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IOR 2005 - 13th European Symposium on Improved Oil Recovery
- Conference date: 25 Apr 2005 - 27 Apr 2005
- Location: Budapest, Hungary
- Published: 25 April 2005
1 - 50 of 80 results
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Fractured Reservoir Modelling – Recent Progress and Promising Perspectives
Authors B. Bourbiaux, R. Basquet, A. Lange and L.Y. HuC01 FRACTURED RESERVOIR MODELLING – RECENT PROGRESS AND PROMISING PERSPECTIVES 1 B. Bourbiaux R. Basquet A. Lange and L.Y. Hu IFP 1& 4 Avenue de Bois-Préau 92852 RUEIL-MALMAISON Cedex FRANCE Abstract In the last decade the petroleum industry became more and more aware of the necessity to take into account fractures and faults to optimise oil field production and recovery. The main reasons include an improved fracture detection from efficient logging tools and from an improved interpretation of high-quality seismic data. Moreover production difficulties -such as early breakthroughs- are met in an increasing number of mature fields where the impact
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Restarting a History-Matching Study for an Existing Reservoir Model
Authors M. Le Ravalec-Dupin and F. RoggeroC02 RESTARTING A HISTORY-MATCHING STUDY FOR AN EXISTING RESERVOIR MODEL Abstract 1 Sometimes reservoir engineers want to update a previously built reservoir model to integrate newly collected data. Unfortunately the data used to generate the existing reservoir model are often lost. To avoid restarting the history-matching study from the very beginning we developed several techniques to infer the missing data. These data consist of a random function characterized by geostatistical parameters and a set of random numbers. The existing reservoir model is the realization associated to the estimated random numbers given the estimated random function. Once the random function and
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Using Seismic Velocities to Improve Permeability Estimation of a Carbonate Reservoir
Authors E. Hassanzadeh, I. Maddahi and F. TalebiC03 USING SEISMIC VELOCITIES TO IMPROVE PERMEABILITY ESTIMATION OF A CARBONATE RESERVOIR Abstract 1 Permeability is one of the most important factors for quality assessment of a carbonate reservoir; furthermore mapping the permeability over an exploratory carbonate oil field is of essential importance. The area under study is a newly explored oil field containing carbonate reserves of Cretaceous age located in the southwest Iran and covered by 3D seismic data. It is well known that carbonates have different types of porosity that affect permeability and seismic wave propagation; therefore these facts can be used for integrated permeability studies of such
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Pore-to-Field Multi-Phase Upscaling for a Depressurization Process
Authors T.G. Theting, A.B. Rustad, T.R. Lerdahl, J.Å. Stensen, T. Boassen, P.-E. Øren, S. Bakke and P. RingroseC04 PORE-TO-FIELD MULTI-PHASE UPSCALING FOR A DEPRESSURIZATION PROCESS Abstract 1 This paper describes the application of a multi-step multi-phase upscaling technique to the Statfjord Field a mature oil field located in the North Sea. The method is aimed at consistently accounting for the effects of small-scale heterogeneities on field simulations. In this work special attention is given to the small-scale (pore- to lithofacies-scale) modeling and upscaling for a pressure depletion process in a water flooded reservoir. Five different lithofacies models for the Rannoch and Tarbert Formations were created. Both formations are central in the studied field and consequently have been
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Upscaling for Improved Oil Recovery
Authors G.E. Pickup, P. Zhang and M.A. ChristieC05 UPSCALING FOR IMPROVED OIL RECOVERY Abstract 1 Upscaling for the simulation of IOR processes is a big challenge for several reasons. Firstly the geological model may be complex in order to resolve important structures such as channels or shales and to target remaining oil. Secondly the recovery processes also tend to be complex involving two-phase or three-phase flow. Careful flow simulation is therefore required to estimate oil recovery. Many upscaling methods have been developed to reduce the number of cells in a geological model so that the models can be used for flow simulation. Inevitably coarse-scale simulations are less
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Flexible Upscaling Using Perturbed Boundary Conditions
Authors L. Ricard, M. Le Ravalec-Dupin and Y. GuéguenC06 Flexible upscaling using perturbed boundary conditions L.RICARD M. LE RAVALEC-DUPIN Y. GUÉGUEN Abstract 1 This paper presents a new technique for upscaling absolute permeabilities on coarse CPG grids. Within this framework traditional upscaling methods depend on arbitrary local boundary conditions. They are fairly accurate for lognormal fields but they fail for channelized fields and highly heterogeneous systems. The method introduced in this paper takes advantage of global fluid flow simulations to select pertinent local boundary conditions. These ones are then used for upscaling permeabilities. To reduce interpolation errors and to be independent from fluid flow numerical simulation schemes we
