Comparative Study of Ketone and Surfactant for Enhancement of Water Imbibition in Fractured Porous Media

Wang, Mingyuan; Baek, Kwang Hoon; Abeykoon, Gayan A.; Argüelles‐Vivas, Francisco J.; Okuno, Ryosuke

doi:10.1021/acs.energyfuels.9b03571

Cited by 16 publications

(7 citation statements)

References 31 publications

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“…5 Therefore, imbibition recovery and its rate can be enhanced when surfactants are optimally applied. 147,148 A study showed that 10 surfactant imbibition tests provided 15.7−25.4% imbibition recovery and 4 surfactant imbibition tests provided 6.8−10.2% imbibition recovery; their incremental recoveries are over brine imbibition. 145 Panels a 45 and b 118 of Figures 22 show that imbibition recovery increases when surfactants are applied, and its incremental degree is related to the types and concentrations of surfactants and the characteristics of reservoirs.…”

Section: Eor By Imbibition In Reservoir Developmentmentioning

confidence: 99%

A Critical Review of Enhanced Oil Recovery by Imbibition: Theory and Practice

Tian

Gao

et al. 2021

Energy Fuels

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Imbibition is very common, occurring in life, material, chemistry, and energy. It plays an important role in enhanced oil recovery (EOR). The development of many reservoirs is beneficial to the imbibition process, such as fractured reservoirs, conventional reservoirs developed by a water-injection mode of huff-n-puff in their later development, and unconventional reservoirs with abundant micro–nanopores developed by the fracturing technology. Here, we present a critical review of EOR through imbibition. First, the mechanisms of EOR through imbibition are reviewed, including the mechanical analysis of imbibition in a capillary, imbibition models for rocks, and the scaling law. Then, the governing factors of EOR by imbibition are summarized, including the properties of rocks and fluids and the effects of the temperature and pressure. Besides, the EOR by imbibition in the oil and gas development is discussed, including the roles of surfactants, nanofluids, salinity, shut-in time, and injection/production rates. Finally, conclusions and outlooks are presented. This review provides systematic and recent insights about EOR by imbibition and a direction for future research on this topic, which can help for a better understanding of EOR by imbibition.

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Section: Eor By Imbibition In Reservoir Developmentmentioning

confidence: 99%

A Critical Review of Enhanced Oil Recovery by Imbibition: Theory and Practice

Tian

Gao

et al. 2021

Energy Fuels

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“…in length and 1 in. in diameter and Amott cells at 338 K. The experiments largely followed the procedure described by Wang et al , The limestone cores were prepared through core-flooding experiments by first saturating the cores with crude oil and then measuring core properties, such as porosity, permeability, water saturation, and oil saturation Table summarizes the measured core properties for the core samples used in the imbibition experiment.…”

Section: Methodsmentioning

confidence: 99%

“…The partition behavior of surfactants between an aqueous surfactant solution and crude oil has been widely studied to determine the performance of surfactants during surfactant flooding chemical EOR. ,, Different surfactants have different partition coefficients depending upon their solubility in both phases (surfactants can partition into both the aqueous and oleic phases). As wettability modifiers, however, the surfactant solution lowers the water/oil IFT, while the 3-pentanone solution does not …”

Section: Introductionmentioning

confidence: 99%

Effect of Chemical Partition Behavior on Oil Recovery by Wettability Alteration in Fractured Tight Reservoirs

