TY - THES

T1 - Understanding Wettability Changes during Alkali-Polymer through Spontaneous Imbibition Data

AU - Arekhov, Vladislav

N1 - no embargo

PY - 2019

Y1 - 2019

N2 - It is well known that the wetting state of the rock’s internal mineral surfaces affects storage and flow characteristics of the reservoir. Moreover, it has been previously shown that injection of chemicals into the formation leads to alteration of the wettability. The oil characteristic such as the TAN (total acid number) also determines the wetting state of the reservoir. The aim of this study is to examine the effect of alkaline, polymer and alkali-polymer solutions on wettability by means of spontaneous imbibition tests. The data obtained from Amott imbibition tests were analyzed using numerical simulation of the capillary suction process and analytical solution of an equation similar to Fick’s law of diffusion. A detailed comparison is made between rock samples with various mineralogy, oils with different TAN numbers and brines with various composition. The experiments were done on cleaned water-wet core plugs as well as on samples with restored oil-wet state. The results illustrate a large influence of chemicals not only on ultimate oil production, but also on the rate of production over time. The investigation has revealed that the application of chemicals influences capillary forces in the core plug, which can be directly correlated to wettability alteration. The framework presented in the project can be used to evaluate relative wettability change with the application of different EOR agents.

AB - It is well known that the wetting state of the rock’s internal mineral surfaces affects storage and flow characteristics of the reservoir. Moreover, it has been previously shown that injection of chemicals into the formation leads to alteration of the wettability. The oil characteristic such as the TAN (total acid number) also determines the wetting state of the reservoir. The aim of this study is to examine the effect of alkaline, polymer and alkali-polymer solutions on wettability by means of spontaneous imbibition tests. The data obtained from Amott imbibition tests were analyzed using numerical simulation of the capillary suction process and analytical solution of an equation similar to Fick’s law of diffusion. A detailed comparison is made between rock samples with various mineralogy, oils with different TAN numbers and brines with various composition. The experiments were done on cleaned water-wet core plugs as well as on samples with restored oil-wet state. The results illustrate a large influence of chemicals not only on ultimate oil production, but also on the rate of production over time. The investigation has revealed that the application of chemicals influences capillary forces in the core plug, which can be directly correlated to wettability alteration. The framework presented in the project can be used to evaluate relative wettability change with the application of different EOR agents.

KW - Wettability

KW - Spontaneous Imbibition

KW - Enhanced Oil Recovery

KW - Capillary Pressure

KW - Capillary Suction

KW - Total Acid Number

KW - Interfacial Tension

KW - Alkali-Polymer Injection

KW - Oil Displacement

KW - Amott Test

KW - Capillary Diffusion

KW - Numerical Simulation

KW - Wettability Alteration

KW - In-situ Acid Formation

KW - Wettability

KW - Spontaneous Imbibition

KW - Enhanced Oil Recovery

KW - Capillary Pressure

KW - Capillary Suction

KW - Total Acid Number

KW - Interfacial Tension

KW - Alkali-Polymer Injection

KW - Oil Displacement

KW - Amott Test

KW - Capillary Diffusion

KW - Numerical Simulation

KW - Wettability Alteration

KW - In-situ Acid Formation

M3 - Master's Thesis

ER -