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Modeling Induced Fractures in a Dynamic Flow Simulation
More LessC07 MODELING INDUCED FRACTURES IN A DYNAMIC FLOW SIMULATION Abstract 1 This work presents a new and powerful method for modeling fractures – and especially induced fractures – in a dynamic flow simulation to predict well performance. The method aims to accurately model the behaviour of hydraulically fractured wells and to forecast the behaviour of reservoirs under the influence of fractures. Many wells are stimulated by hydraulic fractures to improve well performance. Most reservoir simulators can not appropriately handle those situations due to limitations in the discretization methods or due to limitations in the numerical formulation incorporated in the simulation
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Estimation of Water Saturation from Tracer Data
Authors S.O. Stalheim and R. KlevenC08 ESTIMATION OF WATER SATURATION FROM TRACER DATA Abstract In the coming years production from the Norwegian Shelf will decline and the main focus will be concentrated on smaller fields and mature fields. Thus the importance of minimizing the uncertainty of infill drilling and other IOR methods will increase with the decreasing economic margins. 1 The key to successful reservoir management is a thorough understanding of all the available data how they are obtained and carefully integrated into a consistent and reliable model. The major factor for deciding to adopt IOR strategies as the drilling target is the spatial distribution
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Optimisation of SAGD Processes by Injection of Light/Heavy Hydrocarbons
By G. DarcheC10 OPTIMISATION OF SAGD PROCESSES BY INJECTION OF LIGHT/HEAVY HYDROCARBONS Abstract 1 In this paper we will use thermal simulations of “steam+solvent” processes to investigate the influence of the composition of the co-injected hydrocarbon on the efficiency of the thermal recovery of heavy oil or bitumen. Effectively theoretically “steam+solvent” injection would work best with a pure component like n-hexane or n-heptane since this component would condense approximately in the same pressure-temperature conditions as steam and thus would mix with heated bitumen thus reducing their viscosity. However from a practical point of view more industrial solvents easily available like naphthas will
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Improved Thermal-Steam Treatment of High-Viscosity Oil Pools by CO2 Generating Systems
Authors L.K. Altunina and V. KuvshinovC12 IMPROVED THERMAL-STEAM TREATMENT OF HIGH-VISCOSITY OIL POOLS BY СО2 GENERATING SYSTEMS Abstract 1 A novel technology has been developed to enhance oil recovery from reservoirs containing highviscosity oils. The technology combines thermal-steam and physico-chemical treatments using surfactant-based systems which are capable to generate СО2 and alkaline ammonium buffer solution in situ. Pilot tests of EOR technology were successfully carried out both in Russia and China. In Russia 264 m 3 of 50 % solution of oil-displacing system were injected into three steaminjection wells in the area of Permocarbonic high-viscosity oil pool Usinskoye oil field. In 1-3 months the production
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Wettability Alteraion and Imbibition Effects in Steam Recovery from Matrix Blocks in Fractured Reservoirs
Authors S. Motealleh, B.-R. de Zwart and J. BruiningC13 WETTABILITY ALTERATION AND IMBIBITION EFFECTS IN STEAM RECOVERY FROM MATRIX BLOCKS IN FRACTURED RESERVOIRS Abstract 1 Imbibition in matrix blocks is one of the most important mechanisms for oil recovery from fractured reservoirs. However imbibition is impeded if the matrix blocks are oil-wet. The alteration of wetting from oil-wet to water-wet enhances the recovery. Contact angle measurements show that steam (high temperature) alters the wetting properties. Therefore steam injection has been suggested as an alternative for water drive. Still the mechanism of thermally induced wetting changes remains unclear. Moreover a change in contact angle only indicates the possibility of
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Thermal Modeling Analysis for Completion Design of Deep Offshore Heavy Oil Reservoirs
Authors F.A. Ascanio and L.G. SchoelingC14 THERMAL MODELING ANALYSIS FOR COMPLETION DESIGN OF DEEP OFFSHORE HEAVY OIL RESERVOIRS Abstract 1 This paper examines the theoretical application of wellbore heat losses in the completion design of deep offshore heavy oil reservoirs. As production of heavy and viscous oil moves through the wellbore dynamic transfer of heat occurs between the produced fluids and the surroundings. For a deep offshore reservoir this challenge needs to be properly addressed. Simulations were performed to evaluate these challenges based on the impact that they generate on the flow rate artificial lift injection rate hydraulic fluid circulation rate tubing size and the
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Selection of Optimum Thermal Recovery Method for a Heavy Oil Reservoir of Iran
