TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractHistory matching and simulation of naturally fractured reservoir is a recurring challenge to many oil and gas companies seeking to manage and develop fractured reservoirs. Several techniques have been applied in the past to match past production and pressure history that have been proven unreliable. This paper describes a methodology to improve the simulation of fractured reservoir using seismically driven reservoir characterization. The methodology presented in this paper uses the integration of geophysical, geologic, and engineering data simultaneously to improve the reservoir description. At the root of the reservoir characterization lays the more and more accurate seismic data collected on most of the reservoirs around the world. The initial use of this seismic information is made possible through high-resolutioninversion and spectral imaging. These two processes allow a better imaging of key reservoir properties that have an important impact on fracturing. Based on this seismically driven reservoir characterization, the reservoir properties necessary as inputs to the reservoir simulator, i.e. fracture porosity and permeability, are generated using artificial intelligence tools and core measuremenst as fracture indicators. The usefulness of the derived seismic attributes is illustrated on a specific reservoir where a new well was recently drilled. The drilling results indicate that the derived seismic attributes can be used successfully to locate highly fractured areas. Using the generated seismic attributes in an integrated fracture modeling approach allows for a better modeling of the "plumbing" of the reservoir through a correct estimation of the fracture permeability and porosity. These improved fracture properties lead to a history match of the well performances. Examples of such history matches are given for illustration purposes.

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractA new approach that combines the use of static and dynamic data in fracture modeling has been developed. The approach provides the unique opportunity to constrain the fractured models to an effective permeability derived by automatically matching well performances using a streamline-based inverse approach.The effective permeability derived from well performances reflects the stress changes induced by fluid injection, and takes into account the increase of fracture conductivity along the present day maximum horizontal stress. Given the simplicity, robustness, and speed of the streamline based inversion, the estimation of effective permeability is proposed as an alternative to the tedious and often unreliable process of fracture modeling using stress measurements.Because of the availability of a true integrated fracture modeling framework, where any type of data could be used when deriving fracture models, the use of effective permeability derived by inversion is able to reduce the uncertainties by providing models with better fracture prediction capability, as illustrated on a carbonate reservoir.

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractCharacterization of naturally fractured reservoir is a recurring challenge for many oil and gas companies that manage and develop fractured reservoirs. Several techniques have been applied in the past to characterize these complex reservoirs; most of them have been proven unreliable. This paper will describe a methodology to improve the characterization of fractured reservoir using seismic attributes derived from prestack and post-stack high resolution inversion and spectral imaging. The methodology presented in this paper uses the simultaneous integration of geophysical, geologic, and engineering data to improve the reservoir description. At the root of this reservoir characterization technique is the increasingly accurate seismic data collected on most of the reservoirs world-wide. Extensive use of this seismic information is made possible through the use of pre-stack high-resolution elastic inversion, post-stack high resolution inversion, and spectral imaging. These processes allow the derivation of seismic attributes that are extremely relevant to fracturing and could also be used as input in the continuous fracture modeling approach. Based on this seismically driven reservoir characterization, the fractured reservoir properties could be accurately estimated in 3D. An application of this technology and workflow is presented on a very complex fractured reservoir.

TX 75083-3836 U.S.A., fax 01-972-952-9435. AbstractNaturally Fractured Reservoir (NFR) characterization represents an increased focus for oil and gas companies as it becomes more and more admitted that they represent a substantial part of their portfolio. However the complexity of the understanding of fractured reservoirs, in terms of fracturing mechanism, fracture density, orientation, and the complexity of their management issues (i.e. infill drilling, water production, steam injection, to list few of these issues) pushed several service and integrated companies to tackle the fractured reservoir characterization challenge. Moreover the use of integrated approaches with the help of 3D seismic and new technologies are started to show successful results. This paper will present two technologies where 3D seismic attributes along with geologic and engineering data are being used to characterize fractured reservoirs. The first technology will show how the use of post-stack seismic in an integrated approach, involving high resolution seismic inversion, spectral imaging and static geological modeling, provides an accurate fracture reservoir model that can be applied in the reservoir simulation and development stage. The second technology will highlight the use of pre-stack seismic to actually image the fracture distribution. Application of these technologies is presented on two different fields.

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