- Home
- Conferences
- Conference Proceedings
- Conferences
IOR 1995 - 8th European Symposium on Improved Oil Recovery
- Conference date: 15 May 1995 - 17 May 1995
- Location: Vienna, Austria
- ISBN: 978-94-6282-125-5
- Published: 15 May 1995
87 results
-
-
On the Importance of Correct Inclusion of Capillary Pressure in Reservoir Simulation
Authors T. Bu and L. B. HaoyCapillary pressure is frequently omitted from large scale reservoir simulation, rationalized by arguments that may not always be valid. A number of papers have shown that correct modelling of capillary pressure may be as important for the simulation result as properly accounting for relative permeabilities. Especially in strongly heterogeneous modale it is important to study the sensitivity to all petrophysical parameters before simplifications are introduced in the simulation model.
-
-
-
How Does the Level of Reservoir Description Impact the Choice of Development/EOR Process?
Authors E. Damsleth, L. Wilcox, G. Farrow and S. RodgersDifferences in recovery under several displacement mechanisms, for successive increases in reservoir detail, are outlined for the Brent-NI reservoir in the Visund field off Western Norway.
-
-
-
Three Dimensional Simulation of Multiphase Immiscible Displacements Using a Combined Grid and Particle Approach
Authors D. T. Homolka, J. S. Archer, J. M. R. Graham and T. S. DaltabanThe aim of this work is to model complex petroleum reservoirs in terms of relevant but arbitrarily shaped heterogeneities. This removes the constraint of describing heterogeneiries as constant property regions confined to cartesian grid blocks.
-
-
-
Geological Modelling of Stratified Upper Austrian Gas Reservoirs
More LessThe development of high capacity desktop computers (Workstations) has increased dramatically the possibilities of investigating stratified reservoir characteristics in greater detail than previously.
-
-
-
State-of-the-Art and Prospects of Carbonate Reservoir Developments in Russia
Authors A. V. Davydov, V. K. Gomzikov and A. Ya. KulapinCarbonate oil reservoirs begin to play an ever increasing role in the development of oil production in Russia, as new oilbearing regions and deeper lying formations become involved in geological prospecting works.
-
-
-
Relative Permeability and Capillary Pressure Concurrently Determined from Steady-State Flow Experiments
Authors G. A. Virnovsky and Y. GuoA new method is presented to interpret steady-state flow experiments for relative permeability and capillary pressure functions eliminating errors caused by the capillary end-effect. This is achieved by retaining the capillary term in the equations that are used to interpret the flow data.
-
-
-
Importance of Capillary Hysteresis on Coreflood Experiments
By Y. GuoCoreflood experiments for obtaining relative permeability curves are often subjected to capillary effect which is neglected in the laboratory data interpretation. Due to the well-known capillary end-effect the water saturation distribution prior to start of a flooding experiment is often non-uniform. In addition the saturation at different location of the core has experienced different saturation history, which might make hvsteresis effect significant in the final relative permeability curves.
-
-
-
Experimental Determination of Residual and Remaining Oil in Laminated Rock Samples
Authors Y. Huang, P. S. Ringrose and K. S. SorbieWe have performed a series of water-oil, drainage and imbibition floods on laminated slabs of aeolian rock, using CT imaging techniques to monitor the saturation evolution. Experiments with flow both parallel to and perpendicular to lamination have been conducted, and the role of viscous and capillary forces has been assessed by flooding at different rates.
-
-
-
Analysis of Interwell Tracer Flow Behaviour Through Heterogeneous Layered Reservoirs
Authors T. Yi, T. S. Daltaban and J. S. ArcherTracer tests can be used to investigate reservoir heterogeneity which we define as reservoir characteristics which effect the sweep efficiency and fluid flow behaviour on a scale of practical interest, and which can be very important information especially for the design of IOR applications. It is helpful to understand the mechanism of tracer transport in various heterogeneous reservoirs before any interpretation of tracer test result is used to deduce reservoir heterogeneity.