Authors F. Rashidi and B. Sedaee SolaC16 SELECTION OF OPTIMUM THERMAL RECOVERY METHOD FOR A HEAVY OIL RESERVOIR OF IRAN Abstract 1 Thermal recovery is the most important enhanced oil recovery for heavy oils and the predominant mechanism of these methods is viscosity reduction. These methods fall into two classes: Heat injection and heat generation in reservoir. In this study various thermal recovery methods have been investigated and feasibility of these methods for an Iranian heavy oil reservoir with 17.5 API has been studied. Actual reservoir model was constructed by using commercial softwares and all the aforementioned methods were simulated. Results show that continues steam injection
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Low Salinity Oil Recovery – The Role of Reservoir Condition Corefloods
Authors K.J. Webb, C.J.J. Black and I.J. EdmondsC18 LOW SALINITY OIL RECOVERY – THE ROLE OF RESERVOIR CONDITION COREFLOODS Abstract 1 There is much published data in the literature showing that waterflood recovery is dependent on the composition especially the salinity of the injection brine. These data however have all been generated at conditions which are not representative of the reservoir and therefore it has not been demonstrated that these potential EOR benefits are applicable to real reservoir situations. Reservoir condition coreflood studies using live crude oil and brine were therefore performed on a number of different reservoir systems to determine whether the recovery benefits seen in
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Improved Oil Recovery by Wettability Alteration
Authors Y.C. Araujo and M. AraujoC19 IMPROVED OIL RECOVERY BY WETTABILITY ALTERATION Abstract 1 In the last few decades oil companies have developed several oil recovery methods motivated by the fact that over 50% of the oil in place remains trapped in the formation due to several factors including adverse wettability conditions. Such recovery processes tend to be very costly in their application due to the nature of the injection fluids and/or surfactants used. This fact motivates research for other processes more economically viable. To achieve such goal it is essential the understanding of the mechanisms that control wetting and the fundamentals of rock-fluid interactions.
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Linked Polymer Solutions for Improved Recovery by Waterflooding
Authors A. Skauge, M.G. Aarra, M. Bjørsvik, H. Høiland, T. Skodvin and D. StandnesC20 LINKED POLYMER SOLUTIONS FOR IMPROVED OIL RECOVERY BY WATERFLOODING Abstract 1 MORTEN G. AARRA MAGNY BJØRSVIK HARALD HØILAND TORE SKODVIN DAG STANDNES AND ARNE SKAUGE Centre for Integrated Petroleum Research CIPR University of Bergen Bergen Norway Polymer gel treatments have been widely used to improve sweep efficiency or to reduce production of unwanted water. In this study we have focused on identifying systems for in-depth mobility control to increase sweep efficiency during water flooding. The systems are sometimes referred to as linked polymer systems (LPS) or colloidal dispersion gels (CDG). LPS can be a useful EOR method for oil
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A Comparative Evaluation of Fracturing Techniques, Relating Economic Benefits to Alternative Approaches in Zonal Isolation and Selectivity
Authors K. Furui and J. FothergillC21 A Comparative Evaluation of Fracturing Techniques Relating Economic Benefits to Alternative Approaches in Zonal Isolation and Selectivity Abstract 1 Advantages and cost / benefit evaluations associated with the decision to risk capital for the expectation of justifiable returns on fracturing and stimulation procedures have progressively improved in sophistication and accuracy of predictions. The evolution in software supporting the engineering disciplines as well as the wealth of empirical data have combined to improve returns both in procedural efficiencies and reductions of risk. This paper will review techniques relating to fracturing and stimulation procedures evolving from the basic casing frac through
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Gel Treatment of Injectors – Theory and Practice
Authors K.M. Fedorov, N.E. Pavlov and V.E. AndreevC22 GEL TREATMENT OF INJECTORS –THEORY AND PRACTICE Abstract 1 FEDOROV K.M. (TYUMEN STATE UNIVERSITY) PAVLOV N.E. (RNTC LUKOIL-WEST SIBERIA) ANDREEV V.E. (BASHKIRIAN ACADEMY OF SCIENCES) Semakova st. 10 Tyumen 625003 RUSSIA Gel treatment of producers and injectors is a common field operation for waterflood conformance improvement in West Siberia. The purpose of the method application is flow diverting in a reservoir stratification and sweep improvement. The method is usually applied on the last stage of field development when water breakthrough leads to the high watercut in the production fluid. The analysis of field practice of the Urai department of
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Shallow Perforation Shut-Off with a New Gel-Cement System
More LessC23 SHALLOW PERFORATION SHUT-OFF WITH A NEW GEL-CEMENT SYTEM Abstract 1 Jip van Eijden* and Fred Arkesteijn Shell International Exploration and Production Diederik van Batenburg and Paul McGinn Halliburton Jacques van Vliet Al Furat Petroleum Company *Kesslerpark 1 2288 GD Rijswijk(ZH) The Netherlands Water production in the North-east of Syria has increased significantly in recent years. As a result costs per barrel of oil have increased and production is currently constrained by the facilities capacity. PLT surveys combined with a reservoir study showed that good-quality sands were not properly swept by the water probably due to poor connectivity in the
