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ECMOR IX - 9th European Conference on the Mathematics of Oil Recovery
- Conference date: 30 Aug 2004 - 02 Sep 2004
- Location: Cannes, France
- Published: 30 August 2004
87 results
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Neptune Project – Modelling and Simulation of Carbonate Environments
Authors B. Leflon and G. MassonnatA001 NEPTUNE PROJECT – MODELLING AND SIMULATION OF CARBONATE ENVIRONMENTS Abstract 1 Neptune is a software developed to provide realistic and consistent stratigraphic grid and facies proportions from well data and geology knowledge. It is based on the relationship between the facies and the bathymetry of deposit. Such a relation is generally known approximately by sedimentologists and is case study dependant. It is defined as bathymetry distribution of probability for each facies. A method has been developed to compute automatically and for each well path a curve of bathymetry deduced from observed facies log and given distributions of bathymetry. Extrapolation
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Structural Uncertainty Modelling and the Representation of Faults as Staircases
Authors H.H. Soleng, J.C. Rivenæs, J. Gjerde, K. Hollund and L. Holden1 A002 STRUCTURAL UNCERTAINTY MODELLING AND THE Abstract REPRESENTATION OF FAULTS AS STAIRCASES HARALD H. SOLENG ∗ JAN C. RIVENÆS ‡ JON GJERDE ∗ KNUT HOLLUND ∗ and LARS HOLDEN ∗ ∗ Norwegian Computing Center P.O. Box 114 Blindern NO-0314 Oslo Norway ‡ Norsk Hydro P.O. Box 7100 NO-5020 Bergen Norway Quite often structural uncertainty is the dominating uncertainty of the oil production of a field. The structural geology of an oil field is a large-scale property with non-linear effects on flow. Hence its effect on production can’t be quantified simply by varying a few parametres and as a consequence
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A 4D Stratigraphic Model Fitting Seismic Data for Sedimentary Basin Modelling
Authors G. Dobranszky, R. Masson, E. Albouy and M.C. CacasA003 A 4D STRATIGRAPHIC MODEL FITTING SEISMIC DATA FOR SEDIMENTARY BASIN MODELLING Introduction 1 G. DOBRANSZKY* R. MASSON E. ALBOUY & M.C. CACAS Institut Français du Pétrole 1 et 4 avenue du Bois Préau 92500 Rueil-Malmaison Abstract. Diffusive multi-lithology stratigraphic models are used in oil exploration in order to determine the geometry of sedimentary units and to characterise their sedimentary facies (depositional water depth sand/shale ratio…). One of the main difficulties in the use of such models is that their entry parameters (mainly accommodation input sediments diffusion coefficients) have to be inverted to fit the seismic and well log data.
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3D-Parameterization of the 3D Geological Space – The GeoChron Model
Authors R. Moyen, J.-L. Mallet, T. Frank, B. Leflon and J.-J. RoyerA004 3D-PARAMETERIZATION OF THE 3D GEOLOGICAL SPACE – THE GEOCHRON MODEL Abstract 1 One of the key points in reservoir modeling is the building of a complex 3D-mesh which must integrate various constraints: respecting the geometry of the fault network taking into account stratigraphic knowledge computing petrophysical properties by geostatistical methods allowing upscaling and/or flow simulation… The building of this mesh relies on the use of a parametric coordinate system (u v t) such that (u v) corresponds to “horizontal” curvilinear coordinates tangent to the horizons while (t) corresponds to the “vertical” curvilinear axis approximately orthogonal to the horizons. So
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Local Geostatistics
By C.L. FarmerA005 LOCAL GEOSTATISTICS 1. Introduction 1 Standard approaches to scattered data interpolation use the theory of Gaussian random functions. First the correlation function (or equivalently the variogram) is defined either by direct assumption based on analogues and conceptual models or sometimes by inference from the data to be interpolated. Then a maximum probability argument leads to the various forms of Kriging. This is justified when the data is plentiful and such that the Voronoi diagram of the data points has cells that are less than the correlation length in diameter. When data is scant realisations conditioned on the scattered data
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Dynamic Conditioning of Geo-Models Using Gradient-Based Optimization
More Less� A006 DYNAMIC CONDITIONING OF GEO-MODELS USING GRADIENT-BASED OPTIMIZATION �������� ���� ���� �������� � ������ ��� ������������ ������ ����� �� � ���������� ��������� �� ������� �������� ����� ���� ���� ����� ��� ���������� � �������������� ������������ ������ �� ���� �� �������� �� ��������� �������� ����� �������� �������� ���� ���� ������� ���� � ��������� ���������� ��� ��������� �������� ���� �� � ������������� �������� �� ����� ���� � ��� ����������� ��������� ��� � ���������� ���������� ��� ��������� �������������� ������� �� ��� ������ �������� ����� ��������� ����������� ��� �� ��������� ������������ ��� ��� �� �������� �� ���������� ����� ��� ��� �� ��� �������� �������������
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Rebuilding and Recalibrating an Existing Reservoir Model
Authors M. Le Ravalec-Dupin, L.Y. Hu, O. Merghirbi and F. RoggeroA007 REBUILDING AND RECALIBRATING AN EXISTING RESERVOIR MODEL Abstract 1 The increasing computer power and the recent developments in history-matching can motivate the re-examination of previously built reservoir models. To save engineer and CPU times we develop four distinct algorithms which allow for rebuilding an existing reservoir model without restarting the reservoir study from scratch. These algorithms involve techniques such as optimization relaxation Wiener filtering or sequential reconstruction. Basically they are used to identify a random function and a set of random numbers. Given the random function the random numbers yield a realization which is pretty close to the existing
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The Probability Perturbation Method – An Alternative to a Traditional Bayesian Approach for Solving Inverse Problems
By J. CaersA008 THE PROBABILITY PERTURBATION METHOD – AN ALTERNATIVE TO A TRADITIONAL BAYESIAN APPROACH FOR SOLVING INVERSE PROBLEMS Abstract 1 Jef CAERS Stanford University Petroleum Engineering Stanford CA 94305-2220 USA Bayesian inverse theory provides a framework for solving inverse problems that are non-unique e.g. history matching. The Bayesian approach relies on the fact that the conditional probability of the model parameters given the data (the posterior) is proportional to the likelihood of observing the data and a prior belief expressed as a prior distribution of the model parameters. In case the prior is not Gaussian and the relation between data and
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History Matching with the Probability Perturbation Method – Applications to a North Sea Reservoir
Authors B.T. Hoffman and J. CaersA009 HISTORY MATCHING WITH THE PROBABILITY PERTURBATION METHOD – APPLICATION TO A NORTH SEA RESERVOIR Abstract 1 This paper presents a general history matching technique to create simulation models that honor prior geological information and match production data. The methodology relies on a region-wise perturbation of the probability distributions used to generate the reservoir models. Perturbing probabilities rather than actual petrophysical properties guarantees that the conceptual geologic model is maintained and that border artifacts are avoided. By allowing the properties in different region to be perturbed by different amounts an efficient match of the observed data can be found. A
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Multiscale Reservoir Characterization Using Production and Time Lapse Seismic Data
