Effects of oligomers dissolved in CO2 or associated gas on IFT and miscibility pressure with a gas-light crude oil system

Hinai, Nasser Mohammed Al; Myers, Matthew; Dehghani, Seyed Ali Mousavi; Wood, Colin D.; Valdéz, Raúl; Jin, Fang; Xie, Quan; Saeedi, Ali

doi:10.1016/j.petrol.2019.106210

Cited by 19 publications

(9 citation statements)

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“…The IFT trend with increasing pressure can be explained by two main factors. First, increasing pressure increases the intermolecular forces of the gas molecules, which results in increasing its density and thus promotes miscibility. − Second, increasing pressure likely improves the extraction of crude oil components into the gas phase and the condensation of enriched gas into crude oil. ,,− These processes of extraction (vaporization) and condensation between gas and oil phases are developed through several stages (multi-contact miscibility). For example, the light and intermediate crude oil components are extracted first into the gas phase (the first IFT trend); then with further increasing pressure (the second region), the heavier oil components start to be extracted into the gas phase at a slower rate. ,, …”

Section: Results and Discussionmentioning

confidence: 99%

“…These processes are typically divided into condensing gas drive and vaporizing gas drive, , where the gas phase is enriched through the extraction (vaporization) of light and intermediate crude oil components and then the enriched gas is dissolved (condensed) into the oil phase. Consequently, a miscibility (transition) zone is formed between the gas and oil phases. , …”

Section: Introductionmentioning

confidence: 99%

“…Consequently, a miscibility (transition) zone is formed between the gas and oil phases. 20,21 However, the minimum miscibility pressure for some reservoirs is far higher than the formation fracture pressure, which limits the application of miscible gas injection, and this inability to achieve miscibility results in unfavorable sweep efficiency. This problem typically occurs in high temperature reservoirs where the MMP increases due to the high temperature, or in shallow reservoirs where the fracture pressure is very low.…”

Section: Introductionmentioning

confidence: 99%

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Effect of Functional Groups on Chemical-Assisted MMP Reduction of a Methane-Oil System

et al. 2021

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Natural gas injection (i.e., recycling) is a commonly used for enhanced oil recovery method and is potentially costeffective and efficient. However, natural gas injection, particularly methane, often has a high minimum miscibility pressure (MMP) which likely exceeds the fracture pressure of many otherwise viable reservoirs. Therefore, this work aims to investigate the potential of chemical-assisted MMP reduction of the methane-oil system to expand the application of miscible natural gas injection to more candidate reservoirs. In this context, we performed a study to test six potential surfactant-like chemicals with different polar headgroups (i.e., morpholine, aromatic sulfonic acid, aromatic carboxylic acid, and 2-oxypyrrolidine). The intent is to reduce the methane-oil interfacial tension using the vanishing interfacial tension method at a constant temperature of 373 K. First, at a concentration of 2 wt %, we tested the effect of the polar headgroups with the same hydrocarbon chain. Then, we investigated the effect of increasing the hydrocarbon chain length on the methane-oil miscibility. Our results show that chemical additives with the 2oxopyrrolidine and aromatic sulfonic acid functional groups give higher MMP reductions (8.7−9.6%, respectively) compared with aromatic carboxylic acid and morpholine groups, which only give limited or no MMP reduction. Moreover, the results show that the reduction in first contact miscibility pressure is higher (12.8−19.1%) compared to MMP. Furthermore, increasing the hydrocarbon chain length (from 10 to 13) of the 2-oxopyrrolidine and aromatic sulfonic acid molecules seems to decrease the efficiency in reducing MMP. Our results screen the potential of a combinatorial chemistry approach (where two molecules with differing sizes and functional groups can be readily joined together to make a large library of compounds) that can be used to identify chemical additives for reducing MMP of methane-oil. This approach underscores the importance of optimizing the functional group and hydrocarbon chain length in potential chemicals for MMP reduction. The outlined research results likely expand the application of miscible natural gas injection to deep and/or high-temperature reservoirs, in addition to the environmental benefits of reducing gas flaring and greenhouse gas emissions through natural-gas recycling.