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Water Shutoff Using Oil-Soluble Chemicals – An X-Ray CT Study
Authors K. Elewaut and P.L.J. ZithaC24 WATER SHUTOFF USING OIL-SOLUBLE CHEMICALS – AN X-RAY CT STUDY Abstract 1 Koenraad Elewaut and Pacelli L.J. Zitha Mijnbouwstraat 120 2628 RX Delft The Netherlands [email protected] We investigate the modification of porous media properties for reducing water production in oil wells using a novel chemical which is soluble in oil without any chemical reactions but when brought in contact water reacts and forms a stable gel. This oil-soluble chemical (OSC) is deemed capable of reducing considerably the risk of damaging oil bearing layers during bullhead water control treatments. We present an experimental study of the emplacement of the OSC
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Scales, Scaling and Scale-Up
By L.W. LakeC25 SCALES SCALING AND SCALE-UP 1 Much engineering practice involves the manipulation and understanding of scales. The existence of scales seem to intrinsically evident from observations. But it is also evident that scales has a highly elastic meaning that is at the least a barrier for communication among disciplines and at the most is a source of error. This presentation reviews the idea behind scales and what they mean to petrophysical properties. There are 4 central ideas all related. The first idea the motivation for the remainder of the presentation is that all petrophysical properties seem to depend on scale
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Displacement of High-Viscosity Oil Using Microorganisms
Authors L.I. Svarovskaya, L.K. Altunina and V.S. OvsyannikovaC26 DISPLACEMENT OF HIGH-VISCOSITY OIL USING MICROORGANISMS Abstract 1 A complex method for enhanced oil recovery has been developed at the Institute of Petroleum Chemistry. This is a combination of physical chemical and microbiological techniques aimed at enhancing the efficiency of oil displacement from high-viscosity oil reservoirs employing multicomponent oil displacement systems with high detergent properties. The oil displacement systems used comprise hydrolyzed carbamide solution that is readily assimilated by microorganisms which enhances the geochemical processes involved in the microbial activity and brings about metabolism product accumulation and hence an improvement in the rheological properties of the oil. In view
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Interpretation of Microbial Oil Recovery from Laboratory Experiments
Authors E. Kowalewski, I. Rueslåtten, E. Gilje, E. Sunde, G. Bødtker, B.L.P. Lillebø, T. Torsvik, J.Å. Stensen, B. Bjørkvik and K.A. StrandC27 INTERPRETATION OF MICROBIAL OIL RECOVERY FROM LABORATORY EXPERIMENTS Abstract 1 Microbial Improved Oil Recovery (MIOR) involves stimulation of oil-degrading bacteria in order to mobilize previously trapped and bypassed oil. This paper presents a bacteria stimulated aerobic core experiment together with microbiological analyses and measurements of the impact aerobic bacteria may have on the interfacial tension (IFT). In addition the potential for improved recovery when including the measured IFT reduction is investigated by simulating a surfactant flood on a field scale model. The effect of microbial activity on relative permeabilities residual oil saturation IFT wetting properties etc. is important in
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Laboratory Study of 'Super' Surfactants as Candidates in Surfactant Flooding
Authors I. Lakatos, J. Tóth, Z. Bedö, J. Lakatos-Szabó, M. Hlatki, S. Puskás, P.D. Berger and C. LeeC28 Laboratory Study of “Super” Surfactants as Candidates in Surfactant Flooding Abstract 1 Extensive application of IOR/EOR methods represent a focus in rejuvenation strategy of matured oil fields operated by the Hungary Oil and Gas Plc. Among others the SAP and SA+P methods as mainstays may significantly contribute to improvement of both the sweep and displacement efficiency. Therefore the fundamental point of the laboratory experiments was the screening of newly developed “super” surfactants. The detailed study comprised the determination of surface and interfacial tension CMC bulk and interfacial rheological properties transmission and backscattering photon correlation analysis of micelle properties and
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Thermal Method of Gas Hydrate Fields Development
Authors K.S. Basniev, A.V. Nifantov and A.V. ShchebetovC30 THERMAL METHOD OF GAS HYDRATE FIELDS DEVELOPMENT Abstract 1 Gas hydrates are naturally occurring solid compounds of water and gas that are considered as alternative for conventional energy in the near future. In accordance with the latest estimations potential reserves of gas in hydrates in the world exceed conventional ones in many times. Taking into account instability of oil prices gas hydrates could play a great role in world’s energy balance. Gas hydrate field development technology of using the deep subterranean thermal water heat of underlying bed has been proposed. The 3D mathematical decomposition model has been developed. It