-
-
-
Geostatistics - A Tool to Map Thin Reservoirs
Authors R. Derksen and W. NachtmannThe Munderfing gasfield in the Upper Austrian molasse basin consists of Lower Miocene turbidite sands reworked in a deep ocean bottom channel system. Net thicknesses of sands vary from 0 to 8 m in as many as 10 individual layers over an interval of 150m. Historically, the minimal thickness of these bodies and complex stratigraphy have prevented mapping of the packages. Recent experience with a multidisciplinary approach involving geostatistics and seismic attribute analysis (along with geologic and engineering data) offers the potential of changing this situation. This paper will discuss the data preparation, the geostatistical analysis and the final map evaluation procedures that RAG is currently using in this environment.
-
-
-
Geostatistical Characterisation of a Carbonate Reservoir Located in South East Turkey
More LessSpurred by the enormous expense of developing heterogeneous fields and by the desire of oil companies to increase ultimate recovery, the science of reservoir characterization is making rapid progress. Reservoir characterization encompasses all techniques and methods that improve understanding the geological and petrophysical controls of fluid flow. The objective is to provide practical reservoir models for optimum field development.
-
-
-
Draugen Field Development: The Role of Gravity Drainage and Horizontal Wells
More LessThe Draugen field consists of an elongated low relief anticline containing mainly multi-Darcy sands. Oil initially in place was 182 million Sm³.
-
-
-
Optimizing Oil Production from the Troll Field
Authors O. Boee, S. E. Wennemo and G. NerbyThe giant Troll gas field offshore Norway also contains one of the largest oil accumulations in the North Sea. The oil is located in thin layers sandwiched between the gas cap and an active aquifer. Its development is based on long, horizontal wells tied back to a concrete semi-submersible production platform. The oil will be developed stagewise with first oil planned in late 1995.
-
-
-
Snorre WAG Pilot - A Case Study
Authors H. Stenmark and P. O. AndfossenA WAG injection pilot was initiated in February 1994 in the Snorre Field. This resulted in an immediate increase in oil production, as gas export restrictions no langer limited oil rates. In 1994, the total acceleration of oil production due gas injection was estimated at 1.5 x 10 6 Sm³.
-
-
-
Calculation of Three-Phase Flow Behaviour and its Influence on Reservoir Performance
Authors R. E. Guzman and F. J. FayersIn this paper we study the effects of variations in relative permeabilities for threephase flow on predicted oil and gas production behavior when immiscible gas displacement is used to enhance oil recovery from waterflooding.
-
-
-
Control of Water and Gas Coning by Dynamic Pressure Barrier: Application to a Carbonate Reservoir
Authors G. de Ghetto and Ch. KossackThe ability of a fluid continuously injected at near the water-oil contact or gas-oil contact (white producing oil) to reduce the coming was investigated by numerical reservoir simulation. The injection creates a dynamic barrier to the flow of water or gas info the well.
-
-
-
Application of Horizontal-Branched Wells in Complicated Geological Conditions
Authors V. I. Kudinov, V. S. Kolbikov, M. O. Datsik, A. M. Grigoryan and V. V. VolkovaThe carnet level of novel technologies for oil fields development is sufficiently high. The common world practice includes oil reservoir water flooding, chemical and thermal EOR, miscible/immisible oil displacement - injection of hydrocarbon gases, carbon dioxide etc. In the practical development of heavy oil fields, thermal drive plays an especial role. However, this is a common knowledge, that even the application of high efficient EOR/IOR technologies for oil fields development using vertical wells does not enable to achieve the final oil recovery for more than 40-50% of the estimated reserves.
-
-
-
Foam Pilot Evaluations for the Snorre Field, Part 1: Project and Laboratory Results
Authors I. Svorstoel, T. Blaker, S. Arneson, T. Holt, F. Vassenden and L. M. SurguchevThe Snorre Field, operated by Saga Petroleum a.s., has been developed based on water flooding as the primary recovery mechanism. The field was put on stream in August 1992. In February 1994 a WAG pilot project involving two injection wells and three production wells was started in the Staffjord Formation of the Snorre Field. Extensive evaluations of the project plans and predictions showed that early gas breakthrough may be a potential problem. As a result of this, the use of foam for gas mobility control, fluid diversion, and blocking to reduce GOR in production wells has been included in the project plans as a means of improving the WAG process. A foam pilot test in a producer is scheduled for 1995. This test will be a first step for scaling laboratory data to field conditions, i.e. to investigate the selected surfactant's ability to generate and sustain a stable faam in-site.