Authors M. Mezghani, A. Fornel, V. Langlais and N. LucetA010 MULTISCALE RESERVOIR CHARACTERIZATION USING PRODUCTION AND TIME LAPSE SEISMIC DATA 1 Abstract In reservoir characterization the value of each piece of data does not lie in its isolated use but rather in the value it adds to the analysis when integrated with other data. Earth scientists from different disciplines have made many efforts to better predict the spatial distribution of petrophysical properties. However the interpretation of isolated piece of knowledge without a real integration of disciplines cannot lead to a quantitative answer in terms of reservoir characterization. In this paper we present a joint inversion scheme for estimating petrophysical
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History Matching of a Stochastic Fault Network for Production Forecasts
Authors S. Jenni, L.Y. Hu and G. de MarsilyA011 HISTORY MATCHING OF A STOCHASTIC FAULT NETWORK FOR PRODUCTION FORECASTS Abstract 1 This paper presents a case study that illustrates the applicability of an inverse procedure for history matching of object-based stochastic models of faulted and fractured reservoirs based on the “gradual deformation” algorithm. The procedure preserves the geological constraints derived from seismic attributes fault-related strain field structural information (curvature) etc. The results of this study also show the usefulness of such history matched fractured reservoir models for production forecasts. 1. Introduction S. JENNI 1 L.Y. HU 1 AND G. DE MARSILY 2 1 Institut Français du Pétrole 1
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A Real Parameter Genetic Algorithm for Cluster Identification in History Matching
Authors J.N. Carter and P.J. BallesterA012 A REAL PARAMETER GENETIC ALGORITHM FOR CLUSTER IDENTIFICATION IN HISTORY MATCHING Abstract Non-linear inverse problems by their very nature can be expected to yield multiple solutions. This will occur even when the problem is well defined in the sense that the number of measurements is significantly greater than the number of free parameters. These solutions will manifest themselves as local optima for some objective function and will be separated by regions of poor objective function value. In history matching the challenge is to identify all of the high quality local optima and sample the parameter space around them. Within
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History Matching with Respect to Reservoir Structure
Authors S.I. Aanonsen, O. Lia and O.J. ArntzenA013 HISTORY MATCHING WITH RESPECT TO RESERVOIR STRUCTURE Abstract 1 A practical method for history-matching with respect to geological fault properties (fault displacement average dip and strike smear-gouge-ratio shale-smear-factor etc.) is presented. The method is based on coupling commercial software for fault modelling with a reservoir simulator. The history-matching and control of these tools are performed using standard optimization routines in MATLAB. Both large seismic faults as well as small subseismic faults can be modelled. For the large faults the simulation model grid is automatically deformed in each iteration of the history-matching process. The sealing effect is based on an
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Robust Coarse Scale Modeling of Flow and Transport in Heterogeneous Reservoirs
Authors L.J. Durlofsky, Y. Chen and X.H. WenA014 ROBUST COARSE SCALE MODELING OF FLOW AND TRANSPORT IN HETEROGENEOUS RESERVOIRS Abstract 1 Techniques for the generation of accurate coarse scale simulation models are described and applied. An iterative procedure for the calculation of upscaled transmissibilities referred to as an adaptive localglobal method is presented. This approach uses a global coarse scale flow solution for the determination of the local boundary conditions required for the upscaling computations. Enhanced accuracy relative to existing techniques is demonstrated. For transport calculations the method is applied in the context of multiscale modeling (which entails a reconstruction of the fine scale velocity field followed
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Classification of Pseudo Functions Using Statistical Analyses
Authors E. Bagnolet, P. Samier, P. Dupouy and J.P. ValoisA015 CLASSIFICATION OF PSEUDO FUNCTIONS USING STATISTICAL ANALYSES 1 Pierre SAMIER 1 Eline BAGNOLET 2 Philippe DUPOUY 3 Jean Paul VALOIS 1 1 TOTAL CSTJF Avenue Larribau 641018 PAU Cedex – France 2 IMPERIAL COLLEGE Earth Science and Engineering – London - UK 3 TOTAL YEMEN – SANA’A - YEMEN Abstract In reservoir engineering although upscaling absolute permeability is now a well-established technique upscaling relative permeability and capillary pressures remains still a complicated issue. Pseudo relative permeabilities and capillary pressures are used in reservoir simulation in an attempt to capture the effects on multi-phase fluid flow of heterogeneities not represented
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3D Upscaling of Fault Damage Zones for Reservoir Modelling
Authors A.Z. Vaszi, S.D. Harris and R.J. KnipeA016 3D UPSCALING OF FAULT DAMAGE ZONES FOR RESERVOIR MODELLING 1 ATTILA Z. VASZI SIMON D. HARRIS AND ROB J. KNIPE Rock Deformation Research School of Earth Sciences University of Leeds Leeds LS2 9JT UK Abstract The characterisation of the architecture of fault zones where a damage zone around the major slip surface is composed of a complex array of minor faults is only usually achievable via 2D maps or 1D line samples or well logs. In this paper we address issues related to generating a 3D stochastic fault damage zone (FDZ) model that creates realistic fault systems resembling those
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The Development of Upscaling for Poroelasticity and Macro-Anisotropy Modeling of the Biot Problem
Authors M.Y. Zaslavsky and A.K. PergamentA017 THE DEVELOPMENT OF UPSCALING FOR POROELASTICITY AND MACRO-ANISOTROPY MODELING OF THE BIOT PROBLEM Abstract 1 This paper focuses on blocks upscaling for 3D poroelastic problem in fractured media. In the beginning the set of upscaling procedures for determining the coefficients or poroelastic equations is examined. It is established that the P. King procedure [14] and others may be obtained by developing the specific finite difference schemes for each cell of the grid each difference scheme being in accordance with the kind of upscaling procedure. As a result in poroelastic theory the diagonal effective tensors of permeability and elastic moduli
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A New Way of Looking at Upscaling
Authors G.E. Pickup, H. Monfared, P. Zhang and M.A. ChristieA018 A NEW WAY OF LOOKING AT UPSCALING Abstract 1 G.E. Pickup H. Monfared P. Zhang and M.A. Christie Institute of Petroleum Engineering Heriot-Watt University Edinburgh EH14 4As Scotland UK. The current trend in reservoir simulation is to generate a large number of models (sometimes many thousands) in order to investigate the effects of uncertainty in model parameters. For speed often only coarse-scale models are created. However these may over-look the effects of finer-scale structure. On the other hand generating fine-scale models presents problems because it is time-consuming and the models have to be upscaled to reduce the number of
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Joint Propagation in Relatively Undeformed Bedded Sedimentary Rock through Compression Failure Mechanisms
Authors D. Picard, C. Putot and D. LeguillonA020 JOINT PROPAGATION IN RELATIVELY UNDEFORMED BEDDED SEDIMENTARY ROCK THROUGH COMPRESSION FAILURE MECHANISMS 1 Abstract The representation of joint (opening –mode fractures) and fracture swarm development is classically presented by a first order phenomenon involving effective traction orthogonal to fracture plane (regional extension). Although commonly used this hypothesis seems to us less realistic in many circumstances and may conflict with geological observations. Therefore we describe fracture growth as a second order phenomena resulting from crack parallel compression. Figure 1 : systematic jointing Figure 2 : fracture swarm (after Auzias[1]) One example of systematic joint characterisation D. PICARD 1 2 C.