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Effects to be Considered When Planning Late Stage Depressurisation
Authors A. Skauge, D. Standnes and Ø. PettersenC31 EFFECTS TO BE CONSIDERED WHEN PLANNING LATE STAGE DEPRESSURISATION 1 DAG STANDNES ARNE SKAUGE AND ØYSTEIN PETTERSEN Centre for Integrated Petroleum Research University of Bergen Bergen Norway Abstract The main effects of depressurisation influencing oil recovery is changes in; fluid properties fluid saturation phase mobilities and rock properties. This paper includes a mechanistic simulation study including effects involved in depressurisation. The emphasis of this paper is special effects related to rock compaction which may occur during depressurization (DP) in mature oil fields. Empirical data indicate that reservoirs containing high-permeability channels (kc) in a background (kb) of more low-permeability soil
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Downhole Gasification for Improved Oil Recovery
Authors M. Greaves, T.X. Xia, R.R. Rathbone and A.H. BentaherIOR-C32 DOWNHOLE GASIFICATION FOR IMPROVED OIL RECOVERY AUTHOR(S) Abstract 1 M. GREAVES T. X. XIA R. R. RATHBONE AND A. H. BENTAHER Address Improved Oil Recovery Group Department of Chemical Engineering University of Bath Bath BA2 7AY England A new unique IOR concept has been investigated for application in light oil reservoirs that have been previously water flooded but which can be applied at any stage of oil production. The method operates via GSGI (gravity stabilized gas injection) but does not require the injection of displacement gas from the surface. Instead gas is generated in situ using a downhole (underground)
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Waterflooding of Fractured Carbonate Reservoirs
Authors T. Austad, S. Strand, E.J. Hønesen and P. ZhangD01 WATERFLOODING OF FRACTURED CARBONATE RESERVOIRS Abstract The wetting nature of a carbonate reservoir determines the potential of improved oil recovery by water injection especially if the formation is highly fractured which often is the case for chalk formations. The exceptional good response of seawater injection into the Ekofisk chalk formation is an indication of a special rock-water interaction which improves the spontaneous displacement of oil. In the present paper we will summarize the results from ongoing research to improve spontaneous imbibition of water into oil-containing chalk samples at various wetting states and temperatures. The chemical composition of the imbibing
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Qualitative and Quantitative Study of Asphaltenes Precipitation During a Gas Injection Project
Authors S. Sfakiotakis, N. Pasadakis, N. Varotsis and H.P. HjermstadD02 QUALITATIVE AND QUANTITATIVE STUDY OF ASPHALTENES PRECIPITATION DURING A GAS INJECTION PROJECT Abstract 1 Laboratory and field data from the Snorre reservoir oil in the North Sea confirm that asphaltenes due to the fact that they precipitate when the oil in which they are contained is subjected to considerable compositional changes can be used as a natural tracer for monitoring the success of a gas miscible flooding during IOR projects. The field data reveal that the change of GOR in producing wells affects the asphaltenes content of the producing oil only in the cases where injection gas has gone
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Waterflood Efficiency for Different Pore Classes in Carbonate Reservoirs
Authors A. Skauge, K. Spildo, A. Lønøy, G. Njøten and B. OttesenD03 WATERFLOOD EFFICIENCY FOR DIFFERENT PORE CLASSES IN CARBONATE RESERVOIRS 1 Abstract Carbonate reservoirs are usually very heterogeneous and contain a wide range of different pore classes. The main pore classes are primary and secondary interparticle pores mouldic pores intercrystalline pores and also chalk and chalky microporosity. In this paper we have studied limestone cores with intercrystalline macroporosity patchy intercrystalline mesoporosity and dolomite cores with mouldic micropores Single phase dispersion was measured by injecting a slug of water tracer. The dispersion characteristics can give information about the amount of dead-end pores inaccessible pore volume and hydraulic mixing due to the
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Improved Procedure for alculating Unsteady-State Relative Permeability
Authors A.S. Lackner and O. Torsaeter1 D04 Improved Procedure for Calculating Unsteady- State Relative Permeability A.S. Lackner and O. Torsæter Abstract Department of Petroleum Engineering and Applied Geophysics the Norwegian University of Science and Technology (NTNU) Norway The effects of capillary number viscosity-ratio and heterogeneity on unsteady - state calculated relative permeability were evaluated. Flow data from simulated waterflooded cores were generated in a 1D black-oil simulation model. Two different methods were used to calculate water and oil relative permeability from the output simulated flow data: First a traditional method that requires measured pressure drop versus time and cumulative volumes produced and second a method
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Contact Angle Determination Using Logs and Capillary Pressures for a Carbonate Reservoir