-
-
-
Foam Pilot Evaluations for the Snorre Field, Part 2: Numerical Simulations and Economical Evaluations
Authors I. Svorstoel, T. Blaker, S. Arneson, T. Holt, F. Vassenden and L. M. SurguchevThis paper is the second in a series of papers dealing with various aspects of the hydrocarbon gas-foam pilot project planned for the Snorre Field. The first paper summarized the project plans and detailed the laboratory work leading to the selection of a surfactant for the field test.
-
-
-
Evaluation of IOR Techniques at the Ula Field
Authors St. R. Jakobsen, T. M. Hegre, J. Peak and T. JohansenThe Ula reservoir consists of ons main reservoir unit which presently is very well swept by injected water, and ons upper reservoir unit from which there is significantly lower oil recovery due to its lower permeability.
-
-
-
Scaling of Three Phase Compositional Simulation - A Numerical Investigation
Authors D. Wessel-Berg and O. St. HustadA general method for scaling three dimensional three-phase compositional flow based on a fine scale simulation is presented.
-
-
-
Pore Level Modelling of Three Phase Flow in Porous Media
Authors D. H. Fenwick and M. J. BluntWe analyze the pore level displacement of three phases - water, oil and gas. The presence of a third phase dramatically alters the flow, because of the formation of a layer of oil between water and gas in the pore space.
-
-
-
EOR Application in Large Oil/Gas Fields of West Siberia: Generalisation of the Experience, New Technologies
More than 30% of oil and gas-condens ate reserves in Russia are contained in the oil fields having gas caps. Annual recovery race of such reserves is less than 6%. Race of oil production and oil recovery factor are also very low. The discovery of giant oil fields in the West Siberia, such as the Samotlor oil field, the Lyantor oil field and the Fyodorovskoe oil field as well as many other fields, has demanded application of new technologies for the development of wast under-gas zones.
-
-
-
Matching the Future for the Evaluation of Extreme Reservoir Development Scenarios
Authors D. Guerillot and F. RoggeroThe reservoir engineer needs not only to match the past but also has to forecast production by considering various geological models and reservoir development scenarios.
-
-
-
Scale-Up of Near Miscible Gas Injection Processes: Integration of Laboratory Measurements and Compositional Simulation
Authors K. K. Pande, J. M. Sheffield, A. S. Emanuel, R. L. Ulrich and E. F. De ZabalaResults from laboratory PVT measurements, special core analysis studies, and reservoir condition coreflood studies were used to develop and test the accuracy of a compositional simulation model in predicting near- mullticontact miscible gas flood performance at the laboratory scale.
-
-
-
The Role of Capillary Pressure in Compositional Simulation of Heterogeneous Reservoirs
Authors J. W. Barker and G. SindicCompositional simulations (neglecting gravity) of a simple reservoir element consisting of regions of high and low permeability reveal imbibition of oil into the low permeability region during depletion, and extraction of the oil from this region during lean gas injection by `capillary pumping', a mechanism driven by variations in interfacial tension. Initial fluid composition is found to have a significant effect. The range of dimensionless capillary numbers for which capillary pressure may be neglected is determined, but evaluation of these numbers is not easy.
-
-
-
Enhanced Oil Recovery of the Anisotropic Reservoir
Authors S. Zakirov and V. PiscarevUsually, productive formations of oil and gas fields are anisotropic on their reservoir properties. Most scientists paid attention to determination and taking into consideration the anisotropy of permeability in vertical direction.
-
-
-
A Generalized Streamline Method to Predict Reservoir Flow
Authors M. J. Blunt, K. Liu and M. R. ThieleWe present a generalized streamline method that is able to model flow in porous media-including gravity, compositional effects and dispersion in three dimensions. First we describe the theory and discuss the approximations of the method. Then we compare the predictions using the streamline technique against high resolution numerical simulation.
-
-
-
WAG Injection at Reservoir Conditions in a Layered Long-Core Loaded with a Live North Sea Crude
Authors I. Akervoll, P. A. Slotte and A. G. HansenWater-alternating-gas (WAG) and Combined water/gas (CWG) injection schemes have gained increasing interest in the recent years as a strategy to improve and accelerate oil recovery from North Sea Fields.