et al. 2022

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Various compounds have been studied as aqueous wettability modifiers that alter the matrix wettability for enhanced oil recovery from shales. This paper compares the oil recovery performance/characteristics using different wettability modifiers that have different partition behaviors into oil and water. We used two types of wettability modifiers: (1) a naturally occurring sulfaterich injection brine (IB) of 13 500 ppm salinity containing 3900 ppm of sulfate and (2) 1.0 wt % 3-pentanone in IB (3pIB). Sulfate is highly polar, while 3-pentanone is miscible with oil and only slightly soluble in IB. Contact angle experiments using oil-aged calcite surfaces confirmed that IB and 3pIB changed the wettability from 122°to 69°and 72°, respectively, within 3 days. Furthermore, spontaneous imbibition and forced imbibition experiments determined the Amott index to water of 0.68 for IB and 0.67 for 3pIB, indicating similar levels of wettability alteration. This result posed an important question as to how both modifiers would perform in oil recovery from the matrix in huff-n-puff, where the rapid transfer from the fracture to the matrix is an important step. Therefore, we tested IB and 3pIB in huff-n-puff experiments using Wolfcamp shale outcrop cores that were initially saturated with dead oil. Results showed that 3pIB started producing oil from the matrix from the first cycle and continued to produce until the fifth cycle, with a final oil recovery of 57%. IB did not show oil recovery until the second cycle, reaching a final oil recovery of 15% after 5 cycles. IB, however, showed no clear difference in brine composition between the injected and produced water. This is the first comparative study of wettability modifiers with different levels of polarity, which affect the mass transfer between the fracture and the matrix volumes in huff-n-puff.

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“…Recently, short-hydrophobe surfactants were studied by several researchers. − Wang et al tested a short-hydrophobe surfactant as a wettability modifier for oil recovery from fractured limestone cores . They found that 2-etheylhexanol-4PO-15EO (or 2-EH-4PO-15EO) altered the wettability of calcite surfaces from oil-wet (contact angle: 134.1°) to water-wet (contact angle: 47.1°) after 1 day.…”

Section: Introductionmentioning

confidence: 99%

“…7−9 Wang et al tested a short-hydrophobe surfactant as a wettability modifier for oil recovery from fractured limestone cores. 7 4PO-15EO (or 2-EH-4PO-15EO) altered the wettability of calcite surfaces from oil-wet (contact angle: 134.1°) to waterwet (contact angle: 47.1°) after 1 day. Then, they conducted dynamic imbibition tests for oil recovery from fractured limestone cores.…”

Section: Introductionmentioning

confidence: 99%

Low-Tension Polymer Flooding Using a Short-Hydrophobe Surfactant for Heavy Oil Recovery

et al. 2020

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Short-hydrophobe surfactants based on cosolvent species have been studied as novel surfactants for enhanced oil recovery. The objective of this research is to investigate such simple surfactants as a sole additive that enhances the efficiency of oil displacement by creating low-tension polymer (LTP) fronts. This paper presents the potential enhancement of oil displacement efficiency by LTP flooding based on comprehensive experimental data, such as interfacial tensions (IFTs), surfactant partition coefficients, surfactant adsorption in a sandpack, polymer/LTP rheology, and sandpack flooding results. The optimal LTP identified was composed of 0.5 wt % 2-ethylhexanol-7PO-15EO in partially hydrolyzed polyacrylamide polymer solution, which reduced the IFT with heavy oil from 15.8 to 0.025 dyn/cm, without creating microemulsions. The surfactant adsorption in the sandpack was only 0.055 mg-surfactant/g-sand. Sandpack flooding results show that the LTP flooding achieved an incremental oil recovery in comparison to straight-polymer flooding. The oil recovery at 1 pore-volume injected (PVI) was 47% original-oil-in-place (OOIP) for the polymer flooding, 63% for the smaller LTP slugs (0.5 wt % surfactant for 0.1 PVI and 0.1 wt % surfactant for 0.5 PVI), and 70% for the larger LTP slug (0.5 wt % surfactant for 0.5 PVI). Fractional flow theory was applied to confirm that the IFT reduction by 3 orders of magnitude was conducive to a lowered residual oil saturation in LTP flooding, leading to a delayed polymer breakthrough and an increased oil cut thereafter in comparison to polymer flooding.

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Comparative Study of Ketone and Surfactant for Enhancement of Water Imbibition in Fractured Porous Media

Cited by 16 publications

References 31 publications

A Critical Review of Enhanced Oil Recovery by Imbibition: Theory and Practice

A Critical Review of Enhanced Oil Recovery by Imbibition: Theory and Practice

Effect of Chemical Partition Behavior on Oil Recovery by Wettability Alteration in Fractured Tight Reservoirs

Low-Tension Polymer Flooding Using a Short-Hydrophobe Surfactant for Heavy Oil Recovery

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