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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
41 - 60 of 100 results
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Xanthan injection in North Sea Field: Laboratory studies
Authors A. Audibert, J. Lecourtier and T. LundThe methodology used for selecting the polymer having the best characteristics for injection in North Sea reservoirs, particularly at 75°C, is described.
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Influence of pore radi distribution on polymer retention in natural sandstones
Authors M. Ranjbar, J. Rupp and G. PruschIn polymer flooding processes for enhancing oil recovery, polymer retention is a major economic factor which limits the applicability of this technique. Polymer retention occurs mainly by the following two mechanisms: - adsorption of polymer molecules on the surface of accessible pores, and - mechanical entrapment in small pores in a manner similar to the process of deep bed filtration.
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Polymer retention and inaccessable pore volume in North Sea reservoir material
Authors T. Lund, E. Ø. Bjørnestad, A. Stavland, N. B. Gjøvilki, A. J. P. Fletcher, S. G. Flew and S. P. LambAmong the factors that govern the propagation of a polymer slug through porous media are retention and inaccessible pore volume (IPV). These quantities are sensitive to several parameters which often vary in coreflood experiments. Examples of these sensitivies include the core preparation procedure such as core cleaning and saturation restoration.
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Application of a synthetic copolymer under harsh environment conditions in the Ploen-Ost Field
Authors W. Schuhbauer, B. Maitin and H. VolzIn the Ploen-Ost field in Northern Germany, a polymer pilot flood is being carried out under harsh reservoir conditions.
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A Commercial scale xanthan polymer flood project in a high salinity, low viscosity oil reservoir
Authors W. Littmann, G. Kleppe and T. LundA commercial scale polymer pilot project is performed in cooperation between Preussag and BEB in Germany and Statoil in Norway.
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Alternate dual-engergy gamma-ray attenuation technique: A new tool for three-fluid saturation measurements in lOR flood experiments
Authors C. Barroux, L. Bouvier, P. Maquignon and B. ThiebotMany oil recovery processes, such as gas injection or gas-cap expansion in an already water-flooded zone, or water-alternate-gas flooding, involve three-phase flow. A new dual-energy gamma-ray attenuation technique is described, which allows for gas, oil, water saturation profile measurements during the physical simulation of improved oil recovery processes at reservoir conditions.
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Use of variations in strontium isotope ratios for mapping barriers: An example from the Troll Field, Norwegian continental shelf
By K. GibbonsCritical to production of the 12 to 28 meter truck oil column from horizontal wells in the Western Troll Field is an evaluation of the lateral extent of calcite cemented horizons. On average, 10% of the 200 meter truck main reservoir, is calcite cemented. Cements vary from nodules and concretions to stratiform layers .1 to .5 meters truck.
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Acoustic tomography for improved oil recovery
Authors J. H. Justice, A. A. Vassiliou, M. E. Mathisen, W. H. Troyer and P. S. CunninghamIn order to fully realize the reserve and economic potential of our reservoirs, attention is now being focused on the reservoir as a domain worthy of detailed study and planning. Successful reservoir management in the future will combine results from many disciplines to formulate a development and surveillance program for the reservoir. This plan will be periodically updated as new data is acquired and interpreted.
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Applying a novel steam-CO2 combination process in heavy oil and tar sands
By R. L. EsonIt is estimated that there are 85-110 billion barrels of heavy oil reserves in the U.S.. Since the 1960's, steam has been the predominant Enhanced Oil Recovery (EOR) method for these high viscosity, heavy oil reservoirs world-wide. However, some experimentation utilizing immiscible carbondioxide injection in heavy oil reservoirs has shown encouraging results. This paper documents the efforts of a 2-1/2 year, two phase project conducted in the Midway-Sunset field of California applying a novel steam/carbon-dioxide combination process to reeover heavy oil.
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Advanced vibroseismic technique for water flooded reservoir stimulation, mechanism and field tests results
Authors E. M. Simkin and M. L. SurguchevTheoretical and experimental studies show significant changes in flow properties of water-oil and water-oil- gas systems within the field of elastic vibrations. It results in multiple acceleration of the gravity segregation, increase of gas saturation of the reservoir fluids, rate and efficiency of capillar displacement as weIl as enhancement of the oil displacement by water. Newly designed technology of vibroseismic stimulation incorporating surface energy sources has been successfully tested in two depleted oil fields being at the late stage of waterflooding.