Authors F. Rashidi and B. Sedaee SolaD05 CONTACT ANGLE DETERMINATION USING LOGS AND CAPILLARY PRESSURES FOR A CARBONATE RESERVOIR Abstract 1 Distribution of fluids in a porous media is directly affected by rock Wettability. Therefore Know adage this parameter is necessary for optimum production. Data obtained from well log analysis is representative of real reservoir condition and therefore these data could be converted to water saturation profiles. On the other hand laboratory capillary pressures can be converted to saturation pressures. In this paper Wettability of an Iranian reservoir rock has been investigated by comparison between log and capillary pressure data. Results reviewed that this rock is
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Characterization of Sulfur in Reservoir Rocks by Rock-Eval Analysis
Authors F. Lorant, R. Antonas and J. EspitalieD06 CHARACTERIZATION OF SULFUR IN RESERVOIR ROCKS BY ROCK-EVAL ANALYSIS Abstract 1 As a result of steam or hot water injection reservoir rocks can generate significant amounts of H2S. Such recovery operations are therefore subject to corrosion and environmental risks which are currently difficult to predict. Previous works have shown that the formation of H2S is thermally induced by the alteration of organic sulfur in heavy oils (aquathermolysis). Other phenomena involving interactions between mineral sulfur (sulfates pyrite) and organic matter have been reported as sources of H2S as well. According to the current knowledge on these processes H2S can occur
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Interpretation of Displacement Data Obtained from Unsteady-State Radial Fluid Flow Systems
More LessD07 INTERPRETATION OF DISPLACEMENT DATA OBTAINED FROM UNSTEADY-STATE RADIAL FLUID FLOW SYSTEMS Abstract 1 This paper presents the practical interpretation formulae which can be used for determination of the relative permeability data obtained from immiscible fluid displacement experiments. The derived formulations are convenient to determine the relative permeability curves the Leverett functions and the displacement efficiency. The results were validated by using the laboratory data obtained by lateral immiscible fluid displacement in horizontal porous disks. For this purpose the convenient interpretation formulae elaborated and demonstrated by the authors (1998 2002) earlier for determination of relative permeability from unsteady-state twophase linear
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Experimental Evaluation of H2S Yields in Reservoir Rocks Submitted to Steam Injection
Authors V. Lamoureux-Var and F. LorantD08 EXPERIMENTAL EVALUATION OF H2S YIELDS IN RESERVOIR ROCKS SUBMITTED TO STEAM INJECTION Abstract 1 Steam injection can induce H2S generation resulting from physicochemical transformations of sulfur compounds in reservoirs at temperatures from 200°C to 300°C: reactions between organic sulfur compounds and water (aquathermolysis) organic and mineral interactions (sulfate reduction and/or pyrite oxidation). The occurrence of these processes depends on the availability of the different sources of sulfur in reservoirs: organic sulfur sulfates and pyrite. The organic and mineral sulfur contents of bulk reservoir rocks might therefore be correlated to the yield of H2S that is potentially generated within reservoirs
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Miscible Gas Injection Issues in a Thick Carbonate Volatile Oil Reservoir
Authors P.G. Denby, L. Tealdi, M. Vert and L. FranciaD09 MISCIBLE GAS INJECTION ISSUES IN A THICK CARBONATE VOLATILE OIL RESERVOIR Abstract 1 This paper discusses a number of challenges around the development by miscible gas reinjection of the Kashagan field situated in the North Caspian. The Kashagan field is a highly pressured sour carbonate oil reservoir. Due to the lack of a significant local gas market and the cost associated with treating the sour products re-injection of the associated gas is intended from early in the field development. This is not only environmentally and economically very sound but will also significantly enhance the recovery efficiency due to the
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Three-Phase Relative Permeabilities and Capillary Pressure by Upscaling
Authors A. Lohne, G.A. Virnovsky and A. HiorthD10 THREE-PHASE RELATIVE PERMEABILITIES AND CAPILLARY PRESSURE BY UPSCALING Abstract 1 Three phase flow properties are important for correct modeling and prediction of such IOR processes as WAG and blow-down/depletion after waterflooding. On the core-scale these properties can generally by obtained directly from experiments (though this is not usually done) from pore-scale modeling of threephase flow or from empiric formulae interpolating two sets of two-phase data oil-water and oil-gas which are supposed to have been measured into the three-phase saturation region like the ones proposed by Stone. For the usage in the simulator the core scale properties have to be
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Application of a New Upscaling Technique to a Miscible Gas Injection Field Study
