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

Abstract

Model developments for transient analysis of fractured horizontal wells have gained tremendous attention in tight reservoirs, especially, during the flowback period. However, the existing models so far have rarely considered two-phase flow and complex fracture networks. To improve this situation, in this work, we present a new semianalytical two-phase flow model. Water and oil simultaneously flow in the matrix and fracture networks. By iteratively correcting the relative permeability to water and gas phases, we incorporate the two-phase flow into fracture model. Complex fracture networks with arbitrary geometries are described and the fluid flow interplays at fracture intersections are eliminated through mass balance equation. The model solution is obtained by using Laplace transform inversion, and it is verified by performing a case study with a numerical simulator. Our results show that there exist two distinct flow regimes: fluid feed and pseudo-boundary dominated flow (PBDF), which is generated by the permeability contrast between fracture networks and matrix. We also investigate the impacts of some key reservoir and fracture properties on the characteristics of productivity index. Results indicate that the productivity index increases with an increase in initial water saturation. Furthermore, it is found that during the PBDF, different fracture-network parameters have various constant productivity indexes, providing an efficient tool to characterize the fracture networks. Based on that, we apply the model to estimate the fracture networks of a tight-oil well in CJ formation at Tarim Bain with flowback data and micro seismic data, which provides an efficient technique to estimate the stimulation effectiveness during the flowback period.

A Two-Phase Numerical Model of Well Test Analysis to Characterize Formation Damage in Near-Well Regions of Injection Wells

“…However, formation damage is quite common in near-well regions of injection wells in offshore oilfields due to interaction between injection water and clay minerals [1][2][3][4][5][6][7][8][9][10][11][12]. To characterize the formation damage and estimate reservoir properties, transient pressure data observed from the testing wells are usually interpreted by traditional pressure transient analysis models [13][14][15][16][17][18][19][20][21][22], which are simplified single-phase models divided into two or three regions according to the properties of formation and fluids.…”

A Two-Phase Flow Model for Pressure Transient Analysis of Water Injection Well considering Water Imbibition in Natural Fractured Reservoirs

“…The two or three zones for a composite reservoir were divided according to the formation and fluid properties. Some scholars [9][10][11][12][13] developed a two-or threezone composite reservoir well test model by finite-difference or Laplace transformation method to get the pressure curves for water injection and pressure falloff period. However, these models assumed no saturation gradients within oil and water transition zone and the zone boundaries were virtually stationary before the well shut-in.…”