Transient Shape Factors for Thermal Flow Simulation in Naturally Fractured Reservoirs: A Concept

2014 ◽  
Author(s):  
Loran Taabbodi ◽  
Zhangxin John Chen ◽  
Sebastian Geiger
Keyword(s):  
Fractured Reservoirs ◽  
Flow Simulation ◽  
Naturally Fractured Reservoirs ◽  
Thermal Flow ◽  
Shape Factors ◽  
Naturally Fractured

scholarly journals Predictive Modelling of Naturally Fractured Reservoirs Using Geomechanics and Flow Simulation

GeoArabia ◽  
2001 ◽  
Vol 6 (1) ◽  
pp. 27-42
Author(s):  
Stephen J. Bourne ◽  
Lex Rijkels ◽  
Ben J. Stephenson ◽  
Emanuel J.M. Willemse
Keyword(s):  
Fractured Reservoirs ◽  
Flow Simulation ◽  
Naturally Fractured Reservoirs ◽  
Natural Fracture ◽  
Production Data ◽  
Well Test ◽  
Fracture Networks ◽  
Field Scale ◽  
Fracture Permeability ◽  
Naturally Fractured

ABSTRACT To optimise recovery in naturally fractured reservoirs, the field-scale distribution of fracture properties must be understood and quantified. We present a method to systematically predict the spatial distribution of natural fractures related to faulting and their effect on flow simulations. This approach yields field-scale models for the geometry and permeability of connected fracture networks. These are calibrated by geological, well test and field production data to constrain the distributions of fractures within the inter-well space. First, we calculate the stress distribution at the time of fracturing using the present-day structural reservoir geometry. This calculation is based on a geomechanical model of rock deformation that represents faults as frictionless surfaces within an isotropic homogeneous linear elastic medium. Second, the calculated stress field is used to govern the simulated growth of fracture networks. Finally, the fractures are upscaled dynamically by simulating flow through the discrete fracture network per grid block, enabling field-scale multi-phase reservoir simulation. Uncertainties associated with these predictions are considerably reduced as the model is constrained and validated by seismic, borehole, well test and production data. This approach is able to predict physically and geologically realistic fracture networks. Its successful application to outcrops and reservoirs demonstrates that there is a high degree of predictability in the properties of natural fracture networks. In cases of limited data, field-wide heterogeneity in fracture permeability can be modelled without the need for field-wide well coverage.

Predictive modelling of naturally fractured reservoirs using geomechanics and flow simulation

2000 ◽  
Author(s):  
Stephen J. Bourne ◽  
Franz Brauckmann ◽  
Lex Rijkels ◽  
Ben J. Stephenson ◽  
Alex Weber ◽  
...  
Keyword(s):  
Fractured Reservoirs ◽  
Flow Simulation ◽  
Predictive Modelling ◽  
Naturally Fractured Reservoirs ◽  
Naturally Fractured

Characterization of Matrix Wettability and Mass Transfer From Matrix to Fractures in Carbonate Reservoirs

2012 ◽  
Author(s):  
Anuj Gupta
Keyword(s):  
Oil Recovery ◽  
History Matching ◽  
Oil And Gas ◽  
Fractured Reservoirs ◽  
Naturally Fractured Reservoirs ◽  
Carbonate Reservoirs ◽  
Shape Factors ◽  
Naturally Fractured ◽  
Fractured Carbonate ◽  
The Matrix

This paper presents results of an experimental investigation, supported by numerical analysis, to characterize oil recovery from fractured carbonate reservoirs. Imbibition recovery of oil is measured as a function of time for samples with varying wettability and shape factors. One of the objectives of this study is to verify the validity of exponential transfer function for matrix-fracture systems with varying wettability and flow-boundary conditions. Another objective is to establish the possibility of quantitatively determining the wettability of a sample based on history-matching of cumulative imbibition recovery and recovery rate data. The productivity of most carbonate oil and gas reservoirs is closely tied to the natural or stimulated fracture system present in the reservoir. Further, the recovery from naturally fractured reservoirs, in presence of aquifer drive or waterflooding is closely tied to the wettability of the matrix. The approach presented in this paper offers means to evaluate how recovery factor in a fractured system can be affected by wettability. A detailed understanding of rock-fluid interactions and wettability alterations at the fracturing face should help design improved strategies for exploiting naturally fractured carbonate reservoirs.

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