Authors M.-H. Hui, L.J. Durlofsky and X.-H. WenD11 APPLICATION OF A NEW UPSCALING TECHNIQUE TO A MISCIBLE GAS INJECTION FIELD STUDY Abstract 1 A novel miscible upscaling technique incorporating the use of effective flux boundary conditions and an extended Todd & Longstaff treatment of upscaled relative permeabilities was recently developed and successfully applied to synthetic 2D permeability fields. In this work we extend the overall upscaling procedure to nonuniform 3D grids and apply it to a miscible gas injection field study. A near-well upscaling procedure is also incorporated into the methodology. It is shown that the original fine grid model must be refined areally to achieve numerical
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Numerical and Experimental Investigation into the Mechanisms of First Contact Miscible Simultaneous and Slug WAG Injection
Authors H. Al-Shuraiqi, A. Muggeridge and C.A. Grattoni1 D12 Numerical and Experimental Investigation into the Mechanisms of First Contact Miscible Simultaneous and Slug WAG Injection H. AL-SHURAIQI A. MUGGERIDGE and C.A. GRATTONI Department of Earth Science and Engineering Imperial College SW7 2AZ London United Kingdom Abstract Miscible Water-Alternate-Gas (WAG) injection is currently being performed in many fields around the world and a large number of numerical studies investigating both simultaneous and slug injection including the effects of slug sizes gravity and heterogeneity have been carried out in the past. However there are few laboratory studies to support the numerical work and to understand the interactions between injected
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Fluid Flow Properties of WAG Injection Processes
More LessD13 FLUID FLOW PROPERTIES OF WAG INJECTION PROCESSES Abstract 1 Immiscible water-alternating-gas (IWAG) experiments performed on equilibrated fluids are summarised together with the corresponding two-phase gas-oil and water-oil displacements. Experimental studies at reservoir condition and also mechanistic experiments over many years have shown accelerated oil production and higher core flood oil recovery as a result of three-phase flow. The three-phase effects that are included and analysed are; trapped gas and mobility for secondary processes (ex. water after gas injection). The oil recovery from the different oil recovery processes represented by; gas water and WAG core displacements are also compared. The
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CO2 Injection for IOR and Storage – Opportunities and Challenges for the North Sea
Authors S.R. Ren, F. Gozalpour and B. TohidiD14 CO2 INJECTION FOR IOR AND STORAGE – OPPORTUNITIES AND CHALLENGES FOR THE NORTH SEA Abstract 1 CO2 injection for improved oil recovery (IOR) has been extensively investigated and is commercially pursued in many onshore fields around the world. Concerns over greenhouse gas emissions are leading to the investigation and realisation of its potential as a carbon storage method in recent years. With right reservoir conditions injection of CO2 into oil reservoirs can result in incremental oil recovery and permanent storage of CO2 in geological formation. The North Sea has been considered as a good CO2 storage site for Europe.
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Air Injection in Light-Oil Fractured Reservoirs – A Review of Challenging Reservoir Modelling Aspects
Authors M. Okamoto and B. BourbiauxD15 A REVIEW OF THE CHALLENGING RESERVOIR ENGINEERING ASPECTS OF MODELING THE RECOVERY FROM A LIGHT OIL FRACTURED RESERVOIR BY AIR INJECTION Abstract 1 MARURO OKAMOTO AND BERNARD BOURBIAUX INSTITUT FRANÇAIS DU PÉTROLE (IFP) 1-4 Avenue de Bois Préau 92852 Rueil Malmaison cedex France Although often considered as a thermal recovery method concerning heavy oil reservoirs air injection can be an economical IOR option for light oil reservoirs. Actually unlike other gas injection processes involving a marketable or synthetic gas the air injection method offers the main advantage of an unlimited availability for any field. However especially for fractured reservoirs
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A Review of the Challenging Reservoir Engineering Aspects of Modeling the Recovery from a Light Oil, Fractured Reservoir by Air Injection
Authors A.H. Bentaher, M. Greaves and R.R. RathboneD16 AIR INJECTION INTO LIGHT OIL RESERVOIRS – OXIDATION KINETICS AND SIMULATION AUTHOR(S) Abstract 1 M. GREAVES A. H. BENTAHER AND R. R. RATHBONE Address Improved Oil Recovery Group Department of Chemical Engineering University of Bath Bath BA2 7AY England Air injection into deep light oil reservoirs which have previously been water flooded is a very promising IOR technology. The process of air injection is considered a cheaper injectant gas alternative to using hydrocarbon gas carbon dioxide or nitrogen because it is freely available. The process can also be made sustainable and clean if the produced carbon dioxide is reinjected
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Problems and Prospects of Gas Methods for Enhancing the Reservoir Hydrocarbon Recovery