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Characterizing Fractured Reservoirs Using Structural Attributes
Authors J.J. Royer, P. Muron, R. Moyen, L. Mace and J.-L. MalletA021 CHARACTERIZING FRACTURED RESERVOIRS USING STRUCTURAL ATTRIBUTES Abstract 1 A new full-3D balanced restoration technique for geological structures is used to estimate the strain tensor and to define fractured zones applying failure criteria. This approach based on the elastic solid theory of continuous media gives the tensor of deformations. In simple cases such as thin plates this new approach is in agreement with results predicted by the theory. Strain tensor invariants (dilatation coefficient principal strains etc.) coupled with mechanical properties of rock types are used to characterize the distribution of fracture orientations. The method is applied on the Split Mountain
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The Importance of Incorporating the Multi-Phase Flow Properties of Fault Rocks into Production Simulation Models
Authors B. Al-Busafi, Q.J. Fisher and S.D. HarrisA022 THE IMPORTANCE OF INCORPORATING THE MULTI-PHASE FLOW PROPERTIES OF FAULT ROCKS INTO PRODUCTION SIMULATION MODELS Abstract 1 Numerical modelling has been conducted to determine in which situations it is better to include the multi-phase flow properties of fault rocks in production simulation models and when it is better to accurately include fault rock thickness. The answer to this problem depends on drive mechanism well position and the capillary pressure distribution along the fault as well as on which parameters need to be modelled (e.g. bottom-hole pressures hydrocarbon production rates water cuts etc.). In the situation where a producer is
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Characterisation and Modelling of Fractured Reservoirs – Static Model
Authors C. Daly and D. MuellerA024 CHARACTERISATION AND MODELLING OF FRACTURED RESERVOIRS – STATIC MODEL 1 Abstract Construction of a static reservoir model for a fractured reservoir will typically involve some or all of the following steps: selection of the fracture sets to be considered; identification of the spatial distribution of these fracture sets; modeling of the fractures as objects; assignment of appropriate petrophysical properties to the fractures in particular permeability; communication with a flow simulator. For each fracture set that is to be modeled trend information for density orientation and dip is chosen to control the spatial distribution. If the fracture set is related
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3D Fracture Characterization Based on Geomechanics and Geologic Data Uncertainties
Authors L. Macé, L. Souche and J.-L. Mallet1 A025 3D FRACTURE CHARACTERIZATION BASED ON GEOMECHANICS AND GEOLOGIC DATA UNCERTAINTIES Laetitia MACÉ Laurent SOUCHE and Jean-Laurent MALLET Nancy School of Geology - Gocad Research Group BP 40 Avenue du Doyen Marcel Roubault 54501 Vandoeuvre-les-Nancy France Abstract This paper addresses the issue of Naturally Fractured Reservoirs where fracturation patterns are assumed to be closely related to stress history. Introducing uncertainties on geologic data we propose to compute a new stochastic parameter the Failure Probability based on geomechanics. This fracture parameter is then used to simulate 3D fracture density and orientation analogue. 1 Introduction Natural fractures have dramatic effects on
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Reservoir Characterization Using Multiple-Scale Geological Patterns
Authors G.B. Arpat and J. CaersA026 RESERVOIR CHARACTERIZATION USING MULTIPLE-SCALE GEOLOGICAL PATTERNS Abstract 1 Flow in a reservoir is mostly controlled by the connectivity of extreme permeabilities which are generally associated with marked geological patterns. Thus accurate characterization of such patterns is required for successful flow performance and prediction studies. Multiple-point geostatistics (MPS) a relatively new branch of geostatistics manages to achieve the desired pattern reproduction while successfully constraining to local subsurface data. MPS uses the concept of training image to quantify geological heterogeneities. In MPS a training image is defined as a conceptual depiction of the type of heterogeneities that the geologist believes to
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Uncertainty Assessment in PUNQ-S3 – Neighbourhood Algorithm Framework for Geostatistical Modelling
Authors V. Demyanov, S. Subbey and M. ChristieA027 UNCERTAINTY ASSESSMENT IN PUNQ-S3 – NEIGHBOURHOOD ALGORITHM FRAMEWORK FOR GEOSTATISTICAL MODELLING Abstract 1 Uncertainty quantification and forecasting is a problem of growing importance in reservoir production forecasting. The goal is no longer to produce a single best history matched model but to generate multiple models which are “good enough” to honour the production history data and at the same time include the effects of uncertainty in the model components. We have developed an uncertainty quantification framework for reservoir performance forecasting based on the Neighbourhood Algorithm (NA) which aims to provide a rigorous way to generate an ensemble of parameterised
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Quantification of Uncertainty for Improved Recovery Prediction – Application to Plateau Duration Maximization by Optimizing Well Rate Profiles
Authors I. Zabalza-Mezghani, Y. Le Gallo, M. Mezghani, M. Feraille and E. ManceauA028 QUANTIFICATION OF UNCERTAINTY FOR IMPROVED RECOVERY PREDICTION – APPLICATION TO PLATEAU DURATION MAXIMIZATION BY OPTIMIZING WELL RATE PROFILES Abstract 1 Development strategies and reservoir management techniques play a crucial role in optimizing oil and gas recovery. Management decisions must often be made in a highly uncertain context. Uncertainties are involved in all steps of the construction of the reservoir model (uncertainties on data acquisition geological assumptions modeling technique history matching process etc). These uncertainties may induce significant variations on production forecasts and should be taken into account in the decision making process. Making better decisions which account for uncertainty
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Assessing Uncertainty and Optimizing Production Schemes – Experimental Designs for Non-Linear Production Response Modeling an Application to Early Water Breakthrough Prevention
Authors C. Scheidt and I. Zabalza-MezghaniA029 ASSESSING UNCERTAINTY AND OPTIMIZING PRODUCTION SCHEMES – EXPERIMENTAL DESIGNS FOR NON-LINEAR PRODUCTION RESPONSE MODELING AN APPLICATION TO EARLY WATER BREAKTHROUGH PREVENTION 1 Céline SCHEIDT and Isabelle ZABALZA-MEZGHANI Institut Français du Pétrole 1& 4 avenue Bois Préau 92852 Rueil malmaison France Abstract Production scheme management becomes more and more difficult as production time increases due to water production behavior. In fact one of the most critical aspects for maximizing oil recovery after several years of production is to be able to assess water arrival times and then to infer the most appropriate scheme to delay or reduce water production. Experimental
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Uncertainty Quantification for Mature Field Combining the Bayesian Inversion Formalism and Experimental Design Approach
Authors M. Feraille and F. RoggeroA030 UNCERTAINTY QUANTIFICATION FOR MATURE FIELD COMBINING THE BAYESIAN INVERSION FORMALISM AND EXPERIMENTAL DESIGN APPROACH Abstract 1 The goal of a reservoir study is to help to decide the future development of a field based on technical and economic criteria. To reach this goal one would like to quantify the impact of uncertainty on production and economic forecasts to take the decision while considering the risk. Practically it would correspond to supply to the manager the uncertainty distribution (or P10 50 and 90) of the production forecasts associated to each scenario. The uncertainty on the production forecasts is linked to
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Geo-Models Production Forecast with a Non Linear N-Dimensional Interpolator
Authors E. Fetel, J.-L. Mallet and J.C. Voillemont1 A031 GEO-MODELS PRODUCTION FORECAST WITH A NON LINEAR N-DIMENSIONAL INTERPOLATOR Emmanuel FETEL Jean-Laurent MALLET and Jean-Charles Voillemont Nancy School of Geology - Gocad Research Group BP 40 Avenue du Doyen Marcel Roubault 54501 Vandoeuvre-les-Nancy France Abstract One of the most challenging problem in reservoir modelling is to handle the uncertainty on the reservoir flow performance. Common uncertainty analysis approaches use a large number of equiprobable model however among them only a limited number are considered for detailed flow simulation. This paper proposes an approach based on a n-dimensional response surface to forecast the reservoir flow performance on non-simulated model.
