A Two-Phase Flow Model for Fractured Horizontal Well with Complex Fracture Networks: Transient Analysis in Flowback Period

2017 ◽  
Author(s):  
Zhiming Chen ◽  
Wei Yu ◽  
Xinwei Liao ◽  
Xiaoliang Zhao ◽  
Youguang Chen ◽  
...  
Keyword(s):  
Transient Analysis ◽  
Horizontal Well ◽  
Flow Model ◽  
Two Phase Flow ◽  
Phase Flow ◽  
Fracture Networks ◽  
Two Phase ◽  
Complex Fracture ◽  
Fractured Horizontal Well

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 Temperature Prediction Model for Two-Phase Flow Multistage Fractured Horizontal Well in Tight Oil Reservoir

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-8
Author(s):  
Ruidou Zhang ◽  
Yonggang Duan ◽  
Mingqiang Wei
Keyword(s):  
Horizontal Well ◽  
Two Phase Flow ◽  
Tight Oil ◽  
Oil Reservoir ◽  
Phase Flow ◽  
Thomson Effect ◽  
Temperature Prediction ◽  
Two Phase ◽  
Fractured Horizontal Well ◽  
Tight Oil Reservoir

Distributed temperature sensing (DTS) has been used for fracture parameter diagnosis and flow profile monitoring. In this paper, we present a new model for predicting the temperature profile of two-phase flow multistage fractured horizontal wells in the tight oil reservoirs. The homogeneous reservoir flow/heat transfer model is extended to the tight oil reservoir-fracture-wellbore coupled flow/thermal model. The influence of SRV area on reservoir and wellbore is considered, and the Joule-Thomson effect, heat convection, heat conduction, and other parameters are introduced into the improved model. The temperature distributions of reservoir and wellbore with different production times, water cut, and locations of water entry are simulated. The simulated results indicate that the Joule-Thomson effect will cause wellbore temperature to rise; the temperature of fractures with more water production is significantly lower than that of other fractures, and the water outlet location can be judged according to the temperature change of the wellbore. By using the improved temperature prediction model, the DTS monitoring data of two-phase flow multistage fractured horizontal well in the tight reservoir has been calculated and analyzed, and the accurate production profile has been obtained.

scholarly journals Production Decline Analysis for Two-Phase Flow in Multifractured Horizontal Well in Shale Gas Reservoirs

2015 ◽  
Vol 2015 ◽  
pp. 1-10 ◽  
Author(s):  
Wei-Yang Xie ◽  
Xiao-Ping Li ◽  
Lie-Hui Zhang ◽  
Xiao-Hua Tan ◽  
Jun-Chao Wang ◽  
...  
Keyword(s):  
Shale Gas ◽  
Horizontal Well ◽  
Flow Model ◽  
Transient Flow ◽  
Two Phase Flow ◽  
Hydraulic Fractures ◽  
Phase Flow ◽  
Gas Reservoirs ◽  
Two Phase ◽  
Shale Gas Reservoirs

After multistage fracturing, the flowback of fracturing fluid will cause two-phase flow through hydraulic fractures in shale gas reservoirs. With the consideration of two-phase flow and desorbed gas transient diffusion in shale gas reservoirs, a two-phase transient flow model of multistage fractured horizontal well in shale gas reservoirs was created. Accurate solution to this flow model is obtained by the use of source function theory, Laplace transform, three-dimensional eigenvalue method, and orthogonal transformation. According to the model’s solution, the bilogarithmic type curves of the two-phase model are illustrated, and the production decline performance under the effects of hydraulic fractures and shale gas reservoir properties are discussed. The result obtained in this paper has important significance to understand pressure response characteristics and production decline law of two-phase flow in shale gas reservoirs. Moreover, it provides the theoretical basis for exploiting this reservoir efficiently.

A Semianalytical Method for Modeling Two-Phase Flow in Coalbed-Methane Reservoirs With Complex Fracture Networks

2018 ◽  
Vol 21 (03) ◽  
pp. 719-732 ◽  
Author(s):  
Ruiyue Yang ◽  
Zhongwei Huang ◽  
Wei Yu ◽  
Hamid Lashgari ◽  
Kamy Sepehrnoori
Keyword(s):  
Coalbed Methane ◽  
Two Phase Flow ◽  
Phase Flow ◽  
Fracture Networks ◽  
Two Phase ◽  
Complex Fracture ◽  
Semianalytical Method
Sign in / Sign up

Export Citation Format

Share Document