Modeling of Wettability Alteration Due to Asphaltene Deposition in Oil Reservoirs

Abstract

Wettability is a key property, which controls multiphase fluid flow in oil recovery processes. It is well known that the asphaltene deposition on rock surface changes the wettability of the rock. Although many experiments in the literature have been conducted to understand the physics underlying wettability alteration in crude oil/brine/rock (COBR) system because of asphaltene deposition; a sophisticated mathematical model describing this phenomenon is absent. In this paper, based on available experimental data in the literature and known physical mechanisms of asphaltene deposition on the rock in the COBR system, a model for wettability alteration due to asphaltene instability in crude oil is presented. Contact angle is introduced as a function of asphaltene stability index (ASI), which is determined thermodynamically based on the difference between the fugacity of asphaltene and the heaviest component in the oil. The shape of this function depends on pH, salinity and cation valency of brine, and asphaltene content of crude oil. We implemented our proposed model along with asphaltene precipitation, flocculation, and deposition models into an in-house compositional simulator, UTCOMP, developed at The University of Texas at Austin. Permeability and porosity reduction due to asphaltene deposition are also considered. Furthermore, relative permeabilities and capillary pressure are modified because of contact angle alteration during simulation. Although the amount of asphaltene deposition in the reservoir may not be comparable to the wellbore, a significant change in wettability occurs after the deposition of first layer of asphaltene on the rock surface. The result of our simulation shows that wettability alteration affects oil recovery, specifically when the brine produces unstable water film on the rock surface. In this case, rock wettability can change from 30° (water-wet) to 150° (oil-wet) and yield change in recovery depending on absolute permeability reduction magnitude and change in trapped oil saturation as well as end-point relative permeability.

A Critical Assessment of Several Reservoir Simulators for Modeling Chemical Enhanced Oil Recovery Processes

“…These methods are referred to as Enhanced Oil Recovery processes (Lake, 1989;Green and Willhite, 1998). In recent years chemical processes are considered as valuable EOR methods for mature depleted light oil conventional reservoirs, nonthermal recovery of viscous oils and fractured carbonate reservoirs using chemicals for wettability alteration (Delshad et al, 2006;Darabi et al , 2012).…”

Fully implicit compositional simulator for modeling of asphaltene deposition during natural depletion

“…This figure presents the buildup of deposited asphaltene in the well block. As can be seen, the asphaltene deposited per unit bulk volume of the reservoir gradually increases in gridblock(11,1,1). This figure shows that rate of deposited asphaltene reaches a maximum value at the 35 days of simulation and then it decreases towards a value of less than 0.0002 (Mass per Bulk volume per time lb/ft3/day).…”

“…Even though none of these models satisfactorily match the experimental data, some are simple and fast and have been implemented in reservoir simulators [11,12]. The solid models have been widely used in the reservoir simulators due to the flexibility and simple application [13] .…”

Modeling and Simulation of Near-Wellbore Asphaltene Remediation Using Asphaltene Dispersants

“…We consider asphaltene precipitation, flocculation, and deposition as well as permeability and porosity relation, wettability alteration, and oil viscosity reduction due to asphaltene deposition. More details of the formulation of the simulator are presented in Darabi et al (2012), Darabi et al (2014), and Darabi (2014). In this simulator, we assume that deposited asphaltene changes the pore volume at each time step.…”