Surface Reactivity Analysis of the Crude Oil–Brine–Limestone Interface for a Comprehensive Understanding of the Low-Salinity Waterflooding Mechanism

Tetteh, Joel T.; Veisi, Masoumeh; Brady, Patrick V.; Barati Ghahfarokhi, Reza

doi:10.1021/acs.energyfuels.9b03664

Surface Reactivity Analysis of the Crude Oil–Brine–Limestone Interface for a Comprehensive Understanding of the Low-Salinity Waterflooding Mechanism

Journal Article · Sun Feb 09 00:00:00 EST 2020 · Energy and Fuels

DOI:https://doi.org/10.1021/acs.energyfuels.9b03664· OSTI ID:1617303

Tetteh, Joel T. ^[1]; Veisi, Masoumeh ^[2]; Brady, Patrick V. ^[3]; ^[1]

Univ. of Kansas, Lawrence, KS (United States)
Univ. of Kansas, Lawrence, KS (United States); Kansas Geological Survey, Lawrence, KS (United States)
Sandia National Lab. (SNL-NM), Albuquerque, NM (United States)

Low-salinity waterflooding (LSWF) has proven to improve oil recovery in carbonate formations through rock wettability alteration, although the underlying mechanism remains elusive. Multivalent ionic exchange and calcite dissolution have usually been investigated using geochemical analysis in secondary coreflooding. In this work, coreflooding, in tertiary mode, coupled with a surface reactivity analysis approach was employed to investigate the interplay of wettability alteration mechanisms such as mineral dissolution, electrostatic bond attraction, and the effect of pH at in situ conditions. Improved oil recovery (IOR) in tertiary mode observed by coreflooding in Indiana limestone rocks showed an ionic strength dependence, that is, reducing brine ionic strength resulted in an increase in oil recovery. Coreflooding results showed that the seawater and low-salinity brines deprived of Mg²⁺ ions resulted in the lowest IOR in tertiary mode, indicating the significance of Mg²⁺ on IOR in limestone rocks. Similar results were observed through the contact angle measurement showing the limestone rock wettability state dependence on ionic strength and the effect of Mg2+ ions. Surface reactivity analysis showed an increase in solution pH, Ca²⁺ and Mg²⁺ ions concentration in the effluent solution from the coreflooding in tertiary mode using low salinity brines (about 40 and 20% increase in the effluent composition for Ca²⁺ and Mg²⁺, respectively). These changes in solution composition were used to calculate the in situ oil–brine and rock–brine zeta potential using a validated surface complexation model, showing the changes of zeta potential as brine is injected into limestone rocks. The results show that using seawater-like brine in tertiary mode resulted in no mineral dissolution or ionic exchange. However, improved oil recovery (IOR) using such seawater-like brine was due to wettability alteration caused by reduced electrostatic bond attraction associated with Mg²⁺ ions [from 2.6 × 10^–13 (mol/m²)² for formation water salinity to 1.5 × 10^–13 (mol/m²)² for seawater salinity]. Using low-salinity brines in tertiary mode improved oil recovery by mineral dissolution, resulting in oil desorption and an increase in solution pH. Finally, the increase in solution pH also resulted in reduced electrostatic bond attraction which lead to rock wettability alteration using low-salinity brines.

View Accepted Manuscript (DOE)

Research Organization:: Sandia National Laboratories (SNL-NM), Albuquerque, NM (United States)

Sponsoring Organization:: USDOE National Nuclear Security Administration (NNSA)

Grant/Contract Number:: AC04-94AL85000; NA0003525

OSTI ID:: 1617303

Report Number(s):: SAND--2019-15123J; 682177

Journal Information:: Energy and Fuels, Journal Name: Energy and Fuels Journal Issue: 3 Vol. 34; ISSN 0887-0624

Publisher:: American Chemical Society (ACS)Copyright Statement

Country of Publication:: United States

Language:: English

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