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IOR 1997 - 9th European Symposium on Improved Oil Recovery
- Conference date: 20 Oct 1997 - 22 Oct 1997
- Location: The Hague, Netherlands
- ISBN: 978-90-73781-08-5
- Published: 20 October 1997
21 - 40 of 72 results
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Finding a Regular Geometry for an Irregular Reservoir Shape for Well Performance Calculations
Authors D. H. Tehrani, G. Chen and J. M. PedenThe shape and geometry of the reservoir play an important rule in well pressure performance calculations by analytical methods. Dietz (1965) reported analytical solutions for a variety of regular shape reservoirs.
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Measurement of Gas-Oil Contact Angle at Reservoir Conditions
Authors Z. K. Al-Siyabi, A. Danesh, B. Tohidi and A. C. ToddSurface forces between rock and fluid system play a major role in the flow characteristics of fluids in hydrocarbon reservoirs, hence, the recovery of hydrocarbons in such media. In petroleum engineering, these forces are indexed by the interfacial tension (IFT) between different phases, and the contact angle between the reservoir rock and the fluids. The evaluation and alteration of these forces are essentul in planning, management and operation of reservoirs for optimum recovery.
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Effect of Fractional Flow Heterogeneity on Compositional and Immiscible Displacements
Authors S. K. Subramanian, R. T. Johns and B. DindorukThe scale of heterogeneities in reservoirs is often smaller than the grid size used in large scale reservoir simulations. Relative permeabilities have the foremost effect on fluid flow and small scale fractional flow must be upscaled to the grid size in flow simulations.
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The Design of a Miscible Gas Flood for the Wytch Farm Sherwood Reservoir
Authors P. F. Harrison, A. P. Cockin and R. C. SkinnerA miscible gas injection project has recently been sanctioned for the Wytch Farm Sherwood reservoir. Commencing during the second half of 1997, a total of 23mmscfpd of miscible gas will be injected into five wells in a Water AIternating Gas cycle, sweeping the reservoir through inverted nine-spot patterns. The project will be extended to a further five patterns over a ten year period to cover almost 50% of the reservoir. It is predicted that an incremental 12.6mmstb of oil reserves will be produced, but losing 10.6Bscf of sales gas and 443mtn of LPG to the reservoir.
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Wettability Heterogeneities in Gas Injection - Experiments and Modelling
Authors C. Laroche-Jaffrennou, O. Vizika and F. KalaydjianThe objective of the present work is to study the effect of wettability heterogeneities on: (1) displacement mechanisme, (2) sweep efficiency, and (3) trapped oil quantities and fluid distribution in three-phase gas injection.
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Sweep Efficiency in a Waterflooding Pattern Processed by Horizontal Wells
Authors C. G. Popa, F. Simion-Constantinescu and G. I. MarcuJoshi [1] derived an equation to compute the horizontal well production considering that the flow is symmetrical and similar to the flow into a pipe-like radial fracture. However this is a rode approximation especially for long and very long horiwntal well sections where the pressure loss along the well pipe shell be taken into consideration. Some results [2,3] have shown that the pressure loss can play a significant role on the horizontal well performances. On the other hand the pressure loss along the horizontal section generate a non uniform flux and potential distribution along the well. This well influence the front displacement in a waterflooding process.
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Water Quality and Well Injectivity
Authors L. Nabzar, J. -P. Coste and G. ChauveteauSmall particles suspended in injection waters may cause more severe permeability damages than larger ones. In addition, the deposition kinetics increases as velocity decreases so that substantial permeability damages are expected at large distances from injection wells where remediation is questionnable.
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A Production Well Foam Pilot in the North Sea Snorre Field - Application of Foam to Control Premature Gas Breakthrough
Authors I. Svorstøl, T. Blaker, M. J. Tham and A. HjellenThis paper discuses the design, field operatien, data acquisition and the performance of a foam pilot conducted in the North Sea Snorre field in mid-1996.
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Foams for GOR Control - Improved Stability by Polymer Additives
Authors M. G. Aarra, P. A. Ormehaug and A. SkaugeDisplacement tests in sandstone cores have been applied to quantify formation of foam and the gas blocking ability of water continuous foams with polymer additives. The different chemical properties of polymers and their interactions with surfactants made it intergisting to test both biopolymers and syrithetic polymers. Love mobility foams were generated both in Berea and reservoir core material with AOS based foams. The formation of foam with alphaolefinsulfonate surfactant was little influenced by polymer additives as indicated by similar foam properties throughout the core. The gas blocking ability of the foams was improved with polymer.
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Immiscible WAG Injection in the Fensfjord Formation of the Brage Oil Field
Authors A. Skauge and E. A. BergAn immiscible gas, WAG injection was initiated in the Fensfjord reservoir of the Brage Field late 1994. Two injection wells initially applied cyclic injection of gas and water. The pulse length of gas injection was about three months, and the W/G ratio has been close to 1:1. Gas breakthrough was observed after three months, according to expected breakthrough time from simulation studies. The WAG injection has later been expanded to six injection wells.