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Reservoir Optimization Tool for Risk and Decision Analysis
Authors B. Couët, W.J. Bailey and D. WilkinsonA032 RESERVOIR OPTIMIZATION TOOL FOR RISK AND DECISION ANALYSIS Abstract 1 BENOÎT COUËT WILLIAM J. BAILEY DAVID WILKINSON * Schlumberger-Doll Research 36 Old Quarry Road Ridgefield Connecticut 06877-4127 U.S.A. * Efficient Solutions Inc. 311 Ned’s Mountain Road Ridgefield Connecticut 06877 U.S.A. A software tool is described that enables optimization for maximizing the asset value of a real reservoir both with and without uncertainty. Modular architecture allows examination of different objective functions optimization schemes and financial models. The method generates an efficient frontier for risk and decision analysis with the goal to maximize asset returns while simultaneously mitigating the risk. The
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Practical Methods for Uncertainty Assessment of Flow Predictions for Reservoirs with Significant History – A Field Case Study
Authors A. Castellini, J.L. Landa and J. KikaniA033 PRACTICAL METHODS FOR UNCERTAINTY ASSESSMENT OF FLOW PREDICTIONS FOR RESERVOIRS WITH SIGNIFICANT HISTORY –AFIELD CASE STUDY Abstract 1 This paper discusses two practical strategies to quantify the uncertainty in production and injection forecasts for a field with a long and complex production history with poor quality measurements. These methods are applied to a large offshore field in Africa that has been on production for more than 30 years. The first method follows an advanced Experimental Design framework and requires the use of non-linear Response Surfaces such as kriging. The second method uses sensitivity coefficients; it can be considered as
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Unstructured 3D Gridding and Upscaling for Coarse Modeling of Geometrically Complex Reservoirs
Authors M. Prevost, F. Lepage, L.J. Durlofsky and J.-L. Mallet1 A035 UNSTRUCTURED 3D GRIDDING AND UPSCALING FOR COARSE MODELING OF GEOMETRICALLY COMPLEX RESERVOIRS M. PREVOST 1 F. LEPAGE 2 L.J. DURLOFSKY 3 J.-L. MALLET 4 Abstract The generation of accurate and reliable unstructured 3D models for reservoir simulation remains a challenge. In this paper new developments for grid generation upscaling and streamline simulation for such models are described. In combination these techniques provide a prototype workflow for the construction of unstructured simulation models. The grid generation framework described here allows for the incorporation of both geometrical constraints and grid-resolution targets. Flow adaptation of the unstructured grid (i.e. higher grid
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Generation of Unstructured 3D Streamline Pressure-Potential-Based K-Orthogonal Grids
By L. Souche2 Figure 1: Left : A simple SPP-grid Right :Primal-Dual method [4] In the lower right picture the arrow highlights a particular oblique face artifact due to the violation of the cocircularity condition. The left term of the equation is the flow term the right term is the accumulation term : � ¨ is the density of phase� � ¨ is its saturation and� is the porosity of the medium. The velocity term ¦ � is given by the Darcy’s Law : ¨ ¡ � ¡� � ¨ (2) � � ¨ is the relative permeability of phase� � ¨
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Use of Time-Dependent Flow-Based PEBI Grids in Reservoir Simulation
Authors M.J. Mlacnik, A.W. Harrer and Z.E. HeinemannA037 USE OF TIME-DEPENDENT FLOW-BASED PEBI GRIDS IN RESERVOIR SIMULATION Abstract 1 This paper presents a technique applicable for the generation of 2½ dimensional PEBI grids based on streamlines and isopotentials for specific well configurations. The procedure presented involves a hybrid gradient Laplacian grid optimization procedure global-local transmissibility upscaling suitable for the resulting partially unstructured grids and time-dependent handling of flow-based grids using the windowing technique. Examples for grids in complex environments will be shown and numerical simulation results will be presented for a channelized reservoir. Introduction Martin J. Mlacnik ([email protected]) 1 Andreas W. Harrer 2 and Zoltan E. Heinemann
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Growing Region Technique Applied to Grid Generation of Complex Fractured Porous Media
More LessA038 GROWING REGION TECHNIQUE APPLIED TO GRID GENERATION OF COMPLEX FRACTURED POROUS MEDIA Abstract 1 This paper describes a new methodology to generate unstructured grid for complex fractured porous media. A growing region technique is used to perform a volume partitioning of the space between the fractures. Then the fractures are identified as interfaces between matrix control volumes. The control volumes are represented by convex polygons in 2D and convex polyhedra in 3D. The methodology is illustrated with 2D and 3D examples. For a 2D example the presented gridding technique is combined with an efficient discrete fracture model to perform
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3D Hybrid Mesh Generation for Reservoir Simulation
Authors C. Bennis, N. Flandrin and H. BorouchakiA039 3D HYBRID MESH GENERATION FOR RESERVOIR SIMULATION Abstract 1 A great challenge for flow simulators of new generation is to gain more accuracy at well proximity within complex geological structures. For this purpose a new approach based on hybrid mesh modeling was proposed in 2D in [4]. In this hybrid mesh the reservoir is described by a structured quadrilateral mesh and drainage areas around wells are represented by radial circular meshes. In order to generate a global conforming mesh unstructured transition meshes constituted by convex polygonal elements satisfying finite volume properties are used to connect together these two structured
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Unmatched Multiblock Grids for Simulation of Geometrically Complex Reservoirs
Authors C. Wolfsteiner, S.H. Lee, H.A. Tchelepi, P. Jenny and W.H. ChenB001 UNMATCHED MULTIBLOCK GRIDS FOR SIMULATION OF GEOMETRICALLY COMPLEX RESERVOIRS Abstract C. WOLFSTEINER 1 S.H.LEE 1 H. A. TCHELEPI 2 P. JENNY 3 and W. H. CHEN 1 (1) ChevronTexaco Energy Technology Co. (2) Stanford U. (3) ETH Zürich A simulator with hexahedral multiblock grids has been developed to simulate flow in reservoirs with geometrically complex features (i.e. faults and wells). A reservoir model can always be gridded with multiblock grids with matching grid lines between blocks. However this matching requirement may introduce many small cells that have little impact on the simulation results as well as unnecessarily increase the
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Recent Advances for MPFA Methods
Authors G.T. Eigestad, T. Aadland, I. Aavatsmark, R.A. Klausen and J.M. Nordbotten¡ ¡ ¤ ¥ ¦ ¨ ¦ � � � � � � � ¨ ¦ � � � ¥ � � � � � ¦ � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � �
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Multi Point Flux Approximations and Finite Element Methods; Practical Aspects of Discontinuous Media
Authors R.A. Klausen and G.T. Eigestad� � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � � �
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A Flux-Vector-Based Green Element Method for Highly-Heterogeneous Media
Authors P. Lorinczi, S.D. Harris and L. ElliottB004 A FLUX-VECTOR-BASED GREEN ELEMENT METHOD FOR HIGHLY-HETEROGENEOUS MEDIA Abstract 1 The Green element method (GEM) is a modern technique for solving nonlinear problems encountered in flow in porous media. It combines the second-order accuracy of the boundary element method with the efficiency and versatility of the finite element method. The high accuracy of the GEM comes from the direct representation of the normal fluxes as unknowns. However the classical GEM procedure which overcomes the difficulty imposed by a large number of normal fluxes at each internal node by approximating them in terms of the primary variable leads to a
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A New Fast Fourier Transform Algorithm for Fluid Flow Simulation
Authors L. Ricard, M. Le Ravalec-Dupin, B. Noetinger and Y. GuéguenB005 A NEW FAST FOURIER TRANSFORM ALGORITHM FOR FLUID FLOW SIMULATION Abstract 1 Fluid flow simulators are usually based upon finite difference finite volume or also finite element schemes. As these methods can be CPU-time consuming we develop an alternative approach involving Fast Fourier Transforms to simulate steady-state single-phase flow. In this paper two algorithms are envisioned. They apply to heterogeneous porous media submitted to periodic boundary conditions. Basically the algorithms are designed to solve sequentially the pressure equation in the frequency space. For the first algorithm the convergence rate is proportional to the permeability contrast. It can be pretty
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Multi-Scale Finite-Volume Method for Highly Heterogeneous Porous Media with Shale Layers
More LessB006 MULTI-SCALE FINITE-VOLUME METHOD FOR HIGHLY HETEROGENEOUS POROUS MEDIA WITH SHALE LAYERS Abstract 1 A multi-scale finite-volume (MSFV) method for solving elliptic problem in highly heterogeneous media was recently developed. The goal of the MSFV method is not simply to capture the large-scale effects of the fine-scale heterogeneity but to fully describe the fine-scale velocity field with the original resolution. Thus the MSFV method differs fundamentally from upscaling since it provides an efficient tool for solving large flow problems with fine-scale resolution. The first step in the MSFV method is to compute the effective parameters that are used to solve
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A Finite Element Upscaling Technique Based on the Heterogeneous Multiscale Method
Authors J. Ma and G. CouplesB007 A FINITE ELEMENT UPSCALING TECHNIQUE BASED ON THE HETEROGENEOUS MULTISCALE METHOD Abstract 1 Simulating fluid flow through heterogeneous reservoirs requires the use of upscaling techniques that account for subscale effects but which nevertheless accurately represent the fluid flow behaviors at the reservoir scale. To simulate single-phase fluid flow through a system upscaling often involves estimating the unknown permeability at the coarse scale using information available at the fine scale. Many upscaling methods share a common feature: they define localized fine-scale problems or cell problems and solve them to estimate the permeability at the coarse scale. Cell problems are often
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Comparison of Methods for Downscaling of Coarse Scale Permeability Estimates
Authors A.-A. Grimstad and T. Mannseth1 B008 COMPARISON OF METHODS FOR DOWNSCALING OF COARSE SCALE PERMEABILITY ESTIMATES Alv-Arne Grimstad 1 and Trond Mannseth 1 2 1 RF-Rogaland Research 2 Now with CIPR - Centre for Integrated Petroleum Research University of Bergen Abstract Fine scale reservoir models with all available information integrated are important for predictions of future behavior. Traditionally fine-scale realizations of the geostatistical model are adjusted in some way to integrate production data. Since these data do not support high resolution of the permeability representation strong regularization of the history matching problem is needed. In this paper we study how integration of information may
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Reduced-Order Optimal Control of Waterflooding Using POD
Authors J.F.M. van Doren, R. Markovinovic and J.D. JansenB009 REDUCED-ORDER OPTIMAL CONTROL OF WATERFLOODING USING POD 1 J. VAN DOREN * R. MARKOVINOVI� * AND J.D. JANSEN *+ * Delft University of Technology Dept. of Geotechnology PO box 5028 2600 GA Delft The Netherlands + Shell International Exploration and Production Exploratory Research PO box 60 2280 AB Rijswijk The Netherlands Abstract Model-based optimal control of water flooding generally involves multiple reservoir simulations which makes it into a time-consuming process. Furthermore if the optimization is combined with inversion i.e. with updating of the reservoir model using production data some form of regularization is required to cope with the ill-posedness
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Reduced Representations in Reservoir Simulation – Extending POD to Include More General Optimality Conditions
Authors R. Markovinovic, J.D. Jansen and J.R. RommelseB010 REDUCED REPRESENTATIONS IN RESERVOIR SIMULATION - EXTENDING POD TO INCLUDE MORE GENERAL OPTIMALITY CONDITIONS 1 R. MARKOVINOVI� * J.D. JANSEN *+ AND J.R. ROMMELSE * * Delft University of Technology Dept. of Geotechnology PO box 5028 2600 GA Delft The Netherlands + Shell International Exploration and Production Exploratory Research PO box 60 2280 AB Rijswijk The Netherlands Abstract We consider mathematical reduction methods to generate low-order system representations of high-order reservoir models. In this paper we concentrate on possible extensions of our previous work on the use of proper orthogonal decomposition (POD) for effectively representing the reservoir dynamics (e.g.
