Evaluation of Imbibition Oil Recovery in the Duvernay Formation

Abstract

Summary In this study, we evaluate the wettability of shale plugs from the Duvernay Formation, which is a self-sourced reservoir in the Western Canadian Sedimentary Basin. We use reservoir oil and flowback water (brine) to conduct air/liquid contact-angle and air/liquid spontaneous-imbibition tests for wettability evaluation. We characterize the shale samples by measuring pressure-decay permeability, effective porosity, initial oil and water saturations, mineralogy, and total-organic-carbon (TOC) content, and by conducting rock-eval pyrolysis tests. We also conduct scanning-electron-microscope (SEM) and energy-dispersive X-ray spectroscopy (EDS) analyses on the shale samples to characterize the location and size of pores. After evaluation of wettability, we conduct soaking tests. First, we measure liquid/liquid contact angles for the droplets of the soaking fluids and reservoir oil equilibrated on the surface of the oil-saturated plugs. Then, we conduct soaking tests by immersing the oil-saturated plugs in different soaking fluids, and record the oil volume produced from spontaneous imbibition of the soaking fluids. The soaking fluids are characterized by measuring surface tension (ST), interfacial tension (IFT), viscosity, and pH. We analyze the results of soaking tests and investigate the controlling parameters affecting oil recovery factor (RF). The results demonstrate that the shale samples have stronger wetting affinity toward oil compared with brine. The positive correlations of TOC content with effective porosity and pressure-decay permeability suggest that the majority of connected pores are within the organic matter. The strong oil-wetness of the shale samples can be explained by the abundance of organic porosity, verified by the SEM/EDS images. The results of liquid/liquid contact-angle tests show that the soaking fluid with lower IFT exhibits a stronger wetting affinity toward the shale. The results also show that oil RF is higher for the soaking fluids with lower IFT, which may be caused by wettability alteration. In addition, comparing the results of air/brine imbibition with those of the soaking tests indicates that adding nonionic surfactant to the soaking fluid may alter the wettability of hydrophobic organic pores toward less-oil-wet conditions, leading to the displacement of oil from organic pores.

A Literature Review of CO2, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

“…332 A recent study of imbibition oil recovery from the oil-wet Duvernay shale formation provided a comparison of distilled water, produced brine, a nonionic surfactant, and clay stabilizer (Table 6, entry 16). 67,326,327 The greatest oil recovery was attained with the surfactant solution, which was attributed to surfactant solution being capable of displacing oil from hydrophilic pores and a portion of the hydrophobic pores. These researchers concluded that water cannot displace oil from hydrophobic organic pores.…”

Shale Wettability: Data Sets, Challenges, and Outlook

“…Other observations also suggest that microstructure and characteristics of organic matter pores may be related to wettability. Thus, Yassin and co-workers , and Begum et al analyzed the influence of kerogen matter-hosted pores on shale wettability for a broad range of samples (16 Upper Duvernay and 147 Lower Duvernay shale samples). A cross plot of ϕ eff (effective porosity) and k Decay (permeability) vs TOC was created which demonstrated that ϕ eff generally increased with increasing TOC, suggesting that most pores were located inside the organic matter (OM).…”

Wettability Alteration of Carbonate Rock by Chelating Agents and Viscoelastic Surfactants: Synergetic Impact

“…A small part of oil could be removed from the rock surface by buoyancy, exposing the rock surface to the water, thus slightly changing the surface wettability. The positive effect of IFT reduction on WA can be found in the studies conducted by Alvarez and Schechter, 39 Liu et al, 40 and Yassin et al 41 3.4. Wettability Alteration by Chelating Agents + VES in Synthetic Seawater.…”