-
-
-
A Consistent Correlation for Three Phase Relative Permeabilities and Phase Pressures Based on Three Sets of Two Phase Data
Authors O. St. Hustad and A. G. HansenA correlation for three-phase relative permeabilities and phase pressures for reservoir simulators is presented.
-
-
-
Gas Mobility during Three Phase Flow in a WAG Process
Authors P. K. Munkerud and O. HoimyrThe main objectives of the work presented in this paper was to determine the influence of saturation history, fluid/rock interaction (wettability), fluid interfacial tensions and capillary pressure on gas mobility during three phase flow in combined gas/water injection processen (CGW, WAG or tertiary gas injection).
-
-
-
Evaluation of Associated Gas Injection in the Miller Field
By T. P. MouldsThe Miller Field, located in the UKCS, contains a light oil with 18% C02 and a high GOR of 1830 scf/stb. The associated gas is currently exportel with 22% C02 content.
-
-
-
Simulation of WAG and Gas Injection with Potential Sweep Improvement by Application of Foam
Authors L. M. Surguchev, J. E. Hanssen, D. A. Coombe and I. SvorstoelStratified oil reservoirs with high permeability contrast and moderate structural dip are considered today as potential candidates for WAG and/or for dowdip gas injection. The combination of waterflooding and gas injection processes in WAG as well as updip gas injection are well known processes, quite intensively studied for North Sea application. This simulation study aims to compare different gas-assisted processes and has a focus on the importance of anisotropy and vertical inter-layer communication in stratified reservoirs for these methods.
-
-
-
Oil Recovery by Gravity Drainage during Gas Injection
Authors H. Skurdal, O. St. Hustad and T. HoltThis paper presents the results from six gravity stable gas injection experiments in 1.2 m long water flooded sandstone cores. All experiments were performed close to ambient conditions with different combinations of spreading and wetting characteristics for time periods of 50 to 170 days. The effectiveness of oil recovery by gravity drainage for the different flow conditions are shown. A mixed wet membrane was placed on the outlet of each core to eliminate end effects. Experimental techniques for eliminadon of capillary end effects are discussed. Saturation profiles in the cores were determined at the end of each experiment.
-
-
-
Impact of Large Scale Permeability Heterogeneity in the Optimisation of a WAG Process in Tertiary Conditions
Authors J. P. Duquerroix and F. KalaydjianAmong the Improved Oil Recovery (IOR) processes, Water Alternating Gas (WAG) injection process seems to have a wide potential in the North Sea. The Tule of thumb is still in use and both industry and research need to design procedures to ensure broader application of WAG technology.
-
-
-
Simulations of CGW Injection in Parts of a Fluvial Deposited Reservoir
Authors P. A. Slotte, A. Solheim and J. I. JensenPoor sweep efficiency and early break through is a main concern with respect to improved oil recovery by gas injection processes. These adverse effects may be eliminated by combined gas and water (CGW) injection. The efficiency of a CGW injection proces is strongly related to the size of the mixed gas/water flow zone in the reservoir.
-
-
-
The Design of a (Near) Miscible Gas Displacement Process for a Transition Zone Reservoir
Authors A. A. Espie, Ch. E. Brown and R. C. SkinnerNorth Sea reservoirs tend to be characterised by a relatively low relief with a substantial part of the reservoir consisting of a water / oil transition zone.
-
-
-
Gravity Drainage during Gas Injection
Authors P. Naylor, N. C. Sargent, A. J. Crosbie, A. P. Tilsed and S. G. GoodyearThe drainage of oil under gravitational forces has been an important mechanism in the production of many oil fields. In order to extend the economic implementation of gas injection into more marginal fields, a reduction in the uncertainties associated with gravity drainage is required. This paper describes a series of three tertiary, nitrogen experiments which investigated the effect of permeability on gravity drainage. The experiments were conducted at low pressure using long, vertical, water-wet sandstone sores and decane in the presence of connate brine.
