A dual‐porosity model considering the displacement effect for incompressible two‐phase flow

2020 ◽  
Vol 44 (5) ◽  
pp. 691-704
Author(s):  
Huan Zheng ◽  
An‐Feng Shi ◽  
Zhi‐Feng Liu ◽  
Xiao‐Hong Wang
Keyword(s):  
Two Phase Flow ◽  
Dual Porosity ◽  
Phase Flow ◽  
Two Phase ◽  
Displacement Effect ◽  
Dual Porosity Model ◽  
Porosity Model

scholarly journals A semi-analytical two-phase flow model of fractured horizontal well with complex fracture networks in natural fractured reservoirs

2021 ◽  
pp. 014459872110417
Author(s):  
Mengmeng Li ◽  
Gang Bi ◽  
Yu Shi ◽  
Kai Zhao
Keyword(s):  
Two Phase Flow ◽  
Fractured Reservoirs ◽  
Flow Regimes ◽  
Dual Porosity ◽  
Phase Flow ◽  
Fracture Networks ◽  
Two Phase ◽  
Secondary Fracture ◽  
Complex Fracture ◽  
Main Fracture

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.

scholarly journals A Semianalytical Two-Phase Imbibition Model in Dual-Porosity and Dual-Permeability Reservoirs

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-14
Author(s):  
Mengmeng Li ◽  
Gang Bi ◽  
Jie Zhan ◽  
Liangbin Dou ◽  
Hailong Xu
Keyword(s):  
Single Phase ◽  
Two Phase Flow ◽  
Transient Behavior ◽  
Dual Porosity ◽  
Test Model ◽  
Phase Flow ◽  
Fracture System ◽  
Two Phase ◽  
Pressure Transient ◽  
Water Imbibition

The pressure transient behavior of water injection well has been extensively investigated under single-phase flow conditions. However, when water is injected into formation, there are saturation gradients within the water flooded area. Additionally, water imbibition is essentially important for oil displacement in dual-porosity and dual-permeability (DPDP) reservoirs. In this work, a novel semianalytical two-phase flow DPDP well test model considering both saturation gradient and water imbibition has been developed. The model was solved by the Laplace transform finite difference method. Type curves were generated, and flow regimes were identified by the model. The model features and effect of parameters were analyzed. Results show that water imbibition reduces the advancing speed of water drive front in the fracture system and slows down the water cut raising rate and the expansion speed of the two-phase zone in the fracture system. Therefore, the fluid exchange between the fracture and matrix systems becomes more sufficient and more oil will be recovered from the DPDP reservoir. The shape of pressure curves is similar for the single-phase and two-phase flow DPDP model, but the position of the proposed model is above the curves of the single-phase model. Shape factor mainly influences the interporosity period of the pressure derivatives. Water imbibition has a major effect on the whole system radial flow period of the curves. The findings of this study can help for better understanding of the oil/water two-phase flow pressure transient behavior in DPDP reservoirs considering saturation gradients and water imbibition.

scholarly journals A new estimation of equivalent matrix block sizes in fractured media with two-phase flow applications in dual porosity models

2017 ◽  
Vol 548 ◽  
pp. 508-523 ◽  
Author(s):  
Chahir Jerbi ◽  
André Fourno ◽  
Benoit Noetinger ◽  
Frederick Delay
Keyword(s):  
Two Phase Flow ◽  
Fractured Media ◽  
Dual Porosity ◽  
Phase Flow ◽  
Two Phase ◽  
Matrix Block ◽  
Block Sizes
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