The influence of spreading coefficient on carbonated water alternating gas injection in a heavy crude oil

Riazi, Masoud; Golkari, Abdolah

doi:10.1016/j.fuel.2016.03.021

Cited by 70 publications

(32 citation statements)

References 58 publications

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“…In all of IFT tests, the CO 2 density was considered equal to that of pure CO 2 , and it was extracted from National Institute of Standards and Technology source data at both temperatures and desired pressures (''NIST, Chemistry WebBook, NIST Standard Reference Database'', 2014). (Riazi and Golkari 2016) Since the pure CO 2 density has a small difference with that of the CO 2 equilibrium with oil, this assumption does not make a considerable error in the results (Zolghadr et al 2013). …”

Section: Resultsmentioning

confidence: 97%

Experimental investigation of miscibility conditions of dead and live asphaltenic crude oil–CO2 systems

Golkari

Riazi

2016

J Petrol Explor Prod Technol

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Carbon dioxide (CO 2 ) injection is a well-established enhanced oil recovery method. The optimization process of CO 2 injection is usually performed through estimation of two physical properties, i.e., minimum miscibility and first-contact miscibility pressures (MMP and FCMP) for the crude oil-CO 2 system. In this experimental study, the equilibrium IFT of the crude oil-CO 2 system is measured at (313.15 and 323.15 K) for two oil types (i.e., live and dead crude oil) using the axisymmetric pendant drop shape analysis method. Vanishing interfacial tension technique is also applied to estimate the MMP and FCMP. The experimental results demonstrate that IFT decreases with different trends as the equilibrium pressure increases for the systems of live oil/CO 2 and dead oil/CO 2 systems.The IFT test results demonstrate that the estimated MMP and FCMP values of crude oil-CO 2 system increase with temperature. It was also observed that the presence of methane gas in the oil phase increases the MMP value, whereas it decreases the FCMP.

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Section: Resultsmentioning

confidence: 97%

Experimental investigation of miscibility conditions of dead and live asphaltenic crude oil–CO2 systems

Golkari

Riazi

2016

J Petrol Explor Prod Technol

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“…Reduction of oil‐water IFT by dissolution of CO 2 in water and oil has been reported by several researchers . While IFT reductions up to 20% were reported for oil‐brine systems, carbonated smart water has been reported to have 48% lower IFT compared to its non‐carbonated type.…”

Section: Introductionmentioning

confidence: 89%

Experimental evaluation of carbonated waterflooding: A practical process for enhanced oil recovery and geological CO₂ storage

et al. 2017

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The rapid escalation of anthropogenic CO2 emissions at the same time as the growth in energy demand has brought the importance of CO2 enhanced oil recovery (EOR) into the spotlight. Nevertheless, fundamental problems with conventional CO2 injection have paved the way for practicing other strategies, such as carbonated waterflooding (CWF), i.e., flooding of CO2 dissolved in flood water through the reservoir. In this work, performance of CWF as a joint method of EOR and CO2 storage in an Iranian oil field is examined through sets of coreflooding experiments, conducted at a specified pressure and temperature condition on two different reservoir oil (light and heavy) and rock (carbonate and sandstone) samples from the investigated oil field. In summary, CWF improved the oil recovery as compared to waterflooding (WF). Average recovery factors (RFs) for CWG ranged from 6.4% to 13.6% when implemented as a secondary recovery technique and 4.2% to 4.8% when used as a tertiary recovery technique. This improvement was also higher in the carbonate rock than in the sandstone one, slightly higher with light oil than with heavy oil, and lower when a more saline brine was used for carbonated water preparation. CWF also showed to be more effective when implemented in a mixed‐wet system than in a water‐wet one. Moreover, considerable amounts (about 42‒60%) of the CO2 injected through the flooding brine were ultimately stored in the porous media. Finally, a co‐optimizing function was used as a standard for coupling CO2 EOR and storage. © 2017 Society of Chemical Industry and John Wiley & Sons, Ltd.

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“…Approximately, 40 to 60 % of oil production rate has been attained with the utilization of the EOR technologies (Muggeridge et al, 2014). Water Alternating Gas (WAG) technology, which requires simultaneous injection of gas and water into the reservoir has been the most frequently employed EOR technology (Riazi and Golkari, 2016). However, early gas breakthrough, gravity override and viscous fingering constituted the main challenge in the WAG execution, and result to poor sweep efficiency over time (Qureshi et al, 2016).…”

Section: *Enhancedmentioning

confidence: 99%

Effect of SiO2 on the foamability, thermal stability and interfacial tension of a novel nano-fluid hybrid surfactant

Hamza

2018

Int. j. adv. appl. sci.

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In foam assisted water alternating gas (FAWAG) method, thermal stability, foamability and interfacial effect of foaming agents (surfactants) are important properties governing the success of oil recovery. The effect of high reservoir temperature is detrimental to these properties, which becomes a great challenge for the applications of surfactants in enhanced oil recovery (EOR). Silica nano-fluid (SiO2), which is a recently employed technology, has been utilized to improve the rheology, stability and interfacial properties of surfactants. This study is aimed at investigating the effect of SiO2 in improving the thermal stability, relative foamability and interfacial (IFT) effect of industrial based surfactant (IBS). Design Expert Software (DOE) using central composite design (CCD) at five levels (-1.68 to +1.68) was employed in the experimental design. The chemical interaction between the SiO2 and IBS in the novel nano-fluid hybrid surfactant (SiO2-IBS) had been successfully established using different spectroscopic instruments (FTIR, XRD, FESEM etc.). Furthermore, under the optimum conditions established, SiO2 had significant effects on the relative foamability and thermal stability of the hybrid material (SiO2-IBS) at 25-110 o C, and their synergistic effect had been quantified in the multivariate models (cubic). However, the IFT result indicated that presence of the SiO2 in the hybrid had reduced the IFT drastically from 120.3 ± 9.8 mN/m to 10.6 ± 6.8 mN/m. Consequently, the novel SiO2-IBS nano hybrid surfactant could be a suitable flooding agent in the high temperature reservoirs for application in FAWAG method.

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The influence of spreading coefficient on carbonated water alternating gas injection in a heavy crude oil

Cited by 70 publications

References 58 publications

Experimental investigation of miscibility conditions of dead and live asphaltenic crude oil–CO2 systems

Experimental investigation of miscibility conditions of dead and live asphaltenic crude oil–CO2 systems

Experimental evaluation of carbonated waterflooding: A practical process for enhanced oil recovery and geological CO₂ storage

Effect of SiO2 on the foamability, thermal stability and interfacial tension of a novel nano-fluid hybrid surfactant

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The influence of spreading coefficient on carbonated water alternating gas injection in a heavy crude oil

Cited by 70 publications

References 58 publications

Experimental investigation of miscibility conditions of dead and live asphaltenic crude oil–CO2 systems

Experimental investigation of miscibility conditions of dead and live asphaltenic crude oil–CO2 systems

Experimental evaluation of carbonated waterflooding: A practical process for enhanced oil recovery and geological CO2 storage

Effect of SiO2 on the foamability, thermal stability and interfacial tension of a novel nano-fluid hybrid surfactant

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Experimental evaluation of carbonated waterflooding: A practical process for enhanced oil recovery and geological CO₂ storage