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IOR 1999 - 10th European Symposium on Improved Oil Recovery
- Conference date: 18 Aug 1999 - 20 Aug 1999
- Location: Brighton, UK
- ISBN: 978-90-73781-11-5
- Published: 18 August 1999
21 - 40 of 50 results
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Gas Tracer Modelling in Field Studies using a Conventional Reservoir Simulator
Authors A. Skauge and A. G. HansenThe objective of this work was to use gas tracers for production monitoring and reservoir management in a North Sea oil reservoir. The injection strategy for the field involved immiscible WAG and the field in question has experienced a period with pressure decline leading to production under bubble point, and is currently being repressurised. The tracer production has been simulated using a conventional reservoir simulator. We have treed to minimise the numerical diffusion by grid refinement, reduction of time step, and selecting different tracer modelling options.
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Risk Management for Production Below the Bubble Point
Authors M. A. Thompson, S. Goodyear, T. Fishlock and P. JonesThis paper develops methods which provide practical guidelines for the volume of reservoir around a production well that can "safely" be dropped below the bubble point without losing reservoir energy due to excessive gas production. The methods enable a gas production envelope to be calculated for vertical or horizontal wells in dipping reservoirs.
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Studies of Production under Bubblepoint
Authors A. Skauge, G. S. Haskjold, P. A. Ormehaug and M. G. AaraStudies of production under bubblepoint including both experiments and simulations are presented. A novel approach for modelmg of critical gas saturation is described. Depletion rate dependent critical gas saturation gave a different GOR development on individual Wells, and seems also to better match the production bistory. Experimental studies have investigated how production under bubblepoint effects the oil recovery. Waterflooding at condition below bubblepoint was compared to standard waterfloods above bubblepoint. The paper also summarize critical gas saturation data measured by different experimental techniques and conditions, and discusces the effect of different factors on the critical gas saturation.
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Quantifying Uncertainties in Reservoir Simulation - from Waterflooding to Improved Oil Recovery
More LessEvaluation of field performance and a long-term production forecast requires considerable resources spent on [numerical] reservoir simulation. Uncertainty in reservoir characterization and future prospects concerning oil price, operating cost, etc. advocates for sound sensitivity analysis which requires even more resources.
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Screening of IOR Methods Using a Fast Pre-Simulation Tool
Authors E. -M. Reich, L. Surguchev and L. LiSWORD is a tool for pre-simulation and screening of potential oil recovery methods. It is based on proven analytical solutions and allows fast evaluation of IOR/EOR methods. Water flooding, miscible gas injection, WAG injection, surfactant and/or polymer flooding are methods that can be evaluated by SWORD: The predictions are based on Dykstra-Parsons and vertical equilibrium solutions and gravity segregated three-phase flow modeling. Multicriterion analysis using artificial neural network approach provides fast assessment of IOR and well intervention methods applicability at different reservoir conditions.
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The Optimising of Layered Oil Field Development by the Rearrangement of Exploitation Plays
Authors E. M. Ponomarenko and N. A. EreminSelection of exploitation plays is an important part of oil field development projects. Our method of the layer similarity estimation allows to optimally distribute the layers in the exploitation plays. The main purpose of our method is to optimize the multitask wells performance and to decrease the technological risk. The technique of exploitation play selection is based on multicriterial decision-making approach and on fuzzy set theory.
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Principles of Combined Geologo-Technological Substantiation and Feasibility Prediction of EOR Methods Application in Fields of TPP "Lukoil-Kogalymneftegaz
Authors N. Sh. Khairedinov, S. M. Vainshtok, V. V. Kalinin and V. I. NekrasovThe problem of oil recovery is one of the fundamental problems of contemporary natural science. This problem is caused by complexity of hierarchic organization of oil-gas-geological system, by the imperfection of technologies applied for hydrocarbon extraction by inadequate level of scientific-methodological, industrial engineering and informational supervision of technologies under development.
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Rejuvenation of Highly Watered Reservoirs by Seismic Waves
More LessRejuvenation of highly watered reservoirs is very important task in the modern conditions because the number of depleted large reservoirs is increased with every year. The processes of gravitational filtration take place without human participation. The main result of our investigations is fact of jet mechanism of that kind of filtration. But as known such jets could be destroied or stopped by impermeable screens, so efficiency of natural processes is not significant.
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Drilling of Sidetracks for Improved Oil Recovery From Mature Fields
Authors R. N. Diyashev, R. S. Khisamov, R. G. Ramazanov, R. B. Khisamov and A. N. KhamidullinaMain problem at late stage of multilayer oil fields development by water flooding methods is decrease of oil production rate of wells and increase of water cutting of well production with existing unrecovered reserves in low permeable formations and isolated zones. Conventional methods of these oil reserves recovery are often low efficient.
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New In-situ Carbon Dioxide Generating Enhance Oil Recovery Technology
More LessMiscible/Immiscible carbon dioxide injection is considered to be as one of most effective technology to improve oil recovery from complicated formations, and hard to recover oil reserves, in particular. Application of this technology can increase ultimate oil recovery by 10-15% and even more [1]. One of the main advantage of this technology is that it can be applied in a wide range of geological conditions for production both light and heavy oils.