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Simulation Studies of WAG Using Three-Phase Relative Permeability Hysterises Models
By A. SkaugeA novel three-phase relative permeability hysteresis model has earlier been developed from experimental results. This paper has applied the three-phase hysteresis approach in simulations of three-phase flow situation and especially immiscible WAG.
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A Detailed Simulation Study of WAG Injection in a Heterogeneous Fluvial Reservoir Zone
Authors D. Kjønsvik, J. A. Stensen and J. AlvestadThe WAG performance in a water flooded high net-to-gross fluvial reservoir zone is compared to continoued water injection and tertiary gas injection. The reservoir model is a realistic, stochastic and detailed representation of a zone in a North Sea reservoir. The WAG process is studied in detail, with respect to fluid distributions in the inter-well volume and the attic volume for different production scenarios. A special focus is put on the influence of hysteresis in the gas relative permeability.
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Reduced Gas - Water Segregation by Use of Foam
Authors T. Holt and T. VassendenTwo dimensional laboratory experiments bas been performed in order to study the segregation of gas and water, and foam. The observed gas/water segregation was in good agreement with segregation theory, whereas foam segregation appears to be slower than predicted from theory, indicating an improved sweep efficiency by injection of foam. The latter observation is not conclusive, however, as all aspects of the foam experiments are not presently understood.
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Laboratory and Field Studies on Gravitational Effect in Low-Tension Waterflooding
Authors G. Gesztesi, M. Bodola, J. Török, J. Toth and B. MatingTheoretical considerations indicate the dominant role of gravitational force when emulsified oil flows in low-tension environment. Spontaneous segregation observed in vertically oriented sand columns suggests the gravity underride of the mobilizing micellar solution.
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Thin Under Gas Oil Rims - New Technology for Efficient Oil Production Using Foam Generating Oil/Water Polymers
Authors G. S. Stepanova, Y. G. Mamedov, I. A. Babayeva, A. A. Mosina, T. L. Nenartovich and A. A. LiWorldwide experience shows that oil production from thin onder gas cup zones with active aquifer is not efficient doe to quick gas/water breakthrough and depends on oil column thickness and the ratio between gas cap and oil part thickness. New WAG Technology based on injection of water solution of oil/water soluble polymers for efficient oil production from thin (5-15m) oil rims have been developed. Results of lab studies and simulation are discuseed. New WAG technology can be used for production of both, light and heavy oils. For heavy oils this technology can be considered to be as altemative to thermal EOR.
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Foam Propagation in Snorre Reservoir Core - Effects of Oil Saturation and Ageing
Authors K. Mannhardt and I. SvorstølA series of foam floods was conducted in Snorre reservoir core at 90°C and 300 bar, at different oil saturations. The rate of foam propagation and the time required to reach the maximum attainable apparent foam viscosity depended strongly on oil saturation. Apparent foam viscosity decreased steeply at a "critical " oil saturation of 13 to 15%. Extremely high apparent foam viscosities, up to 1000 cP, were generated at miscible gas flood residual oil saturation (13%). Above the critical oil saturation, strong foam with apparent viscosities of about 200 cP were still formed, compared to apparent gas viscosities in the absence of surfactant of 0 .5 to 0. 7 cP. The effect of gas composition (Snorre field gas, methane, nitrogen) on foam performance was minor. Significant residual gas mobility reduction was observed during gas injection into the foam-filled core.
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Role of Interfacial Rheological Properties of Oil/Water Systems in Mechanism and Design of EOR/IOR Technologies
Authors J. Lakatos-Szabó, I. Lakatos and B. KosztinInterfacial rheological properties of different Hungarian crude oil/water systems were determined in wide temperature and shear rate range and in the presence of inorganic electrolytes, tensides, alkaline materials and polymers. The detailed laboratory study definitely proved that the interfacial rheological properties are extremely sensitive parameters towards the chemical composition of immiscible liquids. Therefore, comparison and interpretation of the interfaciel rheological properties may contribute significantly to extension of the spectrum of the reservoir characterization, better understanding of the displacement mechanism, development of more profitable EOR/IOR methods, intensification of the surface technologies, optimization of the pipe line transportation and improvement of the refinery operations.
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Selective Fluid Shut-Off Treatments at the Algyõ Field, Hungary
Authors I. Lakatos, J. Lakatos-Szabó, S. Trömböcky, M. Bodola and G. PalásthyThe paper analyzes the field results of different selective fluid shut-off treatments carried out at the largest Hungarian oil field during the past decade. The polymer/silicate method was routinely and profitably used for water shut-off in oil producing wells. Recently a novel method based on is-site hydrolysis and flocculation of inorganic compounds is tested with the same goal. A complex foam/gel double injection technique was developed and used for restriction of gas conning in oil producing wells. Restriction of water conning and side invasion by injection of alcoholic polymer solutions into gas producing wells is also in the centre of field management. Although diverse experiences were obtained, the positive results and the substantial oil production entourage the experts to continue the laboratory and the field studies and to implement prospectful methods.
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