A semi-analytical two-phase flow model of fractured horizontal well with complex fracture networks in natural fractured reservoirs. Issue 1 (January 2022)

• Record Type: Journal Article
• Authors: Li, Mengmeng; Bi, Gang; Shi, Yu; Zhao, Kai
• Is Part Of: Energy exploration & exploitation. Volume 40:Issue 1(2022)
• Page Start: 174
• Page End: 192
• Publication Date: 2022-01
• Subjects: Semi-analytical model -- complex fracture network system -- dual-porosity system -- oil/water two-phase flow -- pressure transient analysis; Power resources -- Periodicals; 333.79
• DOI: 10.1177/01445987211041782
• Languages: English
• ISSNs: 0144-5987

Abstract

Complex fracture networks are easily developed along the horizontal wellbore during hydraulic fracturing. The water phase increases the seepage resistance of oil in natural fractured reservoir. The flow regimes become more intricate due to the complex fractures and the occurrence of two-phase flow. Therefore, a semi-analytical two-phase flow model is developed based on the assumption of orthogonal fracture networks to describe the complicate flow regimes. The natural micro-fractures are treated as a dual-porosity system and the hydraulic fracture with complex fracture networks are characterized explicitly by discretizing the fracture networks into multiple fracture segments. The model is solved according to Laplace transformation and Duhamel superposition principle. Results show that seven possible flow regimes are described according to the typical curves. The major difference between the vertical fractures and the fracture networks along the horizontal wellbore is the fluid "feed flow" behavior from the secondary fracture to the main fracture. A natural fracture pseudo-radial flow stage is added in the proposed model comparing with the conventional dual-porosity model. The water content has a major effect on the fluid total mobility and flow capacity in dual-porosity system and complex fracture networks. With the increase of the main fracture number, the interference of the fractures increases and the linear flow characteristics in the fracture become more obvious. The secondary fracture number has major influence on the fluid feed capacity from the secondary fracture to the main fracture. The elastic storativity ratio mainly influences the fracture flow period and inter-porosity flow period in the dual-porosity system. The inter-porosity flow coefficient corresponds to the inter-porosity flow period of the pressure curves. This work is significantly important for the hydraulic fracture characterization and performance prediction of the fractured horizontal well with complex fracture networks in natural fractured reservoirs.