-
-
-
CO2 IOR in the Szank Field Using CO2 from Sweetening Plant
Authors I. Remenyi, A. Szittar and G. UdvardiField scale CO2 EOR operations started in 1972 in Hungary. Partially miscible EOR recovery was completed in the sandstone reservoirs of Budafa and Lovászi fields and recovery by artificial CO2 gas cap has been accomplished in the carstic/cavemous limestone reservoir of the Nagylengyel field.
-
-
-
An Upscaling Technique for Production Forecasting of Gas Recycling in a Near - Miscible Oil Reservoir
Authors M. M. Hanssen and K. HoveThis paper describes a method used for scaling black oil production profiles in order to account for compositional effects taking place during a gas recycling scheme in a neer miscible reserv oir The procedure has successfully been used for the Njord Field offshore mid-Norway.
-
-
-
Transient Foam Flow in Porous Media: Experiments and Simulation
Authors O. Fergui, M. Quintard, H. Bertin and D. DefivesGas injection in the form of foam is an excellent way to enhance gas mobility control and overcome problems caused by density differences encountered duririg IOR operations.
-
-
-
A Foam Pilot Test Aimed at Reducing Gas Inflow in a Production Well at the Oseberg Field
Authors M. G. Aarra, A. Skauge, S. Soegnesand and M. StenhaugIn June 1994 a foam pilot test was performed in a production well at the Oseberg field, North Sea. The Oseberg field is developed by updip gas injection and are currently experiencing gas breaktbrough in some of the production wells.
-
-
-
Modelling and History Matching of Foam Field Pilot, Oseberg Field
Authors L. M. Surguchev, S. Soegnesand, A. Skauge and M. G. AarraGas coning and breakthrough problems in production wells are common for reservoirs under gas injection. like Oseberg. One approach to reduce gas inflow is placement of a foam region around the production well. A pilot test was initiated to evaluate if foam has a potential for reducing gas inflow to the production wells.
-
-
-
Preliminary Study of a New Dynamic Technique to Prevent Water Coning
Authors G. Renard, Cl. Palmgren, C. Gadelle, L. Lesage, A. Zaitoun, Ph. Corlay and G. ChauveteauIn many oil (and gas) reservoirs throughout the world, oil recovery is strongly affected by the presence of a bottom aquifer. The drawdown imposed in production wells induces the water to rise forming a cone.
-
-
-
Practical Experience with Water Control in Gas Wells by Polymer Treatments
Authors G. Pusch, N. Kohler and H. J. KretzschmarThe paper deals with the appraisal and application of water control technologies for gas wells and gas storage wells.
-
-
-
Polymer Flooding: Still a Viable IOR Technique
Authors F. E. de Bons and R. W. BraunThis paper reviews twelve international po!ymer floods. both pilots and fieldwide projects, conducted between 1975 and 1992. The field conditions, designs, and performances of these projects are analyzed and compared with polymer floods conducted in the United States.
-
-
-
Laboratory Evaluation of a New Selective Water Control Treatment and its Implementation in a North Sea Well
Authors M. Zettlitzer, W. Schuhbauer and N. KohlerIn a French-German cooperation, a new weak gel consisting of a nonionic high-moIecular- weight polysaccharide and an organometallic activator was developed for harsh reservoir conditions. Gel formation is delayed in surface conditions, but a gel progressively forms at reservoir temperature and selectively reduces water production, with Iimited effect on oil flow.
-
-
-
An Evaluation of Stable Gel Systems for Deep Injector Treatments and High Temperature Producer Treatments
Authors B. A. Kvankik, J. Kolnes, T. Tyvold, S. Nilsson, B. Matre, B. Skjellerudsveen and K. OlafsenThis paper presents a summary of the activity on gel in the Norwegian RUTH (Reservoir Utilisation through advanced Technological HeIp) research program. RUTH is a four year research program, started in 1992.
-
-
-
Performance of a Single Well Surfactant Tracer Test in the Gullfaks Field, Norway
Authors A. Nordbotten, T. Maldal, E. Grilje, St. Svinddal and R. KristensenThe surfactant test initiated in a GulIfaks Well in January 1991¹, was interrupted before surfactant injection due to operational problems in the well. Based on this experience, a new well was identified, and a single well surfactant injection test was planned and conducted during the first half year of 1992. The results, and a discussion of both the results and the experiences, are presented for the two well operatons.
