Numerical Fluid Flow Modelling in Multiple Fractured Porous Reservoirs

The numerical simulation of polymer flooding is a complex task as this process involves complex physical and chemical reactions, and multiple sets of characteristic parameters are required to properly set the simulation. At present, such characteristic parameters are mainly obtained by empirical methods, which typically result in relatively large errors. By analyzing experimentally polymer adsorption, permeability decline, inaccessible pore volume, viscosity-concentration relationship, and rheology, in this study, a conversion equation is provided to convert the experimental data into the parameters needed for the numerical simulation. Some examples are provided to demonstrate the reliability of the proposed approach.

“…When macromolecular polymers flow through porous media, only water or salt may pass through a small part of pores; this part of pore volume is called the inaccessible pore volume [10].…”

Section: Inaccessible Pore Volumementioning

confidence: 99%

Experimental Study and Numerical Simulation of Polymer Flooding

Bai¹,

Li²,

Zhou³

et al. 2022

“…Compared with other data, production dynamic data are not limited by the development conditions or construction period, and are the easiest to obtain. Based on the data screening and analysis method used, the method of using production dynamic data to identify channeling channels can be further categorized into the gray correlation method [7,8], fuzzy comprehensive evaluation method [9][10][11], cluster analysis method [12][13][14], characteristic curve method [15][16][17], and dynamic comprehensive analysis method [18][19][20].…”

Section: Introductionmentioning

confidence: 99%

Analysis of Channeling-Path Phenomena in a Complex Fault-Block Reservoir with Low Recovery Factor and High Water-Cut Ratio

qunyi¹,

Ma²,

Bi³

et al. 2023

Current methods for the analysis of channeling-path phenomena in reservoirs cannot account for the influence of time and space on the actual seepage behavior. In the present study, this problem is addressed considering actual production data and dynamic characteristic parameters quantitatively determined in the near wellbore area by fitting the water-cut curve of the well. Starting from the dynamic relationship between injection and production data, the average permeability is determined and used to obtain a real-time quantitative characterization of the seepage behavior of the channeling-path in the far wellbore area. For the considered case study (Jidong oilfield), it is found that the seepage capacity of the channeling-path in the far wellbore area is far less (10 times smaller) than that of the channeling-path in the near wellbore area. The present study and the proposed model (combining near wellbore area and far wellbore area real-time data) have been implemented to support the definition of relevant adjustment measures to ultimately improve oil recovery.

“…As mentioned above, analytical and numerical models are the two most widely used models for fractured horizontal well capacity prediction [14,15]. In addition, semi-analytical models are also used for capacity prediction [16]. Analytical models require more assumptions.…”

Section: Introductionmentioning

confidence: 99%

Simulation of Gas-Water Two-Phase Flow in Tight Gas Reservoirs Considering the Gas Slip Effect

Lu¹,

Wang²,

Li³

et al. 2023

A mathematical model for the gas-water two-phase flow in tight gas reservoirs is elaborated. The model can account for the gas slip effect, stress sensitivity, and high-speed non-Darcy factors. The related equations are solved in the framework of a finite element method. The results are validated against those obtained by using the commercial software CMG (Computer Modeling Group software for advanced recovery process simulation). It is shown that the proposed method is reliable. It can capture the fracture rejection characteristics of tight gas reservoirs better than the CMG. A sensitivity analysis of various control factors (initial water saturation, reservoir parameters, and fracturing parameters) affecting the production in tight gas wells is conducted accordingly. Finally, a series of theoretical arguments are provided for a rational and effective development/exploitation of tight sandstone gas reservoirs.