulation provides improved flexibility to represent important geological attributes in a reservoir description model.
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The case for air injection into deep, light oil reservoirs
Authors D. V. Yannimaras, A. H. Sufi and M. R. FassihiThe advantages of air injection for deep, light oil reservoirs are elucidated and discussed, particularly those that accrue in high-pressure applications. Examples of successful field projects are provided and analyzed. Experimental results on light oil oxidation kinetics with air at high pressure are presented, as weIl as results for the stripping of a light oil by flue gas at reservoir pressure. Requirements for highpressure combustion tubes are discussed. The adequacy of three numerical simulators are compared in their ability to model high-pressure air injection into light oil reservoirs. Simulation results on light oil stripping by flue gas and the increase in recovery due to in-situ combustion, by mobilizing the gas drive residual oil, are also presented. Finally, guidance on economic parameters is provided.
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Injection of an oxygen-containing gas into a light-oil reservoir: Numercial evaluation of oil oxidation and ignition phenomena
Authors P. Le Thiez and P. LemonnierCO2 or methane injection is a recovery process often used for a large variety of reservoirs. Economical considerations should lead to inject a cheaper gas, generally air or nitrogen with a poor oxygen content. Under severe conditions of pressure and temperature (e.g. typical North Sea light-oil reservoir), one of the main risks related to th is last process is the oil oxidation leading to chemical degradation and even spontaneous ignition. It is therefore a prime necessity to determine accurately the oil oxidation rate, the delay of a possible ignition and the extension of the oxidation zone, which strongly depend on eperating conditions, reservoir characteristics and oil oxidability (mainly pressure, temperature and reaction kinetic parameters).
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Rheology of foam in porous media at the "limiting capillary pressure
By W. R. RossenRecent research suggests that, for some "strong" foams, foam texture, which controls foam rheology, is in turn closely controlled by capillary pressure Pc. In particular, at steady state these foams flow under conditions in which Pc is nearly constant at the "limiting capillary pressure" Pc*, water saturation and water relative permeability are virtually invariant, and the pressure gradient Vp is proportional to water flow rate and independent of gas flow rate. This report examines some implications of these statements for cases of steady foam flow.
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The destabilization of foams for improved oil recovery by crude oils: Effect of the nature of the oil
Authors L. L. Schramm and J. J. NovosadThis paper describes an investigation into the effects of four different oils on the stability of foams that could be used in enhanced oil recovery (EOR).
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Foam barriers for thin oil rims: Gas blockage at reservoir conditions
Authors J. E. Hanssen and M. DallandCreation of in situ foam barriers to gas flow is a potentially useful means of improving production from thin oil rims, but it requires the foam to maintain gas blockage in the reservoir for extended periods.
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Cyclic gas-steam well stimulations
Authors Yu. I. Stashok, D. G. Antoniady, R. T. Drampov and A. R. GarushevThe paper describes schematic diagram and blocks of a gassteam generator. Technical characteristics and overall dimensions of the generatoris main units are analysed. The analysis proves the suitability of generators of such a kind for high-viscosity and bituminous oil recovery in the littoral shelf by cyclic bottom-hole formation zone stimulation with gas-steam heat-carrier* in particular.
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Field trial results obtained with a foam block during a steam drive experiment in the Romanian Levantine-moreni Reservoir
Authors C. S. Elliot, C. H. Aldea, D. Calarasu, F. L. Teisanu, M. Jiboteanu and G. GutuThis paper presents results obtained by the use of nitrogen foam as a diverting agent in the injection well of a pattem used in the Levantine-Moreni reservoir steam drive experiment.
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A Theory of multicomponent chromatography with application to polymer flooding
Authors T. Johansen, L. W. Lake, A. Tveito and R. WintherThe first part of this paper presents a new procedure for constructing analytical solutions of multicomponent two-phase flow problems in one-dimensional homogeneous penneable media, provided the corresponding simpler single-phase problem can be solved. An explanation of its mathematical basis is given.
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