-
-
-
Foam Field Tests: State of the Art and Critical Review
Authors L. M. Castanier and J. E. HanssenThis paper gives a current overview of field experience with the use of foam for improved recovery and a critical evaluation of selected pilot projects. The focus is on identifying and describing critical problems encountered in foam tests and suggesting improvements.
-
-
-
Simplified Mechanistic Modelling of Foam Processes for Improved Oil Recovery
Authors S. C. Zeilinger, J. X. Shi, M. T. Lim and W. R. RossenThis paper describes simplified mechanistic foam modeling using fractional-flow methods and a simulator that incorporates the fixed-limiting-capillary-pressure model for foams.
-
-
-
Role of Diffusion and Shut-Off Time in Well Treatment Technology
Authors I. Lakatos and J. Lakatos-SzaboAn analysis of ion diffusian in polymer/silicate gels is detailed. The diffusion coefficient, break-through time and retention of chromium ions was determined as a function of gel composition and geometry and temperature. The activation energy of diffusion was also calculated.
-
-
-
Polymer Flooding: Appraisal of Four Different Field Projects in Germany
Authors W. Kleinitz and W. LittmannPreussag accomplished four polymer flood projects during the Iast 10 years in their oil fields in Germany. In three projects (Eddesse-Nord, Vorhop-Knesebeck and Scheerhorn) xanthan broths were used from different producers. The project in the Adorf field was carried out with polyaczylamide.
-
-
-
Field Application and Simulation of Foam for Gas Diversion
Authors S. Mohammadi, J. Collins and D. A. CoombeField application of foam for gas diversion was conducted in a gas condensate reservoir. The application included two years of foam injection in a single pattem, monitonng of condensate recovery in pattern producers and simulation of the process.
-
-
-
Foam Barriers against Gas Coning: Physical-Model and Mechanistic Simulation Study
Authors A. R. Kovscek, T. W. Patzek, C. J. Radke, J. E. Hanssen, L. M. Surguchev and S. EkrannGas coning contributes to unfavorably high gas/oil ratio (GOR) in reservoirs with a gas cap. We investigate a novel treatment technology, currently under consideration for a field trial for prevention of gas coning with an integrated experimental and simulation study.
-
-
-
Isolation of Gas with the Self-Sealing Compositions
Authors A. Kh. Mirzadzhanzade, I. M. Ametov, S. P. Shandin and N. O. CherskayaOperation of the oil producing wells at the oïl fields, possessing a highly fractured reservoirs and a high gas-oil ratios is extremely complicated due to complexities in performing of workovers, as well as due to unreliability of the existing technologies.
-
-
-
Emulsified Solvent Flooding: A Non-Thermal IOR Alternative for Thin, Heavy Oil Reservoirs?
Authors H. K. Sarma and B. B. MainiThis experimental study evaluates the heavy oil recovery potential of a novel non-thermal IOR process which uses emulsified solvents to displace the oil. The process, if successful, would have wide application in thin heavy oil reservoirs (such as those in Alberta and Saskatchewan) which are urtsuitable for thermal methods due to excessive heat Iosses to underlying and overlying formations.
-
-
-
Assessment of Foam for Deep Flow Diversion
Authors S. G. Goodyear and P. I. R. JonesFoam injection has a number of possible applications as an IOR technique. Laboratory studies of foam flow in porous media suggest that relative foam mobility is approximately inversely proportional to permeability. This means that foam has potential as a flow diversion agent, in principle sweeping low permeability regions as affectively as high permeability regions.
-
-
-
The Alkaline-Surfactant-Polymer Combination Flooding and Application to Oilfield for EOR
Authors C. Yang, H. Dakuang, Y. Hong, L. Zhuhong, J. Wenle, T. Shanyu, S. Wanchao, S. Juanhua and L. RenjunSummary not available
-
-
-
Low-Cost Foam Surfactant from Wood Pulping By-Products
Authors W. T. Osterloh and M. J. JanteWe report the results of laboratory experiments designed to evaluate the performance of the sodium salt of tall oil acid, TOA, as a foam surfactant. The objective of the experiments was to determine if this inexpensive by-product could be used to reduce the chemical costs of the foam mobility control process.
