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First EAGE Integrated Reservoir Modelling Conference - Are we doing it right?
- Conference date: 18 Nov 2012 - 21 Nov 2012
- Location: Dubai, United Arab Emirates
- ISBN: 978-94-6282-069-2
- Published: 25 November 2012
41 - 47 of 47 results
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Integrated Reservoir Geomechanics for Heavy Oil SAGD Design
Authors N.L. Deisman, R.J. Chalaturnyk, M.M. Khajeh, S.O. Ojagbohu and M.H. HamoudThe U of A recent work has been aimed at key components and uncertainties around the safe design of Steam Assisted Gravity Drainage for shallow heavy oil production. It has been demonstrated that during SAGD process, geomechanical behaviours heavily influence both the production of oil, and the integrity of the reservoir system. This work highlights the recent work through an integrated SAGD example. It is common practice to deploy geostatistical approaches to create several fine scale reservoir realizations and then upscale. However, geomechanically, these realizations are not included. As well, during production, permeability and porosity are geomechanically influenced during recovery however it is assumed that the relative permeability is unchanged. Several approaches have been deployed to assess the factor of safety for the reservoir caprock however, classic geotechnical approaches have not been used. This work will demonstrate through a synthetic project, an approach to upscale geomechanical properties from fine scale geostatistical realizations. Next, laboratory data will be shown on how relative permeability changes due to geomechanical influences during production. This data will then incorporated into coupled reservoir geomechanical simulation for several scenarios. Lastly, caprock integrity will be examined using a technique adopted from classic geotechnical engineering for slope stability problems.
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Enforcing Geological Consistency Through Interactive Seismic Flattening While Interpreting
Authors S. Panhaleux, M. Palomas, E. Malvesin, T. Laverne and L. SoucheBuilding a geologically consistent interpretation of a structurally complex area (thrust belts, flower-structures, etc.) is often a challenge, especially when the structure has to be interpreted from sparse data (e.g., 2D seismic lines) or when the quality of the seismic image is poor. A solution to these problems is to perform detailed interpretation in a domain in which the considered seismic section has been unfaulted and unfolded in a mechanically consistent way, without breaking the immersive experience of seismic interpreters. In this paper we present a software tool which performs a fully automated flattening process, which is tolerant to minor flaws in the input interpretation, able to handle the most complex structures (X, Y, λ, and thrust fault patterns), and integrated into a seismic interpretation platform. Two user workflows are proposed: (1) a QC of the structural and stratigraphic consistency of an already interpreted seismic section, and (2) an easy tracking of reflectors across faults, by interactively interpreting seismic horizons into a mechanically-flattened section, from which most tectonic deformation has been removed.
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Improve Convergence Rate of Seismic History Matching using NAPG
Authors S. Arwini and K.D. StephenHistory matching is a very important activity during the development and management of petroleum reservoirs. Matched models are fundamental to ensure reliable future forecasts, and enhance the level of understanding of the field via geological and reservoir models. Automated history matching (Figure 1) uses a mathematical algorithm to help choose new parameter values so that models better match historical data. The algorithm may be deterministic such as a gradient based method or stochastic such as a genetic or neighbourhood algorithm (NA). The former finds optimal solutions rapidly but the overall search is limited. Locally optimum solutions are all that may be found and uncertainty analysis is not effective. Stochastic methods are quasi-global but can be quite expensive. In this work we consider an approach to speed up the convergence rate of the NA. A proxy model is used to direct the stochastic search using gradients more effectively than is usual for the NA (Arwini and Stephen 2010). We call the new method Neighbourhood Algorithm with Proxy derived Gradients (NAPG). This results in finding solutions with far fewer models. The approach is further improved by updating the proxy model as we progress with history matching and the initialization is optimized using experimental design methods. We apply the approach to the Schiehallion field where we also use time lapse (4D) seismic data as dynamic constraints to reduce uncertainty to get a more reliable model that we might use it afterwards for the forecasting.
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Time Depth Conversion and Bulk Volume Uncertainty Estimation of a Prospect using well and Seismic Velocity Data
Authors L. Schulte, B.H. Tan and G.C. TayThe bulk volume uncertainty of an oil & gas field, offshore peninsular Malaysia is estimated from the depth error analysis of the depth converted structure. The study area is covered by 3D seismic that delivered the seismic velocity cube (RMO velocities). Eleven wells with check shot surveys were available for the seismic velocity calibration and the depth uncertainty estimation. The depth prediction and depth uncertainty estimation of the reservoir were checked against new wells that are being drilled during the year 2012.
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Gas Hydrate Reservoir Modeling and Validation
Authors E.G. Gloaguen, C.D.B. Dubreuil-Boisclair, B.G. Giroux and D.M. MarcotteThe decrease in conventional gas reservoir new discoveries combined with the increase of the market and improvement of the exploitation technologies push the industry to look for unconventional gas resources. Gas hydrates are one of the largest unconventional resource but also one of the less known. In this study, we use a modified bayesian algorithm in order to simulated gas hydrate grades at Mallik, TNO, Canada constrained by 3D seismic acoustic impedances. The results are validated using a high resolution seismic tomographic inversion. Even with the poor quality 3D seismic data, the proposed method is found to be very robust to estimate gas hydrate grades at Mallik.
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Practical Challenges & Recommended Solutions
More LessThis research shows the experience gained from characterizing and modeling 31 oil and gas fields located within the Middle East and North Africa regions. Analyzing and interpreting the results of these studies showed that five factors are affecting to a great extent the field development scenario(s). Regardless of the reservoir’s type, depth, depositional environment or the diagenetic history; the trap’s geometry, type or mechanism; the fluid’s type, properties or composition; the recovery method’s type or period; and the production history length, it is proved that three major technical and two non-technical factors are controlling the success of any field development plan. These are: reservoir heterogeneity, fault transmissibility, fracture effect, integration of people, data and managers and human resources. The targets of this paper are to highlight the major challenges modelers will face while characterizing and modeling their reservoirs and recommending the best solutions to overcome these challenges. Understanding these challenges benefits an integrated system for assisting in management of reservoir assets and demonstrates the latest appropriate technologies to increase productivity of any asset team.
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Parameter Sensitivity in Seismic Net Pay Workflow
By B. DuttonAn investigation to illustrate the relative importance of the controlling factors in estimating seismic net pay from colour-inverted band-limited impedance data has been performed. This was achieved by using a new, semi-automated implementation of the process, allowing the sensitivity of each of the key controls on the resulting net pay to be found quickly and easily. This automated workflow was run over a synthetic dataset varying different input parameters. The chi angle and the low frequencies used in building the tuning wedge were found to have the largest effect on the final volume. Using this technique on real datasets could greatly improve the understanding of the possible range of pay volumes, reducing risk and highlighting the key input parameters. The presentation will work through one manual iteration of the complete workflow, then show how this workflow can be automated. The results running the workflow on a synthetic dataset will be described and discussed.
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