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Pilot tests of biogeotechnology applied to enhance oil recovery
Authors S. S. Belyaev, M. V. Ivanov, A. A. Matz and A. Yu. BorisovThe technology to enhance oil recovery of oil-bearing strata based on the targeted activation of stratal microflora and, first of all, hydrocarbon-oxidizing and methanogenic bacteria, was developed. The first stage of activation involves the aeration of water pumped into a stratum with mineral nitrogen and phosporus salts added
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Rheotechnology - A New trend in oil production technology
Authors A. H. Mirzajanzade and I. M. AmetovThe paper presents a review of the major results in the field of the rheotechnological methods for oil production. Also shown are the peculiarities of heavy oil production, abnormal temperatures in particular. The advantages of the, new technology based on monitoring of viscoelastic properties of oil and the applied systems are presented.
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A Comparison of reservoir management options for high relief light oil reservoirs
Authors J. D. M. Belgrave and W. R. HovdetadThis paper documents a systematic investigation of gravity stable recovery strategies for light oil reservoirs, using an equation of state compositional simulator on a Cyber 205 supercomputer.
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On the aspects of reservoir fluids phase behavior important in design of miscible gas injection processes
By Z. NovosadThe study examines features of oil and injection gas (solvent) phase behaviour that control the mechanism of mass transfer in EOR by miscible gas injection.
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Minimum miscibility pressure calculations including effects of three phase equilibria
By M. P. WalshThis work presents the first equation-of-state (EOS) algorithm to compute minimum miscibility pressures (MMP) in hydrocarbon systems exhibiting three-phase (L-L-V) equilibria. Previous efforts have been limited to systems involving only two-phase equilibria. This work is particularly applicable to low-temperature reservoirs since they often exhibit L-L-V phase behavior. A comparison of twoand three-phase algorithrn results shows that the two-phase algorithm may overpredict the MMP in cases where three-phase equilibria is realized. The results of a CO2 - West Texas oil system show that the error by the two-phase algorithm is significant and the three-phase algorithm offered here should be used.
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Miscible gas EOR in a partially cooled reservoir
Authors S. T. Lee, P. J. Kisha, D. M. Grist and P. J. BriggsThe effect of cold-water induced reservoir cooling on tertiary gas injection processes is investigated. Numerical and analytical models of fluid and heat flows are employed to analyse the reservoir cooling phenomena. For the conditions studied, the injected water cools a significant volume of the reservoir. The altered formation temperature distribution affects significantly the displacement and sweep efficiencies, from the phasebehaviour point of view. Equation-of-state and compositional simulation approaches are adopted to analyse and quantify this effect. It is shown that a partially cooled hydrocarbon formation. can bring about a significantly larger tertiary oil bank than that without considering the temperature alteration.
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Mobility control experience in the Joffre Viking miscible carbon dioxide flood
Authors D. J. Stephenson, A. G. Graham and R. W. LuhningThe first CO2 miscible flood in Canada is located in a field that had been waterflooded to its economic limit and abandoned in 1965. Carbon dioxide alternating water injection commenced in January 1984 and incremental recovery from the initial experimental area has exceeded 20% of original oil- in - place bringing total recovery to over 60%. Although oil recovery has been excellent numerical simulation studies suggest that less than half the formation in this area has been contacted by carbon dioxide.
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Gas flooding of the Statfjord reservoir, Statfjord Field
Authors S. A. Haugen and S. HaalandGas has been injected into the Statfjord reservoir in the Statfjord Field for more than ten years. The reservoir is a heterogeneous sandstone reservoir of Jurassic age and is not considered as an ideal candidate for gas injection. The displacement is more gravity stable than originally anticipated, and currently a large gas cap has been established on top of the reservoir. A low residual oil saturation is expected behind the gas front. The gas flood is believed to be a multicontact miscible process. Fluid sampling from the field has shown minor transfer of molecules between the oil and gas phases. An aggressive drainage strategy and frequent well interventions have contributed to a high recovery from the Statfjord reservoir.
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Deep diverting gels for very cost effective waterflood control
Authors A. J. P. Fletcher, S. Flew, I. N. Forsdyke, J. C. Morgan, C. Rogers and D. SuttlesPlacement of gels in depth is an effective approach to Improving waterflood sweep efficiency, particularly In layered reservoirs. The process can give significant and timely additional oil compared with the waterflood baseline. It can be low cost, and operationally convenient. There are a number of possible approaches to ensuring gel is formed where needed, and nowhere else. In the present case, advantage is taken of the thermal gradient set up when cold water is injected into a hot reservoir (or aquifer). The position of the cold front can be modelled to at least sufficient accuracy to ensure correct gel placement.
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Conformance control gels - Formation by contact with brine
Authors I. E. Whittington and D. G. NaaeNew technology for gel treatments has been developed. The gel is formed when a solution of a water-soluble polymer (hydroxypropylcellulose, HPC) and a surfactant (sodium dodecyl sulfate, SDS) mixes with brine. While conventional gels use a chemical initiator or activator, such as a heavy metal like chromium, to form the gel, the new HPC/SDS gel uses the salinity of the connate brine to initiate the gel formation.
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