-
-
-
The Technical Performance and Interpretation of Results from a Large Scale Na-Silicate Gel Treatment of a Production Well on the Gullfaks Field
Authors T. A. T. Lund, H. I. Berge, S. Espedal, R. Kristensen, T. A. Rolfsvag and G. StroemsvikThe development program for processes to reduce watercut during production of the lower Brent reservoir unit of the Gullfaks field culminated by a large scale injection of alkaline Na-silicate gel in a lower Brent production well during summer 1993. The operation was prepared and designed through an extensive laboratoiy program as well as small scale onshore field tests.
-
-
-
*The Effect of Velocity and Interfacial Tension on the Relative Permeability of Gas Condensate Fluids in the Wellbore Region
Authors G. D. Henderson, A. Danesh, D. Tehrani and J. M. PedenHigh pressure core flood experiments using gas condensate fluids in long sandstone cores have been conducted to determine the effect of flow rate and interfacial tension (IFT) on relative permeability. The experimental data are intended to be applied to near wellbore flow in gas condensate reservoirs, as viscous forces increase over capillary during the course of the tests.
-
-
-
*Depletion of Gas-Condensate Low Permeability Reservoirs (Höflein Field, Vienna Basin)
Authors K. T. Potsch, W. Liebl and P. BedrikovetskyThis paper combines theoretical, experimental and field data of a low permeable gas condensate reservoir Static laboratory experiments - constant composition expansion (CCE) and constant volume depletion (CVD) - are compared with dynamic depletion experiments from artificial sandpacks. Additionally, calculations from a PVT package and field data from the production history are also included.
-
-
-
*The Effects of Interfacial Tension and Spreading on Relative Permeability in Gas Condensate Systems
Authors P. K. Munkerud and O. TorsaeterIn this paper the results of a series of flow experiments performed on a gas condensale system will be presented.
-
-
-
**Application of Control Theory to Optimize Horizontal Well Location Producing from a Thin Oil Zone
Authors G. A. Virnovsky and H. KleppeProduction from reservoirs consisting of an oil layer sandwiched between a gas cap and bottom water has always been a challenging task for petroleum engineers because of the coning problems.
-
-
-
**Development of the Slumped Crestal Area of the Brent Reservoir, Brent Field/An Integrated Approach
Authors S. D. Coutts, S. Y. Larsson and R. RosmanThis paper describes the various studies undertaken to formulate a development plan for the ±13 million m³ (80 MMstb) of oil reserves in the slumps of the Brent Reservoir and presents initial well results.
-
-
-
Screening Criteria for the Application of Steam Injection and Horizontal Wells
Authors C. Palmgren and G. RenardTechnical and economic problems of efficient development of heavy oil resources receive large attention in all countries where these resources are abundant. This is particularly the case in Canada and Venezuela where some 70 per cent of the world reserves of heavy oil are located.
-
-
-
High Pressure Combustion Tube Performance of Light Oils
Authors D. L. Tiffin and D. V. YannimarasThe research documented here is a systematic study of the effects of pressure on the air injection process for light oils in an adiabatic combustion tube. Tests were conducted at pressures up to 37.2 MPa. The purpose of this research is to study prospects of enhancing oil rates and recoveries by air injection, with particular appllication to large high pressure reservoirs in remote locations where conventional injectants are not available.
-
-
-
Qarn Alam: Application of Simulation for Steam Pilot Design in a Fractured Reservoir
Authors M. Hartemink, B. M. Escovedo, J. E. Hoppe and R. MacaulayLate in 1995 a steam-injection pilot project will be initiated in the Qarn Alam field in Oman. The objective is to test the steam-enhanced gas-oil gravity drainage of the heavy oil remaining in the matrix of the fractured carbonate Shuaiba reservoir.
-
-
-
New Cyclic Technology for Thermal Treatment of Complicated Formations
Authors V. T. Kudinov, V. S. Kolbikov, M. I. Datsik, N. M. Zubov and V. V. VolkovaThe idea of artificial change of formation temperature to increase oil production has a long history. since the beginning of the 20th century. Different methods and technologies to heat heavy oil has being created and implemented in deferent scales. This methods compose of three main trends: - producing wells bottom-hole thermal treatment; - formation treatment by beat carriers injection and; - in-situ combustion process.
