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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
50 results
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Time Lapse Seismic as a Complementary Tool for Infill Drilling
Authors M. Landrø, L. K. Strønen, P. Digranes, O. A. Solheim and E. HildeTime lapse seismic data have improved the drainage understanding of the Gullfaks oil field, and have resulted in several potential new infill drilling targets. The baseline survey was acquired in 1985, one year before production start-up. Since then, two more surveys have been acquired, one in 1995, and another one in 1996. Key elements in the proces of reducing the uncertainties are cross-disciplinary verifications and detailed geophysical analysis and modelling, where different saturation profiles are input to the model. In order to include the interpretational uncertainties in the proces of quantifying the amount of remaining oil for each of the observations, the volume estimates are presented as probability curves.
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Well Planning in a Cave
Authors M. Midttun, R. Helland and A. N. HaalandNew virtual reality and visualization technology defines a new work environment both for individual experts and for larger groups or multidisciplinary asset teams. With this technology, data can be combined and presented in more intuitive ways and new methods for data interaction can be developed. The technology has the potential of improving quality and reducing turnaround for different work processes in the E&P industry. In 1997 Norsk Hydro installed a virtual reality CAVE laboratory and started the development of an integrated software system for seismic interpretation, reservoir modeling and well planning in virtual environments. Since late 1998 the system has been in active use on the Troll oil field for well planning and monitoring of wells during drilling. This paper summarizes the early experience from this activity.
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Multi Target Wells
More LessThe Vienna basin is a sedimentary basin of more than 10 km thickness and includes more than a dozen HC-layers. Since the area has been highly explored in the past 50 years only small reservoirs or compartments of already existing reservoirs can be expected to be found. However, existing infrastructure, such as pipelines, facilities and a nearby refinery would make even small finds attractive. In this light it was and is of eital importance to reduce risk and costs in HC exploration and production.
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Technical and Commercial Success on a Multi-Lateral Infill Drilling Project
Authors C. J. Brown, A. Scott and A. RichardsonDuring the second phase of Infill Drilling (Phase 2 IFD) at Wytch Farm, a 460HP workover rig converted four existing wells to > 1km departure horizontal multi-lateral wells. The project was a complete success technically, economically, and in terms of HS&E performance , productivity and oil recovery.
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Surfactant Concentration for Foam Formation and Propagation in Snorre Reservoir Core
Authors K. Mannhardt and I. SvorstølFoam floods were conducted in an oil-free Snorre field core with C14-16AOS surfactant and methane or Snorre field gas, at 90°C and 300 bar. The lowest surfactant concentration at which foam was generated overlapped the cmc region. Concentrations exceeding the cmc were required to propagate the foam, independently of surfactant adsorption. Once formed and propagated, the foam could be maintained for prolonged periods of gas/liquid co-injection at sub-cmc or zero surfactant concentrations.
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A Unified Model for Steady-State Foam Behavior at High and Low Foam Qualities
Authors J. M. Alverez, H. Rivas and W. R. RossenFoams are used on a pilot basis to divert gas flow in improved-oil-recovery projects. The complexity of foam behavior and apparent contradictions between foam studies has bedeviled attempts to onderstand foams and design effective field treatments.
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A Review of Cold Production in Heavy Oil Reservoirs
Authors B. Tremblay, G. Sedgwick and D. VuThe cold production process, in which sand and oil are produced simultaneously under primary conditions, has been economically successful in several unconsolidated heavy oil fields in Alberta and Saskatchewan, Canada. This review will first describe the field studies that have been performed by oil producers to understand the mechanisme involved in cold production including: tracer tests, gamma ray tests. The laboratory studies performed by different research organizations, including ARC, on the mechanisms involved in cold production: foamy oil drive, geo-mechanics, sand erosion, sand transport will be reviewed.
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Comparative Combustion Kinetics for In-Situ Combustion Process
Authors M. V. Kök and C. Ö. KeskinIn this research thermal characteristics and combustion kinetics of three crude oils (13-27 °API) veere investigated using DuPont 9900 thermal analysis system (TG/DTG) . A sample size of 10 mg., heating rate of 10 °C/min. were used in the temperature range of 20-700 °C under air atmosphere.
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Air Injection into Light Oil Reservoirs - Exothermicity and Kinetics of Crude Oil Oxidation
Authors M. Greaves, O. A. Osindero and R. RathboneGas Injection into light oil reservoirs is capable of achieving substantial incremental Improved Oil Recovery (IOR), providing that gas is available and considerable additional investment is not required. The availability of gas, especially in areas like the North Sea, is a critical factor affecting oil recovery economics. Air meets this criteria, on the basis that the oxygen can be effectively removed in the reservoir.