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Stochastic Reservoir – The Buckley-Leverett Model
More LessB011 STOCHASTIC RESERVOIR – THE BUCKLEY- LEVERETT MODEL Abstract 1 The stochastic approach has found broad acceptance in weather forecasting global climate modelling or hydrology. In the oil business already in the sixties such tools were used to represent the complex and intricate structure of a porous media. Scheidegger Matheron and Beran were among the people who used such approach to deduce Darcy law at a macroscopic scale the flow being modelized at the microscopic scale by Stokes equation. A modern revival of such an approach more mathematically founded could be the homogenisation theory which was developed since the eighties.
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Stationary Fronts in Hetererogeneous Reservoirs
Authors V. Artus and B. NoetingerB012 STATIONARY FRONTS IN HETEROGENEOUS RESERVOIRS Abstract 1 In this paper we show that the careful study of the two-phase front can improve up-scaling techniques for two phase immiscible flows in heterogeneous reservoirs. A detailed numerical and analytical study of the dynamics of the front shows that stochastic approaches cannot neglect the viscous coupling between the pressure and saturation. A very strong interaction exists between the heterogeneity and the stability or instability of the fluid flow displacement. This coupling is responsible for a qualitative and quantitative change of the form of the large scale equations that must be accounted for
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Macroscopic Simulation of Three Phase Flow Using Consistent Pore-Level Model Relative Permeabilities and Capillary Pressures
Authors K.S. Sorbie, I.S. Ivanova and M.I.J. van DijkeB014 MACROSCOPIC SIMULATION OF THREE PHASE FLOW USING CONSISTENT PORE- LEVEL MODEL RELATIVE PERMEABILITIES AND CAPILLARY PRESSURES Abstract 1 In this paper we perform 1D macroscopic simulations using theoretical three phase relative permeabilities and capillary pressures (3PRPs and 3PCPs) based on simple pore-scale models. These 3PRP models were used to perform a range of 1D three phase macroscopic simulations where “low” and “high” viscosity gas has been injected into a system at constant oil and water saturation. No trapped saturations were allowed in these model calculations in order to clarify the structure of the saturation profiles and the phase paths
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Simulation of Air Injection in Light-Oil Fractured Reservoirs – From the Matrix Block Scale to the Cross-Section Scale by Using a Dual-Porosity Model
Authors P. Delaplace, S. Lacroix, B. Bourbiaux and Y. LagalayeB015 SIMULATION OF AIR INJECTION IN LIGHT-OIL FRACTURED RESERVOIRS – FROM THE MATRIX BLOCK SCALE TO THE CROSS- SECTION SCALE BY USING A DUAL- POROSITY MODEL Abstract Air injection can be an economical alternative for pressure maintenance of fractured reservoirs as it avoids re-injecting a valuable associated gas and/or generating or importing a make-up gas. In addition the oil recovery can be enhanced thanks to the thermal effects associated with oil oxidation. However such an improved recovery method requires a careful assessment of the involved reservoir displacement mechanisms in particular the magnitude and kinetics of matrix-fracture transfers. Considering the situation
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Simulation of Displacement Processes by a LBM VOF-CSF Model
Authors C. Redl and J. SteinerB016 SIMULATION OF DISPLACEMENT PROCESSES BY A LBM VOF-CSF MODEL Abstract 1 The Lattice Boltzmann Method (LBM) is known as a very powerful tool for simulating fluid flow processes in highly complex structures. The structure of porous media can be resolved in detail by means of e.g. computer tomography and afterwards used in the LBM. However most LBM models were restricted to single phase flows or to multiphase flows with only small density differences between the phases. By means of the LBM VOF-CSF (LBM Volume of Fluid- Continuum Surface Force) model it is possible to handle multiphase flows with high
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A Black-Oil and Compositional IMPSAT Simulator with Improved Compositional Convergence
Authors J. Haukås, I. Aavatsmark and M. EspedalB017 A BLACK-OIL AND COMPOSITIONAL IMPSAT SIMULATOR WITH IMPROVED COMPOSITIONAL CONVERGENCE Abstract A unified black-oil and compositional simulator has been developed using an IMPSAT formulation within the framework of the Volume Balance Method. By new ways of determining explicit equations and variables we obtain improved convergence over the traditional compositional formulations. In addition simulator maintenance and development costs are reduced due to the unified formulation. Application of the new formulation to simulation of a multiphase multicomponent problem is presented in the paper. Introduction Reservoir Simulation in General All reservoir simulators solve a set of differential equations. If the reservoir fluids
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Mass Conserving Forward & Adjoint Black-Oil Reservoir Simulation for (Under)Saturated Oil
Authors J.R. Rommelse and C.P.J.W. van KruijsdijkB018 MASS CONSERVING FORWARD & ADJOINT BLACK-OIL RESERVOIR SIMULATION FOR (UNDER)SATURATED OIL 1 J.R. Rommelse & C.P.J.W. van Kruijsdijk Delft University of Technology Department of Geotechnology PO Box 5028 2600 GA Delft The Netherlands Abstract Reservoir simulators that efficiently calculate gradients are not yet widely used because for few control parameters (or little data available) it is feasible to approximate gradients by numerical perturbations. As more parameters need to be handled the need for efficiently calculating gradients increases. In this paper it is shown how to implement a Black-Oil reservoir simulator for (under)saturated oil with gradient capabilities. The usefulness of
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Statistical Moment Equations for Flow in Composite Heterogeneous Porous Media
Authors H. Tchelepi and L. LiB019 STATISTICAL MOMENT EQUATIONS FOR FLOW IN COMPOSITE HETEROGENEOUS POROUS MEDIA Abstract L. Li 1 and H. A. TCHELEPI 2 (1) ChevronTexaco Energy Technology Co. (2) Standard U. We describe a conditional statistical moment equations (CSME) method for quantifying the uncertainty in flow related quantities (pressure and velocity) due to incomplete knowledge (uncertainty) about the permeability field in a composite system. We identify multiple permeability regions in the flow domain. For each region the mean variance and covariance of permeability are specified. We focus on the flow problem; specifically we study the first two statistical moments of pressure for incompressible
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Analysis and Design of Coreflow Experiments
By A.E. FinchamB020 ANALYSIS AND DESIGN OF COREFLOW EXPERIMENTS Abstract 1 T. FINCHAM TOTAL UK Geoscience Research Center 33 Cavendish square LONDON UK Relative permeabilities are empirical factors that are used to correct the single-phase Darcy’s law for application to multiphase flow. The relative permeability of any phase is an increasing function of the phase saturation. Relative permeabilities are important input data for reservoir simulation studies and have a strong influence on reservoir behaviour. There are several different types of laboratory experiments on core samples that are used to find the relative permeability of reservoir rock: unsteady state steady-state centrifuge. To extract
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Toward Reservoir Simulation on Geological Grid Models
Authors J.E. Aarnes and K.-A. LieB021 TOWARD RESERVOIR SIMULATION ON GEOLOGICAL GRID MODELS Abstract 1 We present a reservoir simulation scheme that gives accurate resolution of both large-scale and fine-scale flow patterns. The method uses a mixed multiscale finite-element method (MMsFEM) to solve the pressure equation on a coarse grid and a streamline-based technique to solve the fluid transport on a fine-scale subgrid. Through this combination we aim towards a numerical scheme that facilitates reservoir simulation of large heterogeneous geomodels without upscaling. We validate the method by applying it to a 3D upscaling benchmark case taken from the 10th SPE Comparative Solution Project. The numerical
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Parallel Anisotropic Cartesian Grid Adaptation for In-Situ Combustion Simulations