-
-
-
Possibilities for Enhancing Oil Recovery by Hot Water Injection
Authors V. V. Popp, G. Ciuca and V. C. BuiacThe paper presents briefly the research and design works for achieving a hot water injection experimental plant.
-
-
-
Recovery of Residual Light Oil from Waterflooded Reservoirs Using Horizontal Wells - Insitu Combustion Process
Authors M. Greaves and M. Ben RahilPreliminary 3D tests have been performed to physicaily simulate light oil in situ combustion (ISC) under waterflooded conditions
-
-
-
An Investigation of Noncondesible Gas-Steam Injection for Heavy Oil Recovery
More LessPerformance of steamflooding process can be improved by the use of noncoridensable gases such as CO2 or rnethane. Improving steam injectivity, increasing the size of the heated areas and providing additional drive energy are several beneficial effects of the combined use of steam and gases.
-
-
-
A Percolation Based Upscaling Technique for Viscous Force Dominated Waterflooding in Uncorrelated Heterogeneous Reservoirs
Authors P. Bedrikovetsky and J. BruiningWe present a percolation model of relative permeability for the case where viscous forces are dominant.
-
-
-
40 Years Experience of Romashkino Oil Field Development in Tatarstan: Improvements of Water Flooding
Authors R. G. Galeev, R. Kh. Muslimov, R. N. Diyashev and A. F. BlinovThe system of contour water-flooding was for the first time introduced in Romashkino oil field, occupying the territory of about 4300 sq.km. The field was divided into 21 independent areas of development by rows of injection wells. This allowed to bring into development the largest fleid by accelerated rates with reasonable economic costs. The following improvement of water-flooding system allowed to achieve oil recovery factor of 47.7% by the beginning of 1994. Currently developed technological solutions for improvement of water flooding will allow to achieve oil recovery factor of about 53%.
-
-
-
Predicting Water Cut - A Geological Profile
Authors A. W. Mitchell and D. W. SherrardThe Wytch Farm Oilfield produces ≈95rnstb/d oil from a Triassic fluvial sandstone reservoir. Water cut has increased over recent years at a rate of 1500b/d/month.
-
-
-
Water and Surfactant Flooding in Low Permeable Chalk Studied by X-Ray CT Scanning
Authors E. H. Stenby, T. O. Hansen, F. Engstroem and M. T. BieberDisplacement processes of oil by water in low-permeable reservoir chalk from the Danish part of the North Sea have been studied by use of x-ray CT-scanning.
-
-
-
The Impact of Injection Water Temperature on Recovery from Viscous Oil Reservoirs
Authors Cl. Woods, S. G. Goodyear, P. I. R. Jones, C. J. Reynolds and P. H. TownsleyA number of North Sea reservoirs contain viscous oils in high permeability sandstones. One possible IOR technique is the injection of hot water. Even if specific hot water injection facilities are not provided on the platform, hot water (in contrast to cold sea water) may be available as a by-product of the separators or because the injected water is sourced from an aquifer.
-
-
-
Water Flooding Combined With Infill Drilling at the Helvetian Strambu Field
Authors V. Machedon and D. MarcuThe Strâmbu reservoir is located in ten strata caps of the Helvetian period, transgressively and unconformably overlying the Oligocene, with dips ranging from 400° on the West to 10° on the east.
-
-
-
New Gas EOR Technology Based on the Use of Oil-Soluble Surfactants and Polymers
The results of the experimental study of the processes of gas and gas-water treatment on the oil stratum wiih the use of the oil-soluble surfactants and polymers en the reservoir models are presented.
-
-
-
New System Approach to Improve Oil Recovery
Authors A. Kh. Shakverdiev, A. Y. Bruslov, F. Kh. Galeev and O. A. ChukcheevThe highlight of system optimization is to make optimal decision based oil system analysis, diagnosis and prediction of oil-bearing object development /1-7/.
-
-
-
-
The Role of Acoustic Emission at Vibroseismic Stimulation of Waterflooded Oil Reservoirs
Authors G. P. Lopukhov and V. N. NikolaevskiiLaboratory studies of two-pfase fluid flow have shown that mobility of residual oil drops is growing under action of oscillations.
-