Multiphase flow simulation of fractured karst oil reservoirs applying three-dimensional network models

• Published in: Physics of fluids (1994) 2024-07, Vol.36 (7)
• Main Authors: Zheng, Songqing, Wang, Xiukun, Chen, Jin, Gu, Hao, Wu, Wensheng
• Format: Article
• Language: English
• Subjects: Finite volume method; Flow simulation; Fluid flow; Fractures; Image processing; Karst; Multiphase flow; Numerical models; Reservoirs; Seismic surveys; Simulation models
• ISSN: 1070-6631; 1089-7666
• DOI: 10.1063/5.0204625

The characteristics of karst reservoirs are extremely varied and anisotropic, exhibiting notable differences in porosity, permeability, and corresponding fluid flow pathways. Fractured karst petroleum reservoirs, such as distinct caverns and fractures, are an example of a typical discrete media type. The traditional reservoir modeling approach and discrete fracture-like local refinement models are unsuitable for field application of fractured karst oil reservoirs due to the needs of high fidelity geological description and huge computing efforts. Based directly on the spatial characteristics of seismic surveys, a numerical simulation model in three dimensions, akin to a node-like network, is presented here for cracked karst oil reserves. First, the watershed image processing technique and the automatic connection identification procedure are used to extract the three-dimensional node-network model. After that, automatic differentiation is used to build the numerical finite volume scheme, and the proper gradient-based adjoint approach is used to conduct the related historical matching rapidly. After validation by a synthetic model in a commercial simulator, this proposed three-dimensional network numerical model is used for a field reservoir block of deep formation in the Tarim basin to demonstrate its computational efficiency and viability for enormously comparable karst oil reservoirs.