Authors J. Nilsson, M. Gerritsen and R. YounisB022 PARALLEL ANISOTROPIC CARTESIAN GRID ADAPTATION FOR IN-SITU COMBUSTION SIMULATIONS Abstract 1 A parallel anisotropic adaptive Cartesian grid method for simulating in-situ combustion processes is presented. It is based on local cell-based grid refinement that allow fast transition from coarse to fine grids with very few extra cells. The anisotropic refinements allow for an improved alignment of the grid with important features in both the flow and the geology. The pressure equation is discretized on these anisotropic cells with a novel higher order compact finite volume method. The fluxes are computed with a second order accurate finite difference approximation combined
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A Parallel, Multiscale Approach to Reservoir Modeling
Authors O.I. Tureyen, O. Karacali and J. CaersB023 A PARALLEL MULTISCALE APPROACH TO RESERVOIR MODELING Abstract 1 Fine scale heterogeneities may have a significant effect on flow performances in subsurface formations. A large number of grid cells are required to capture the effect of such heterogeneities on flow responses. However flow simulation is rarely feasible without prior upscaling. This presents a problem for the joint integration of fine (well-log) and coarse (seismic production) data. Most approaches proceed in a hierarchical fashion where small scale data is integrated on the fine scale and after upscaling large scale data is integrated on a separate coarse scale. The correspondence between
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Reservoir Streamline Simulations Accounting for Effects of Capillarity and Wettability
Authors R.A. Berenblyum, A.A. Shapiro and E.H. StenbyB024 RESERVOIR STREAMLINE SIMULATION ACCOUNTING FOR EFFECTS OF CAPILLARITY AND WETTABILITY Abstract 1 In this work we present the mathematical grounds and the numerical developments necessary for introduction of the capillary forces and the wettability into a streamline-based simulator. The corresponding simulation tool (the CapSL simulator) has been developed on the basis of the 3DSL0.25 streamline simulator by R.Batycky SUPRI-C group Department of Petroleum Engineering Stanford. Our simulator is capable of predicting the two phase displacement with full account for capillary effects varying between different zones of a heterogeneous reservoir. Introduction In this paper we briefly describe the mathematical grounds
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A Front-Tracking Method for Hyperbolic Three-Phase Models
More LessB025 A FRONT-TRACKING METHOD FOR HYPERBOLIC THREE-PHASE MODELS Abstract 1 We develop and apply a front-tracking method for the numerical simulation of three-phase flow in porous media. The proposed framework combines analytical solutions to the corresponding Riemann problem with an efficient front-tracking method to study Cauchy and initial-boundary value problems. The method has the ability to track individual waves and give very accurate (or even exact) resolution of discontinuities. This numerical procedure is then used in combination with a streamline method for the simulation of three-dimensional three-phase flow problems. We demonstrate the applicability of the method through several numerical examples
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Non-Upwind Monotonicity Based Finite Volume Schemes for Hyperbolic Conservation Laws in Porous Media
By M.G. EdwardsB026 NON-UPWIND MONOTONICITY BASED FINITE VOLUME SCHEMES FOR HYPERBOLIC CONSERVATION LAWS IN POROUS MEDIA Abstract 1 Michael G Edwards Civil and Computational Engineering Centre University of Wales Swansea Singleton Park Swansea SA2 8PP UK The focus of this paper is on the development of Mathematically robust convective flow approximation schemes that offer the benefits of an upwind formalism without actually upwinding. Development of robust schemes that remove upwind dependence would represent a significant step forward leading to a fundamental simplification of current methods. Introduction Standard reservoir simulation schemes employ single-point upstream weighting [1] (a first order upwind scheme) for approximation
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Automated Determination of Aquifer Properties from Field Production Data
Authors G.M. Mittermeir, J. Pichelbauer and Z.E. HeinemannB027 AUTOMATED DETERMINATION OF AQUIFER PROPERTIES FROM FIELD PRODUCTION DATA Abstract 1 This paper presents a fully automated history matching (HM) method for average field and region pressures and for aquifer behaviors. This means that already with a single simulation run the average pressure and water influx is reproduced. The aquifer model analytical or gridded will not be designed as usual at the beginning but at the end of the HM process. The applicability of the method was extensively tested on many field cases. Practice showed that usual history matching time could be reduced by a factor of up to
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Model Selection and Inference for Reservoir History Matching
Authors G. Mtchedlishvili, H.-D. Voigt and F. HaefnerB028 MODEL SELECTION AND INFERENCE FOR RESERVOIR HISTORY MATCHING Abstract 1 This work presents the approach of the model selection and inference for the characterization of complex reservoirs. The Kullback-Leibler information (the measure of departure of the model from the true system) provides the theoretical basis for our methodology of choosing the best parameterized model for the reservoir. The applicability of alternative statistical model selection approaches such as Akaike’s Schwarz’s and Kashyap criteria are also tested. In many cases there is a substantial model selection uncertainty. Therefore as an extension to the model selection approaches the concept of model averaging
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A Practical, Gradient-Based Approach for Parameter Selection in History Matching
Authors A. Cominelli and F. FerdinandiB029 A PRACTICAL GRADIENT-BASED APPROACH FOR PARAMETER SELECTION IN HISTORY MATCHING Abstract Reservoir management is based on the prediction of reservoir performance by means of numerical simulation models. Reliable predictions require that the numerical model mimics the known production history of the field. Then the numerical model is iteratively modified to match the production data with the simulation. This process is termed history matching (HM). Mathematically history matching can be seen as an optimisation problem where the target is to minimize an objective function quantifying the misfit between observed and simulated production data. One of the main problems in history
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A Multiple Model Approach to History Matching and Uncertainty Analysis Using Time-Lapse Seismic
Authors K.D. Stephen, J. Soldo, C. MacBeth and M. ChristieB030 A MULTIPLE MODEL APPROACH TO HISTORY MATCHING AND UNCERTAINTY ANALYSIS USING TIME-LAPSE SEISMIC Abstract 1 We present an automated multiple model history matching method which integrates time-lapse seismic with production data and determines parameter uncertainty. For each simulation model we compare observed seismic attributes to synthetic impedance obtained via a petroelastic modelling step and grid transformation. For seismic and production data we then obtain a misfit which is used to update our model parameters in a Bayesian framework and accounts for model errors and data covariance. We show examples of the method's application to a UKCS field study and
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Optimization of Advanced Well Type and Performance
Authors L.J. Durlofsky, I. Aitokhuehi, V. Artus, B. Yeten and K. AzizB031 OPTIMIZATION OF ADVANCED WELL TYPE AND PERFORMANCE Abstract 1 The optimal deployment and operation of advanced (multilateral or “smart”) wells remains a challenge particularly in light of geological uncertainty. In this paper we apply a genetic algorithm for the determination of optimal well type location and trajectory. The ability of the method to determine the optimal well over multiple geological realizations under different risk attitudes is demonstrated. Next a combined history match – valve optimization procedure is developed. The method allows for the continuous updating of the geological model using data from downhole sensors. We show that for the
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Gradient Based Optimization of the WAG Process with Smart Wells
Authors T.E.H. Esmaiel, S. Fallah and C.P.J.W. van KruijsdijkB032 GRADIENT BASED OPTIMIZATION OF THE WAG PROCESS WITH SMART WELLS ABSTRACT 1 Smart well technology (“downhole measurement and control”) has progressed significantly over the last few years. Previous research has concentrated on the application of the technology to primary and secondary recovery 1 2 . This study aims to advance the technical application to tertiary recovery concentrating on water-alternating-gas (WAG) processes. The primary operational problem cited in literature is early breakthrough in production wells 3 . This is then potentially a prime candidate for smart wells based on the initial success with smart wells in mitigating early breakthrough and