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Section: Results and Discussionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Effect of Functional Groups on Chemical-Assisted MMP Reduction of a Methane-Oil System

et al. 2021

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“…Modifying CO 2 helps to enhance the interaction between CO 2 and oil, thereby reducing IFT and MMP (Saira et al, 2020). Additives used to modify CO 2 -oil systems have included alcohols (Moradi et al, 2014;Luo et al, 2018;Shang et al, 2018;Yang et al, 2019), polymers (Gu et al, 2013;Al Hinai et al, 2019), surfactants (Aji et al, 2016;Luo et al, 2018;Kuang et al, 2021), and other chemicals (Rommerskirchen et al, 2016;Rommerskirchen et al, 2018). Moradi et al (2014) and Yang et al (2019) added alcohol in oil to modify a CO 2 -oil system.…”

Section: Introductionmentioning

confidence: 99%

“…They reported an IFT reduction of 0.7-3.6 mN/m and an MMP reduction of 7.4-7.6 MPa. Al Hinai et al (2019) used polymers placed on metal plate inside HPHT cell to modify CO 2 . They reported slight reduction in IFT with modified CO 2 at lower pressures while 0.5-1.5 mN/m reduction in IFT at high pressures resulted in 5-5.3 MPa reduction in MMP.…”

Section: Introductionmentioning

confidence: 99%

Effect of alcohol-treated CO2 on interfacial tension between CO2 and oil, and oil swelling

Saira

Yin

Le-Hussain

2021

Adv. Geo-Energy Res.

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CO₂–Brine–rock interaction and sequestration capacity in carbonate reservoirs of the Tahe Oilfield, Xinjiang, China

Tan

et al. 2022

Greenhouse Gases

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The characteristics of each carbonate reservoir are greatly different, and current databases are insufficient to support engineering scheme design and optimization of carbon dioxide (CO2) sequestration and enhanced oil recovery. In this paper, the behavior of CO2‐brine‐rock interactions was investigated under supercritical CO2 (50°C and 8.5 MPa) conditions. Five experiments were carried out, including CO2 solubility in brine, mass loss analysis by static reaction of CO2–brine–rock, mineralogical composition analysis by X‐ray diffraction (XRD), core surface morphology analysis by scanning electron microscopy (SEM), and wettability alteration by contact angle analysis. The experimental results showed that: (a) the CO2 solubility in brine increases with increasing pressure, but it increases slowly and gradually reaches equilibrium; (b) the mass loss of carbonate increases with reaction time, but its increments decrease with reaction time; (c) the calcite content gradually decreases and the quartz content slightly increases with reaction time, as evidenced by XRD analysis; (d) based on SEM image analysis, calcite was dissolved into brine by carbonic acid to make the pores larger, and then subsequent precipitation made the pores smaller; and (e) the carbonate rock surface became more water‐wet after CO2–brine–rock interaction experiments due to surface corrosion and increased quartz content. Using the experimental results, a mathematical model was developed to predict CO2 sequestration capacity under reservoir conditions. The results suggest that CO2 solubility in brine was the main aspect compared with mineral trapping in carbonate reservoirs, and CO2 sequestration capacity increased with increasing temperature and pressure. © 2022 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Effects of oligomers dissolved in CO2 or associated gas on IFT and miscibility pressure with a gas-light crude oil system

Cited by 19 publications

References 45 publications

Effect of Functional Groups on Chemical-Assisted MMP Reduction of a Methane-Oil System

Effect of Functional Groups on Chemical-Assisted MMP Reduction of a Methane-Oil System

Effect of alcohol-treated CO2 on interfacial tension between CO2 and oil, and oil swelling

CO₂–Brine–rock interaction and sequestration capacity in carbonate reservoirs of the Tahe Oilfield, Xinjiang, China

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Effects of oligomers dissolved in CO2 or associated gas on IFT and miscibility pressure with a gas-light crude oil system

Cited by 19 publications

References 45 publications

Effect of Functional Groups on Chemical-Assisted MMP Reduction of a Methane-Oil System

Effect of Functional Groups on Chemical-Assisted MMP Reduction of a Methane-Oil System

Effect of alcohol-treated CO2 on interfacial tension between CO2 and oil, and oil swelling

CO2–Brine–rock interaction and sequestration capacity in carbonate reservoirs of the Tahe Oilfield, Xinjiang, China

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CO₂–Brine–rock interaction and sequestration capacity in carbonate reservoirs of the Tahe Oilfield, Xinjiang, China