Parallel Simulation of Multiphase Flow in Fractured Reservoirs
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Solution Overview
Problem
Current dual-porosity and dual-permeability models for simulating fluid flow in naturally fractured reservoirs face challenges due to extreme contrasts in porosity and permeability, and are limited by structured grids and data partitions, which are not optimal for complex, multi-modal pore systems and multi-scale fracture networks.
Innovation Solution
A scalable parallel simulation system that partitions the reservoir into multiple interacting continua, allowing for collocated and multi-interacting continua to exchange fluids, with a global cell domain partitioned into parallel data subdomains and solved using a fully-coupled set of constraint equations, enabling efficient simulation of multiphase flow in complex, heterogeneous reservoirs.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If dual-porosity and dual-permeability models are used to represent fractured media, then the representation of complex heterogeneous reservoirs is improved, but the numerical solution becomes extremely challenging due to extreme contrasts in porosity and permeability
Solution Approach 1:
The reservoir is segmented into multiple continua (matrix continuum and fracture continuum) with distinct porosity and permeability characteristics. Each continuum is solved separately but coupled through interchange terms, allowing the extreme contrasts in properties to be handled in a numerically stable manner while maintaining accurate representation of the heterogeneous system.
Solution Approach 2:
Interchange terms act as intermediaries between the matrix and fracture continua, facilitating fluid transfer while balancing the extreme property contrasts. These terms mediate the interaction between continua with vastly different porosity and permeability values, enabling numerical solution without direct coupling of extreme values.
2Ease of manufacture
If structured grids and structured domain partitioning schemes are used, then the implementation is simplified, but the simulation is not optimal for complex multi-modal pore systems and multi-scale fracture networks
Solution Approach 1:
The domain partitioning is made dynamic and adaptive rather than fixed and structured. The partitioning scheme automatically adapts to the complex multi-modal pore systems and multi-scale fracture networks, optimizing the simulation for each specific reservoir configuration while maintaining implementation feasibility through systematic algorithms.
Solution Approach 2:
Different partitioning strategies are applied locally to different regions of the reservoir based on their specific characteristics. Complex regions with multi-scale fracture networks receive specialized partitioning treatment, while simpler regions use standard approaches, allowing the system to maintain adaptability to local heterogeneities while preserving overall implementation simplicity.
Data Source
AI summary
A subterranean reservoir where the pore space of media or formation rock is multimodal, and the media may have imbedded multiple scales of fracture networks, is simulated. The modes of the pore system and the scale of fracture networks are each represented as a separate, but interactive continuum with the other. A matrix solution with arrangement of the reservoir data adapted for parallel computation is utilized. The simulation allows multiple continua to be co-located and multi-interacting, in that each continuum may have current and counter-current multiple multiphase exchanges with other continua.