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Closed-Loop Waterflooding
Authors K.M. Overbeek, D.R. Brouwer, G. Neavdal, C.P.J.W. van Kruijsdijk and J.D. JansenB033 CLOSED-LOOP WATERFLOODING Abstract 1 Closed-loop waterflooding involves the combined use of model-based optimization techniques and data assimilating techniques which are used to maximize ultimate recovery or net-present value (NPV) and to update the reservoir model during the producing life of the reservoir. In particular we used Optimal Control Theory (OCT) in combination with an Ensemble Kalman Filter (EnKF) to perform closed-loop water flooding. Testing the effectiveness of the closed-loop approach was done on a synthetic reservoir model (SRM) mainly because of repeatability and time aspects. We used the SRM to generate synthetic data such as production measurements and time-lapse
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Parallel Well Location Optimization Using Stochastic Algorithms on the Grid Computational Framework
Authors H. Klie, W. Bangerth, M.F. Wheeler, M. Parashar and V. MatossianB034 PARALLEL WELL LOCATION OPTIMIZATION USING STOCHASTIC ALGORITHMS ON THE GRID COMPUTATIONAL FRAMEWORK 1 Hector Klie 1 Wolfgang Bangerth 1 2 Mary F. Wheeler 1 Manish Parashar 3 and Vincent Matossian 3 1 Center for Subsurface Modeling The University of Texas at Austin Austin TX. 2 Institute for Geophysics The University of Texas at Austin Austin TX. 3 The Applied Software Systems Laboratory Rutgers University Piscataway NJ. Abstract The determination of optimal well locations is a challenging problem in oil production since it depends on geological and fluid properties as well as on economic parameters. This work addresses the efficient
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Extension of Streamline-Based Dual Porosity Flow Simulation to Realistic Geology
Authors M.R. Thiele, R.P. Batycky, M. Iding and M. BluntB035 EXTENSION OF STREAMLINE-BASED DUAL POROSITY FLOW SIMULATION TO REALISTIC GEOLOGY 1 MARCO R. THIELE 1 ROD P. BATYCKY 1 MARTIN IDING 2 & MARTIN BLUNT 3 1 Streamsim Technologies Inc. 9th European Conference on the Mathematics of Oil Recovery — Cannes France 30 August - 2 September 2004 2 Statoil 3 Imperial College London Abstract In this paper we extend the dual porosity streamline-based flow simulation method to complex geological grids containing both single and dual porosity gridblocks with multiple relative permeability regions. We use the streamline dual porosity formalism of Di Donato et al. [1] in conjunction with
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Characterization and Modeling of Fractured Reservoirs – Flow Simulation
By D.K. PontingB036 CHARACTERIZATION AND MODELING OF FRACTURED RESERVOIRS – FLOW SIMULATION Abstract 1 Flow simulation of fractured reservoirs has traditionally been performed using dual porosity models. These are typically characterized by a shape factor σ and a matrix material z-dimension dz. Rock characteristics such as σ and dz will usually vary over the volume of rock included in a reservoir simulator grid block. Assuming a single value per grid block may represent a significant oversimplification particularly when a process such as gravity drainage depends sensitively on the values. Fracture characterization can be done using simple models – such as the Warren
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Development and Application of a Hydraulic Fracture Reservoir Simulation Tool
Authors T. Friedel and F. HäfnerB037 DEVELOPMENT AND APPLICATION OF A HYDRAULIC FRACTURE RESERVOIR SIMULATION TOOL Abstract Torsten Friedel and Frieder Häfner Institute of Drilling Engineering and Fluid Mining Freiberg University of Mining and Technology Agricolastraße 22 D-09596 Freiberg (Germany) A single component three-phase reservoir simulator is presented for detailed investigations of hydraulically fractured wells. The tool features a gas and loadwater phase capturing inertial non-Darcy flow and a special gel phase to represent the highly viscous fracturing fluid. Its non- Newtonian fluid characteristics is modelled by means of the Herschel-Bulkley fluid model with yield stress. Using state of the art numerical techniques the tool
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A Finite Element/Finite Volume Method for the Simulation of Coupled Flow and Geomechanics
By R. JuanesB038 A FINITE ELEMENT/FINITE VOLUME METHOD FOR THE SIMULATION OF COUPLED FLOW AND GEOMECHANICS Abstract 1 R. JUANES Department of Petroleum Engineering Stanford University Reservoir geomechanics is concerned with the simultaneous study of fluid flow and the mechanical response of the reservoir. Quantification of the state of deformation and stress of the reservoir is essential for the correct prediction of a number of processes of great economic impact such as primary compaction drive waterflooding surface subsidence seal integrity hydrofracturing sand production and well failure. The classical treatment of deformation of the reservoir through the rock compressibility is far from adequate
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Development and Application of a Multi-Lithology Stratigraphic Model under Maximum Erosion Rate
Authors V. Gervais, R. Masson and D. GranjeonP001 DEVELOPMENT AND APPLICATION OF A MULTI-LITHOLOGY STRATIGRAPHIC MODEL UNDER MAXIMUM EROSION RATE Abstract 1 We consider here a stratigraphic model coupling a multi-lithology diffusive model with a constraint on the erosion rate. A finite volume implicit in time discretization is derived from this model leading to a non-linear system which is solved using a Newton algorithm adapted to the constraint. However this method can lack robustness especially for small mesh sizes. In this paper we present a simulation of this model on real input data and some techniques to improve the convergence of the Newton method. Finally we will
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Splitting between Thermodynamics and Hydrodynamics in Compositional Modelling
Authors A.P. Pires, P.G. Bedrikovetsky and A.A. ShapiroP002 SPLITTING BETWEEN THERMODYNAMICS AND HYDRODYNAMICS IN COMPOSITIONAL MODELLING Abstract 1 Enhanced Oil Recovery (EOR) methods include injection of different fluids into reservoirs to improve oil displacement. Displacement of oil by any of these fluids involves complex physicochemical processes of interphase mass transfer phase transitions and transport properties changes. These processes can be divided into two main categories: thermodynamical and hydrodynamical ones. They occur simultaneously during the displacement and are coupled in the modern mathematical models of EOR. The model for one-dimensional displacement of oil by gas is analyzed in this paper. The main result is the splitting of thermodynamical
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Operative Estimation Technique of Hydraulic Fracturing Effects
Authors I.A. Vinogradova and A.A. PozdnyakovP003 OPERATIVE ESTIMATION TECHNIQUE OF HYDRAULIC FRACTURING EFFECTS Abstract 1 The calculation procedure for operative estimating of the fracture geometry and its influence on well productivity is presented. It uses the data of the basic technological and geological parameters for specific hydraulic fracturing treatment. The mathematical model of hydraulic fracturing process is the base of the technique which is simple enough to provide convenience and calculation rapidity. The possibility of such model creation is caused by quasistatic property of hydraulic fracturing process which allows receiving the finite (not differential) coupling between governing variables and parameters for each current condition. The
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Simulation of Naturally Fractured Reservoirs Utilizing an Effective Time-Splitting and Upscaling Methods
By T. SutopoP004 SIMULATION OF NATURALLY FRACTURED RESERVOIRS UTILIZING AN EFFECTIVE TIME- SPLITTING AND UPSCALING METHODS Abstract 1 The single-continuum approach employing effective permeability is one of the practical methods for simulating naturally fractured reservoirs. The MFVE method for full-tensor model was used to deal with permeability tensors resulted from upscaling of fractured systems. The governing equations can effectively be formulated in fractional flow equations; i.e. in terms of global pressure and saturation equations. An algorithm is implemented applying a highly accurate numerical approach based on the mixed finite volume element (MFVE) method for discretizing the pressure equation and a combination of
