Asphaltene instability in the presence of emulsified aqueous phase

Shahsavani, Behnam; Riazi, Masoud; Malayeri, M.R.

doi:10.1016/j.fuel.2021.121528

Cited by 8 publications

(10 citation statements)

References 78 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Finally, the UV−vis absorbance of the toluene/asphaltene mixture was measured to measure the asphaltene content by using a calibration curve, as explained in Appendix S.B (in the Supporting Information). 17,34 It is worth mentioning that in this study the water/rock amount, rock type, and contact time are fixed in all experiments. However, the effect of these parameters on asphaltene and emulsion stability is the subject of future works.…”

Section: Investigation Of the Effect Of Calcite Dissolution On Asphal...mentioning

confidence: 99%

“…Therefore, during the waterflooding process, they are mostly attracted to the oil/water interface and form a rigid film that prevents the water droplet coalescence. This process can lead to stable emulsion formation, asphaltene instability, and deposition. ,− Moreover, asphaltene particles could adsorb and deposit on the reservoir rock surface and alter the rock wetting state to oil-wet conditions, causing pore plugging and injectivity/productivity decline. ,− …”

Section: Introductionmentioning

confidence: 99%

“…Various laboratory and field studies have demonstrated that manipulating the type and the content of ions in the injection water, known as low-salinity waterflooding (LSWF), can lead to incremental oil recovery. Even though the effect of LSWF has been justified by several measurements such as rock wettability, relative permeability, capillary pressure, and rock-fluid and fluid–fluid interfacial properties, there is no consensus on the dominant governing mechanism. − Unlike the overwhelming number of papers on solid–liquid interactions and underlying mechanisms of enhanced oil recovery by LSWF, studies on the side effects of LSWF, such as asphaltene instability, (viscous) emulsion formation, and organic scaling–eventually impeding flow and leading to formation damage–are scarce. − It is worth mentioning that some experimental results suggest that emulsion production and asphaltene deposition, as the side effects of the LSWF process, could improve the injection performance by increasing the breakthrough time and sweep efficiency. − …”

Section: Introductionmentioning

confidence: 99%

See 2 more Smart Citations

The Simultaneous Effect of Brine Salinity and Dispersed Carbonate Particles on Asphaltene and Emulsion Stability

2023

View full text Add to dashboard Cite

The oil recovery improvement by low-salinity waterflooding (LSWF) must be achieved with minimal formation damage. The asphaltic fractions of crude oil can be destabilized when in contact with incompatible injection brines resulting in organic formation damage. Due to the lack of fundamental understanding about the potential effect of rock presence on this phenomenon, in this study, the simultaneous effect of brine salinity and calcite rock presence on asphaltene instability in an emulsified system was investigated by developing a new experimental protocol. In this method, calcite rock is dispersed in different brines with total salinity ranging from 0−189,365 ppm and then mixed with oil to find the rock and brine effect on asphaltene and emulsion stability. UV−vis spectroscopy is performed on the supernatant oil phase before and after contact with brine to assess quantitatively asphaltene instability. Oil/water IFT measurements before and after contact and microscopic analysis of the water droplet size were conducted to evaluate the water/oil interface behavior. Besides, the zeta-potential for suspended calcite particles in different brines was measured to evaluate the electrokinetics of rock-oil interaction. The results show increased asphaltene instability when oil makes contact with the brine in an emulsified system. This highly depends on the brine type, and the maximum precipitation occurred at an intermediate salinity with two-times diluted seawater. While the trend of before-contact IFT and the water-in-oil emulsion size at different salinities is consistent, the UV−vis absorbance of bulk oil shows a reverse tendency with the after-contact IFT. Asphaltene deposition generally increased when solid calcite particles were present in the emulsified system, and at higher salinities, more asphaltene adsorption on the rock surface occurred due to a larger attractive force between rock and asphaltene. This trend is consistent with the results of the zeta-potential measurements. These novel findings can help avoid unrepresentative results regarding organic damage in LSWF.

show abstract

Section: Investigation Of the Effect Of Calcite Dissolution On Asphal...mentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

The Simultaneous Effect of Brine Salinity and Dispersed Carbonate Particles on Asphaltene and Emulsion Stability

2023

View full text Add to dashboard Cite

show abstract

“…The chemical removal of ARPDs using hydrocarbon solvents can improve the oil production process, increase the life cycle of the downhole equipment, and accelerate the dissolution and dispersion of organic deposits [26,27]. Solvents based on aromatic and saturated hydrocarbons, gas condensates with various modifying additives, have proven to be highly effective in removing ARPD [28,29].…”

Section: Literature Reviewmentioning

confidence: 99%

“…Industrial experience shows that paraffin deposits are formed by two mechanisms: the process of growth directly on the surface of the pipe, and the accumulation of paraffin crystals in the oil, which eventually attach to each other and to the metal [1][2][3]12,26,27]. Therefore, specialists of the oil industry are looking for ways to prevent the formation of organic deposits.…”

Section: Literature Reviewmentioning

confidence: 99%

Improving the Efficiency of Oil and Gas Wells Complicated by the Formation of Asphalt–Resin–Paraffin Deposits

2021

Self Cite

View full text Add to dashboard Cite

A number of difficulties may be encountered in the final stages of oil field exploitation, including the formation of asphalt–resin–paraffin deposits (ARPDs). It is expedient to use complex technologies to remove the already formed deposits and prevent the formation of ARPDs. This paper focuses on the complex technology of oil field exploitation. This technology combines both the removal of organic deposits and the prevention of the formation of these deposits in the well bottomhole formation zone (BHFZ) system. The calculations for determining the process parameters of selling the ARPD inhibitor solution into the BHFZ are presented in this article. This complex technology includes the process of ARPD removal by flushing the well and the subsequent injection of the developed ARPD solvent into the BHFZ. In addition, the technology is complemented by a method of preventing the formation of these deposits. This method consists of squeezing the ARPD inhibitor and then pumping it by the selling fluid from five to ten times of the volume. This article contains a detailed calculation of the methodology and provides the diagrams for the solvent and inhibitor injection.

show abstract