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Combined Physico-Chemical and Microbiological EOR Method
Authors L. I. Svarovskaya, L. K. Altunina and Z. A. RozhenkovaThe use of a combined physico-chemical and microbiological EOR method is promising for flooded oil fields of West Siberia, which are rich in hydrocarbon-oxidising microflora. The method is based on injection of oil displacing system containing a multicomponent nitrous substrate as a nutrition source for the formation microflora.
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Abnormal Viscosity Behaviour of Near Critical Fluids, Experimental Data and Modelling
Authors Z. Al-Siyabi, A. Danesh, B. Tohidi, D. H. Tehrani and A. C. ToddThe discovery of high pressure-high temperature (HPHT) reservoirs in various parts of the world and the increased possibility of encountering near critical fluids during primary depletion or IOR processes has emphasied the importance of having reliable techniques for predicting the physical properties of these fluids at these adverse conditions.
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Measurement and Interpretation of Three-Phase Capillary Pressure by Centrifuge
Authors G. A. Virnovsky and J. E. IversenThe paper describes the results of research aimed at measurements of capillary pressures and residual oil saturations in centrifuge under three-phase flow conditions. To analyze the data measured during a three-phase centrifuge test, an interpretation procedure based on theoretical analysis of capillary equilibrium in the field of centrifugal force is derived.
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Lagomar's Integrated Field Laboratory for Intensive Evaluation of Technologies
Authors G. De Carvajal, A. Velasquez, J. Graterol, F. Ramirez, M. Medina and R. GuimeransPDVSA's light oilfields in Lake Maracaibo have been onder exploitation for more than foor decades. To date, the expected recovery factor is only 29% of the OOIP. As these resources approach maturity, it has been realized that improving recovery will demand the earliest use of many technologies, proven and new, in an integrated manher and tailored to solve specific regional problems. The Integrated Field Laboratory (IFL) philosophy is one of PDVSA's main technology strategies designed to accomplish these goals. Three Field Laboratories are being developed in the Maracaibo Lake Basin: one for heavy oils and two for light oils: shallow and deep reservoirs.
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Cyclic Water Injection: Improved Oil Recovery at Zero Cost
Authors L. M. Surguchev, A. Koundin, O. B. Melberg, T. A. Rolfsvag and W. P. MenardCyclic injection is a process that improves waterflooding efficiency in heterogeneous reservoirs. The concept of cyclic injection is based on (1) pulsed injection and (2) altemating waterflood patterns. Cyclic injection has been successfully applied in a number of sandstone and carbonate oil fields in Russia. In the rest of the world, pulsed injection has had limited application, and only in naturally fractured reservoirs. Although changing the waterflood patterns is a common approach to deal with increasing water cuts a more systematic approach with both pulsed injection and alternating flow directions is not.
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Use of Core and Well Test Analysis to Improve Models for Stress-Sensitive Reservoirs
Authors T. A. Jelmert, H. Selseng and O. TorsæterThe permeability of stress-sensitive reservoirs are characterized by functions rather than single numbers. Permeability functions obtained by well testing may be thought of as some average on the length scale of the drainage area.
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Identification of the Permeability Heterogeneity of Laboratory Cores by Tracer Displacement
Authors L. Zhan and Y. C. YortsosWe propose a novel approach for the identification of the permeability heterogeneity, based on the analysis of the concentration contours in the miscible displacement of a passive tracer. By monitoring the displacement fronts at successive (and closely spaced) time intervals, the permeability heterogeneity can be obtained from the solution of a boundary-value problem. The method was tested successfully using synthetic data in 2-D geometry, involving a variety of heterogeneity including layered systems, and correlated permeability fields. An extension to anisotropic system is also described. The method finds application in the identification of the permeability heterogeneity of laboratory samples. The possibility of the extension to the field scale application is also discussed.
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Foam Assisted Water Alternating Gas (FAWAG) Process on Snorre
Authors H. A. Martinsen and F. VassendenThe FAWAG (Foam Assisted Water Alternating Gas) project is a full-scale demonstration by Saga Petroleum of the use of foam for gas mobility control. The foam injection started in the Central Fault Block (CFB) of the Snorre field in August 1998, after a two-year planning period, and many years of active research on foam. The first phase of the project, a Surfactant Alternating Gas (SAG) injection was completed in late November 1998. A co-injection phase was carried during January to June 1999. Approximately 1800 tons of commercial grade surfactant was used in this project.
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The Perspectives of Using Gas Technologies for Reef Oil Fields Development
Authors V. P. Davydov, Y. N. Yagafarov, Yu. A. Kotenyov and V. Ye. AndreyevIn the Republic of Bashkortostan gas EOR methods have been commercially introduced in fields related to the Lower Permian age reft masses of Preural foredeep.
