Fracture Network Characterization via Zoning Simplification
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Solution Overview
Problem
The complexity of fracture networks in hydrocarbon reservoirs makes it challenging to simulate fluid flows and calibrate fracture conductivities, leading to prohibitive computational costs and time in reservoir development optimization.
Innovation Solution
A method that simplifies fracture networks around well drainage areas using statistical parameters to deduce equivalent permeability tensors and average openings, constructing a double-medium flow model by dividing the reservoir into zones with varying levels of simplification, and calibrating fracture conductivities through well test simulations.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If detailed fracture networks are modeled to accurately represent reservoir complexity, then measurement precision and reliability improve, but computational time and device complexity increase prohibitively
Solution Approach 1:
The reservoir is divided into multiple zones based on fracture density and complexity characteristics. High-resolution discrete fracture network modeling is applied only to zones with significant fracture complexity, while simpler zones use averaged or simplified representations. This segmentation allows accurate characterization where needed while reducing overall computational burden.
Solution Approach 2:
Different modeling approaches and levels of detail are applied to different spatial zones within the reservoir. Zones with high fracture density and complexity receive detailed discrete fracture network modeling, while zones with simpler fracture patterns use coarser representations. This local quality approach ensures measurement precision is optimized where it matters most without uniformly increasing computational complexity throughout the entire reservoir.
2Measurement precision
If detailed fracture networks are modeled to accurately represent reservoir complexity, then measurement precision improves, but device complexity increases prohibitively
Solution Approach 1:
The reservoir domain is segmented into multiple zones with distinct fracture characteristics. Each zone is modeled with appropriate complexity level - detailed discrete fracture networks in complex zones, simplified representations in simpler zones. This segmentation reduces overall device complexity while maintaining measurement precision where required.
Solution Approach 2:
The modeling system applies different levels of detail and complexity to different spatial locations based on local fracture characteristics. This local quality approach ensures that device complexity is optimized by avoiding unnecessary detailed modeling in zones where simplified representations suffice, while maintaining high measurement precision in zones where fracture complexity demands it.
3Measurement precision
If comprehensive fracture network data is collected to improve reservoir understanding, then measurement precision improves, but loss of information increases due to data processing complexity
Solution Approach 1:
Fracture network data is processed and modeled separately for different zones based on their characteristics. This segmentation allows targeted analysis of fracture data in each zone, reducing the complexity of processing comprehensive datasets while maintaining measurement precision through zone-specific modeling approaches.
Solution Approach 2:
Data processing and modeling are tailored to local fracture characteristics in each zone. This local quality approach ensures that comprehensive fracture network data is processed efficiently by applying appropriate levels of detail and complexity matching each zone's actual fracture patterns, thereby reducing overall data processing complexity while maintaining reservoir knowledge accuracy.
Data Source
AI summary
The invention is a method for constructing a representation of a fluid reservoir traversed by a fracture network and by at least one well. The reservoir is discretized into a set of grid cells and the fractures are characterized by statistical parameters from observations of the reservoir. An equivalent permeability tensor and an average fracture opening is constructed from an image representative of the fracture network delimiting porous blocks and fractures is then deduced from the statistical parameters. A first elliptical boundary zone centered on the well and at least a second elliptical boundary zone centered on the well which form an elliptical ring with the elliptical boundary of the first zone are defined around the well. The image representative of the fracture network is simplified in a different manner for each of the zones which is used to construct the representation of the fluid reservoir.