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Fracturing Optimization for Multi-Well System
Authors R.D. Kanevskaya, A.R. Andriasov and A.A. GaripovaP005 FRACTURING OPTIMIZATION FOR MULTI- WELL SYSTEM Abstract 1 Hydraulic fracturing has become common and widely used well stimulation technique in oil and gas industry. It has a long history but still there is a need in commercial simulator taking into account a reservoir and fracture flow simultaneously for multi-well system. This sort of 3D black oil simulator is presented. Program deals with numerical finite-difference simulation of flow in the reservoir and in the fractures but special in-flow formula for fractured wells was developed. Fracture orientation and length effects during two-phase flow in low permeable formation were studied on a
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Non-Uniform Uplayering of Heterogeneous Reservoir Models
By A.M. SharifP006 NON-UNIFORM UPLAYERING OF HETEROGENEOUS RESERVOIR MODELS Abstract A method for non-uniform uplayering of heterogeneous geological models is proposed. The method generates layering scheme by which coarse scale simulation models preserve the impact of reservoir heterogeneity on fluid flow and production response. The uplayering process involves generation of streamline-based dynamic response of the geological models. The response data were then analysed and processed to establish a set of connectivity-based attribute logs. Multivariate analysis and pattern recognition techniques were finally applied to produce layering scheme for coarse-scale simulation. The performance of the proposed method was investigated under a set of realistic
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The Thermodynamically Conditioned Difference Schemes for Multi-Phase Flow
Authors A.K. Pergament, S.B. Popov, M.F. Yambaev and V.D. YepishinP007 THE THERMODYNAMICALLY CONDITIONED DIFFERENCE SCHEMES FOR MULTI-PHASE FLOW Abstract 1 A.Kh. Pergament S.B. Popov M.F. Yambaev V.D. Yepishin Keldysh Institute for Applied Mathematics Moscow Miusskaya sq. 4 Central Geophysical Expedition Moscow Narodnogo opolcheniya str. 38 It is discussed that the system of filtration equations results in equations for thermodynamic potentials for example the Gibbs potential entropy etc. It is essential that porous pressure is a potential too because it is a volume density of the potentialΩ = − pV . The condition of full conservativeness means that the difference equations for thermodynamic potentials which are consequences of the difference
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A New Analytical Formulation for Tracer Injection Models Applied to Fractured Reservoirs
Authors M. Coronado, J. Ramírez-Sabag and O. Valdiviezo-MijangosP008 A NEW ANALYTICAL FORMULATION FOR TRACER INJECTION MODELS APPLIED TO FRACTURED RESERVOIRS Abstract 1 In the last three decades tracer tests has become an important technique to determine preferential flow directions and characterize reservoirs in oil fields. Knowing main communication channels and their properties in a reservoir is crucial in designing improved oil recovery strategies based on fluid injection such as water flooding. Many of the analytical models developed to describe tracer transport in porous media consider semi-infinite systems and pose conditions on the tracer concentration at the injection border. It has been shown recently that this type of
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The Definition of a Lithologic Well Profile with Application of Artificial Neural Networks
Authors V.E. Lyalin, V.V. Vasilyev, S.I. Kachurin and L.E. TonkovP009 THE DEFINITION OF A LITHOLOGIC WELL PROFILE WITH APPLICATION OF ARTIFICIAL NEURAL NETWORKS Abstract 1 Nowadays the advantages of an artificial intelligence allows to reach a better quality level of well log data processing as it allows to use automated hardware-software complexes functioning practically without involvement of a person. In this case the purpose of the work was the development and scientifically valid application of multilayer neural network (NN) for a solution of the task of qualitative well log data interpretation. The application of this network is of great importance in the field of processing and express-interpretation of logging
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Modeling the Effect of Saturation Change on Seismic Signature for Carbonate Reservoirs
Authors A.K. Tyagi, B. Jee and P. TyagiP010 MODELING THE EFFECT OF SATURATION CHANGE ON SEISMIC SIGNATURE FOR CARBONATE RESERVOIRS Abstract 1 The compressional acoustic waves in carbonates are assumed to travel primarily through the rock matrix and fluid does not play much of role. Extensive study has established the relationship between changes in acoustic property with saturation in clastics. However little is proposed for the interpretation of the Vp/Vs ratio in carbonates. Various studies like Li et. al. 2003 and Eberli et. al.’ 2003 and Alain Brie ‘ 2001 were published to monitor the changes in Vp/Vs ration with respect to saturation for heterogeneous carbonates. Alain
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Local Grid Refinement Methods for Basin Modeling – Migration Modeling
Authors Y. Caillabet, E. Flauraud and F.J.S. SchneiderP011 LOCAL GRID REFINEMENT METHODS FOR BASIN MODELING – MIGRATION MODELING Abstract 1 Local grid refinement (LGR) is applied in reservoir simulation routinely for structured and unstructured grids and implemented in commercial simulators. It is used to add detail where justified by data availability and to keep a coarse resolution where less data are available. In basin modelling LGR has not yet been implemented. It could be used in situations where seismic data are available at individual structures or prospects but not elsewhere in kitchen areas or within the sedimentary cover. Even more importantly for appraisal studies a data set
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Kamennoye Field Complex Geology and Reservoir Properties – A Challenge for Full Field Simulation of the Vast Area Formation in the West Siberia
Authors L. Kollbotn, L. Surguchev, A. Koundin, A. Lazeev, D. Mironov and A. OgnevP012 KAMENNOYE FIELD COMPLEX GEOLOGY AND RESERVOIR PROPERTIES – A CHALLENGE FOR FULL FIELD SIMULATION OF THE VAST AREA FORMATION IN THE WEST SIBERIA Abstract 1 LARS KOLLBOTN 1 LEONID SURGUCHEV 1 ALEXANDER KOUNDIN 2 ANDREY LAZEEV 2 DMITRY MIRONOV 3 & ALEX OGNEV 3 The Kamennoye field operated by TNK-BP is a part of the Krasnoleninsk oil province in the central part of the West Siberia. The field is situated in the low land left bank of the river Ob. The bulk volume of reserves (more than 500 million m3) are located in the upper part of a low
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Introducing a New Generation of Reservoir Simulation Software
Authors J.-M. Gratien, J.-F. Magras, P. Quandalle and O. RicoisP013 INTRODUCING A NEW GENERATION OF RESERVOIR SIMULATION SOFTWARE Abstract 1 As full field reservoir simulations require a large amounts of computing resources the trend is to use parallel computing to overcome hardware limitations. With a price to performance ratio often better than for traditional machines and with services in constant progress Linux clusters have become a very attractive alternative solution to traditional high performance facilities. Therefore oil&gas companies have very quickly been moving to these new architectures. This paper presents the new reservoir simulation software developed at IFP which has been specially designed for Linux clusters. The parallel model
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WAG Study– DOE-Based Sensitivity Analysis and Matrix Fracture Interaction Upscaling
Authors T.E.H. Esmaiel, S. Fallah, S.A. Haghighat and C.P.J.W. van KruijsdijkP014 WAG STUDY – DOE-BASED SENSITIVITY ANALYSIS AND MATRIX FRACTURE INTERACTION UPSCALING Abstract 1 The fundamental aspects of WAG (Water Alternating Gas) injection are still not well understood. This paper discusses two research topics into the WAG process being currently studied at TUDelft. The first part of this study looks at the sensitivity of production to rock and fluid properties on a pattern scale using tools derived from experimental design and response surface modeling. The second aspect discussed involves the fine-scale interaction of the WAG process in fractured media compared to the dual porosity formulation used in commercial simulators. The
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