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Effect of Lean and Inert Gases on Interfacial Properties in Ultra Light Oil Reservoirs
Authors I. Lakatos, K. Bauer, J. Lakatos-Szábo, S. Puskás, G. Y. Palásthy, S. Trömböczky and B. KosztinApplication of lean gases, particularly a methane rich gas, nitrogen, carbon dioxide, air and their mixtures in an ultra light oil bearing reservoir located in Southern Hungary, is in an advanced stage. The relevant studies and mathematical simulations have definitely indicated a substantial surplus oil production and it was also revealed that gravity segregation and vaporization of light hydrocarbons were the main elements of the displacement mechanism.
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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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Up-scaling Laboratory Velocity data to Field Measurements
Authors J. Khazanehdari, C. McCann and J. SothcottIn this work we have tried to explore the practicality of up-scaling laboratory velocity data to field measurements. This was done by conducting a series of laboratory measurements on samples from two shoreface facies sandstone hydrocarbon reservoirs from the North Sea. The acoustic measurements were conducted at room temperature and at confining pressures ranging from 5 MPa up to 45 MPa. The measurements were carried out on vacuum dry, brine- and oilsaturated samples. The ultrasonic data were compared with a sonic laboratory measurement and up-scaled to the wireline velocity data.
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Upscaling on General Quadrilateral Grids in 3D with Application to Field Cases
Authors C. F. Eek-Jensen, I. Aavatsmark and Ø. BøeThis paper presents an upscaling method designed for upscaling of absolute permeability on general quadrilateral grids, i.e., grids with skewed cells. The method is based on conservation of dissipation and periodic boundary conditions.
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A Neural Network for Modelling Well Interactions
Authors R. Ramberger and G. ZanglThe Austrian field Hochleiten at the margin of the Vierma basin is highly compartmentalised, due to intensive faulting. Moreover, the reservoir sands are mainly of deltaic origin and thus often laterally heterogeneous. Because of these discontinuities, a waterflooding program in the field did not work as desired. Seismic and geology give the general framework of the reservoir architecture, but the details of sandbody connections cannot be assessed in this way.
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A Steady-State Approach to Upscale relative Permeabilities and it's Application in 2D
Authors G. Virnovsky and H. A. FriisWe present a model for efficient direct upscaling of two-phase relative permeabilities by solving a series of steady state, two-phase problems. The developed numerical model simulates steadystate multiphase flow in 2 and 3D in heterogeneous reservoirs with account for viscous, capillary and gravity forces at a given external pressure drop. It is used to compute effective properties for a synthetic heterogeneous reservoir. The presented examples show the dependence of effective relative permeabilities and residual oil saturation on the magnitude of the pressure drop applied to the boundaries of the flow domain. The convergence of the effective relative permeabilities towards the viscous limit functions is analyzed in 1 and 2D.
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Modelling Conductive Faults With a Multiscale Approach Involving Segregation Concept
Authors N. Henn, B. Bourbiaux, M. Quintard and S. SakthikumarReservoir engineers have underlined the difficulties to get both good physical representation and numerical performance in modelleng conductive faults. The present work proposes a representative and efficient model to simulate multiphase flows in highly faulted fields. Our model uses the gravity segregation concept to represent flows in the fault planes. The segregated model has been coupled to a conventional black-oil reservoir simulator modelling the matrix flows within the fault panels. This paper describes the model with its physical basis. Validations against finely-gridded simulations for multiphase displacements in a fault panel are also presented.
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Seismic and Rheochemical Technologies for Improving Productive Oil Capacity of Pay Zones and Monitoring of These Technologies
Hard-to-recover reserves whose development by traditional technologies is low effectave or even impossible sometimes, play the growing role in the oil reserves balance of oil fields being under a long-term production.
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Streamline Based Simulations
More LessWith four examples distinct qualifications of the streamline methodology are demonstrated: numerical dispersion free mass transport, fast computer runs, application in inverse modeling and a suggested approach to model compressible flow.
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An Innovative New Combination of Coiled Tubing Tools Which Enables Multiple Re-Entry into Open Hole Laterals Without Any Pre-Placed Datum Devices in the Completion During the Well Construction Phase
By C. HillsThis paper summarises the evolution of coiled tubing tools from the simple jetting nozzle
through to the highly advanced multi-function multi shot tools currently in use today. The paper
goes on to illustrate an innovative method devised for entering open hole laterals as a direct
response to demand for cost effective well maintenance solutions against a backdrop of low oil
prices. The tool illustrated is an evolution of existing knowledge on re-entry technology
combined with the best features of current multi-function coiled tubing manipulation tools. The
new solution allows repeated acces to lateral junctions without the need for special completion
components during the well construction phase.
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