More LessD17 PROBLEMS AND PROSPECTS OF GAS METHODS FOR ENHANCING THE RESERVOIR HYDROCARBON RECOVERY Abstract 1 13 th European Symposium on Improved Oil Recovery — Budapest Hungary 25 - 27 April 2005 R.M. TER-SARKISOV VNIIGAZ Razvilka Leninsky District Moscow Region 142717 Russia The paper presents natural and man-caused factors that govern the existence and formation of hard-to-extract hydrocarbon (HC) reserves in the process of their development. A conceptual approach to the problem of enhancing gas condensate recovery by involving hard-to-extract HC reserves into active development at various stages of their recovery from reservoir is described. It was shown that a formed
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Fluid Flow Behaviour of Gas-Condensate and Near-Miscible Fluids at the Pore Scale
Authors C.A. Grattoni and R.A. DaweD18 Fluid Flow Behaviour of Gas-Condensate and Near-Miscible Fluids at the Pore Scale Abstract 1 RICHARD A. DAWE 1 AND CARLOS A. GRATTONI 2 1 Department of Chemical Engineering University of West Indies St. Augustine Trinidad 2 Department of Earth Science and Engineering Imperial College London SW7 2BP UK Retrograde condensate reservoir behaviour is complex with much of the detailed mechanisms of the multiphase fluid transport and mass transfer between the phases within the porous matrix still speculative. Data measurements in the laboratory are difficult because the precise experimental requirements are unknown. What is certain is that gas production leads
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Investigation of Production Potential of Hosszúpályi-South Gasfield Supposing Different Driving Mechanism – Case Study
By Z. BihariD19 INVESTIGATION OF PRODUCTION POTENTIAL OF THE„HOSSZÚPÁLYI-SOUTH” GASFIELD SUPPOSING DIFFERENT DRIVING MECHANISMS. CASE STUDY 1 Abstract As a demand for natural gas in the world hence in Hungary also is increasing from year to year the development of more gasfields becomes a necessity. To achieve maximum recovery careful planning is needed as early as the pre-production phase. A full field simulation model (included reservoir – well – surface model) was built for Hosszúpályi-South gasfield to study uncertainties and to investigate the optimum development option for the twelve reservoirs which are to be developed. We demonstrate through the example of Hosszúpályi-South
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A Study of IOR by CO2 Injection in the Gullfaks Field, Offshore Norway
Authors H. Agustsson and G.H. GrinestafD21 A Study of IOR by CO2 Injection in the Gullfaks Field Offshore Norway H. Agustsson SPE STATOIL ASA G.H. Grinestaff SPE PETROTEL INC. Copyright 2004 Society of Petroleum Engineers Inc. This paper was prepared for presentation at the 2004 SPE/DOE Fourteenth Symposium on Improved Oil Recovery held in Tulsa Oklahoma U.S.A. 17–21 April 2004. This paper was selected for presentation by an SPE Program Committee following review of information contained in a proposal submitted by the author(s). Contents of the paper as presented have not been reviewed by the Society of Petroleum Engineers and are subject to correction by
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Numerical Simulation of Tertiary CO2 Injection of Ivanic Oil Field, Croatia
Authors D. Domitrovic, S. Šunjerga and J. Jelic-BaltaD22 Numerical Simulation of Tertiary CO2 Injection at Ivanić Oil Field Croatia D. Domitrović SPE S. Šunjerga and J. Jelić-Balta; INA-Naftaplin Copyright 2004 Society of Petroleum Engineers Inc. This paper was prepared for presentation at the 2004 SPE/DOE Fourteenth Symposium on Improved Oil Recovery held in Tulsa Oklahoma U.S.A. 17–21 April 2004. This paper was selected for presentation by an SPE Program Committee following review of information contained in a proposal submitted by the author(s). Contents of the paper as presented have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The
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Lessons from Trinidad's CO2 Immiscible Pilot Projects 1973-2003
Authors L.J. Mohammed-Singh and K. AshokD23 Lessons From Trinidad’s CO2 Immiscible Pilot Projects 1973-2003 Mohammed-Singh Lorna J. SPE Petrotrin and Singhal Ashok K. SPE Alberta Research Council Copyright 2004 Society of Petroleum Engineers Inc. This paper was prepared for presentation at the 2004 SPE/DOE Fourteenth Symposium on Improved Oil Recovery held in Tulsa Oklahoma U.S.A. 17–21 April 2004. This paper was selected for presentation by an SPE Program Committee following review of information contained in a proposal submitted by the author(s). Contents of the paper as presented have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s).
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EOR by In-Situ Combustion Process in Santhal Field of Cambay Basin – A Case Study (not yet confirmed)
More LessD24 Abstract: 1 SPE Paper Number: 89451 ENHANCED OIL RECOVERY BY IN- SITU COMBUSTION PROCESS IN SANTHAL FIELD OF CAMBAY BASIN MEHSANA GUJARAT INDIA – A CASE STUDY S. K. Chattopadhyay Binay Ram R.N.Bhattacharya and T.K.Das Oil and Natural Gas Corporation Limited Sub-Surface Mehsana Asset Mehsana Gujarat India E-mail: [email protected] In-Situ Combustion Process has been implemented in Santhal field in commercial scale for the last 6 years for enhancing the recovery of heavy oil. The process monitoring is the key factor for ensuring the effectiveness of the method. This paper describes the field practices of ignition well preparation sampling and
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