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Intelligent Systems for Optimized Reservoir Management and Improved Oil Recovery
By P. TubelTechnological advances in the oil and gas exploration and production (E&P) industry have improved the efficiency of the processes required to search and produce hydrocarbons. E&P companies can apply these advances in reservoir management techniques and system technologies to create intelligent, self-sufficient systems for exploring and producing hydrocarbons. These intelligent systems provide precise acces to hydrocarbons, optimal reservoir production over the asset life, and processing of produced fluids to improve oil recovery with minimal environmental impact. They can also help decrease the cost of producing hydrocarbons.
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The Use of Horizontal Wells to Optimise the Development of 2 Small, North Sea, Oil Fields
Authors L. Jolley, A. Frankenburg and A. LeonardThe Andrew and Cyrus fields are located in UKCS blocks 16/27a and 16/28, 230 km from Aberdeen. The reservoir is comprised of high net to gross Palaeocene, submarine fan sandstones. The oil and gas is trapped in four way dip closures over Permian salt domes. The fields were discovered in 1974 and 1979 respectively. Cyrus first oil production was in 1990 from a single well into a floating SWOPS vessel. Andrew field development was sanctioned in 1994, following an EWT in 1992, and production began in 1996 , 20+ years after its discovery. Horizontal production Wells, sub-sea technology on Cyrus; the Andrew Alliance and accelerated commissioning of a conventional platform design, transformed the discovertes from economically marginal to economically attractive developments.
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CHOP - Cold Heavy Oil Production
Authors M. B. Dusseault and S. El-SayedCold Heavy Oil Production (CHOP) involves encouragement and maintenance of sand influx as a deliberate production enhancement method in heavy oil solution gas drive reservoirs with no bottom water drive. In site foamy oil generation and flow help maintain sand flux, giving continuons stimulation and permeability enhancement. Also, generation of a continuous gas phase in heavy oil is greatly retarded, compared to conventional oil, thus preserving reservoir energy.
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Effect of Positive Rate Sensitivity and Inertia on Gas Condensate Relative Permeability at High Velocity
Authors G. D. Henderson, A. Danesh and D. TehraniThe authors have previously reported that gas condensate relative permeability will increase with increasing velocity when conducting steady-state measurements. The increase in relative permeability was referred to as "positive rate sensitivity" or the "positive coupling effect", with the initial studies having been conducted using a single core sample at two values of interfacial tension (IFT). A systematic series of core tests have since been completed which generated data for values of IFT ranging from 0.015 to 0.78 mN/m, using core types ranging in permeability from 11 to 350 md. The results confirmed that the positive coupling effect existed in low permeability cores and different lithologies at low and high IFT. The maximum tested velocity was in the region of 75 m/day, which was estimated to be at the boundary above which inertia would be significant.
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Calculating Well Deliverability in Gas Condensate Reservoirs
By R. MottWell deliverability in most gas condensate reservoirs is reduced by condensate banking when the well bottom hole pressure falls below the dew point, although the impact of condensate banking may be reduced due to improved mobility at high capillary number in the near-well region.
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Prediction of Offshore Viscous Oil Field Performance
Authors E. F. Balbinski, D. J. Element, S. Goodyear and A. J. JayasekeraDevelopment plans for UKCS viscous oil reservoirs use production profiles predicted by fullfield simulation models. The use of horizontal wells, possibly combined with other IOR techniques, and the unusually high vertical permeability of many of the fields, lead to a range of issues that need to be carefully considered when building simulation models and integrating laboratory data. This paper gives an overview of experience in modelling UKCS viscous oil fields, highlighting key issues that need to be addressed.
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Hydrodynamic Modeling of Multiphase Flow in Wells Numerical Simulation and Comparison with Field Data
Authors P. Lezeau, P. R. Keul and C. RevillardThe accurate modeling of the multiphase flows occurring in vertical, deviated, horizontal or multi-lateral wells is very important since it anticipates the pressure gradients and therefore the productivity of the wells.
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Correlations Between Natural Fracture Attributes and Equivalent Dual-Porosity Model
Authors S. Sarda, B. Bourbiaux and M. -C. CacasThanks to advanced fracture analysis software, seismic, structural, logging and core information on fractured reservoirs can now be integrated into distribution laws of fracture attributes such as density, length and orientation. In addition, the stochastic network images derived from these distributions can be converted into an equivalent dual-porosity model using an efficient methodology and computation procedures described in recent publications. This paper gives the results of an extensive application of this conversion tool to establish correlations between the distribution parameters of fracture attributes and the equivalent fracture permeabilities of the equivalent dual-porosity model. Geometrical attributes controlling connectivity of the fracture network have been studied on 2D images of a single fracture set: average density, dispersion of azimuths, fracture lengths average and dispersion. Furthermore, the effect of fracture conductivity dispersion han been studied. Analytical relationships have been defined and abacuses constructed for easy use in field applications. The percolation threshold of the fracture network has also been quantified as a function of fracture distribution parameters.
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Validation of Reservoir Static Models Using Welltest Data - an Interesting Case History
Authors F. Verga, P. Dalmasso, P. De Biase, S. Gruttadauria, M. Rovellini and D. VibertiA geostatistical modeling approach was used to simulate the fluvial depositional environment where overlying channel patterns create strong vertical and areal heterogeneity in the petrophysical propertjes of the reservoir.
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