Dimensionless correlation for the prediction of permeability reduction rate due to calcium sulphate scale deposition in carbonate grain packed column

Tahmasebi, Hamzeh Ali; Kharrat, Riyaz; Soltanieh, Mohammad

doi:10.1016/j.jtice.2009.11.006

Cited by 14 publications

(2 citation statements)

References 17 publications

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“…The formation damage, due to scale formation, was also monitored for each core sample in the course of injection period until a constant pressure difference was reached between the inlet and outlet, that is, ambient pressure during the injection time. Thereafter, the formation damage was determined by permeability reduction based on the following Darcy’s law , where k is the absolute permeability (mD), Q is the flow rate (mL/min), μ is the solution viscosity (cP), L is the length of the core sample (cm), A is the cross-sectional area of the cores (cm 2 ), and Δ P is the pressure drop (atm).…”

Section: Materials and Experimental Proceduresmentioning

confidence: 99%

Mitigation of Mineral Deposition in Carbonate and Sandstone Rocks Using Green Scale Inhibitors

et al. 2022

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Waterflooding is potentially a viable approach to enhance oil recovery, though its efficacy can profoundly be compromised due to formation damage as a result of inorganic scale deposition. In this study, a series of high-temperature core flooding experiments were conducted to evaluate two green scale inhibitors (SIs) of folic acid and inulin as alternative inhibitors to mitigate mineral deposition. The co-injection of two incompatible brines (with and without SIs) for two flow rates of 0.5 and 3 mL/min into two core samples of dolomite and sandstone was experimentally investigated. The results showed that folic acid would inhibit scale formation as much as 45–49%, at the lower flow rate, compared to inulin with an efficiency of 29–39%, at the higher flow rate. Moreover, computed tomography imaging technique showed that scale formation and fine migration would be dominant mechanisms for formation damage in dolomite and sandstone rocks, respectively. The theoretical study based on surface energy also confirmed the experimental results in terms of the work of adhesion which showed that folic acid would mitigate the calcite deposition on rock surfaces approximately 55%. Finally, a phosphonate-based commercial SI was compared with the green SIs which reaffirmed their potencies.

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Section: Materials and Experimental Proceduresmentioning

confidence: 99%

Mitigation of Mineral Deposition in Carbonate and Sandstone Rocks Using Green Scale Inhibitors

et al. 2022

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“…It was observed that the pressure drop increases constantly due to pores blockage by solid scale crystals. Tahmasebi et al (2010) conducted dynamic tests in a packed column of glass beads and carbonate grains to explore the influence of temperature, ionic composition, and velocity of injection water on permeability variations. They reported that core permeability decreases due to the formation of calcium sulfate scale with increasing the temperature, and the injection rate.…”

Section: Introductionmentioning

confidence: 99%

Static and dynamic evaluation of formation damage due to barium sulfate scale during water injection in carbonate reservoirs

Valadbeygian,

Hajipour,

Behnood

2023

J Petrol Explor Prod Technol

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One of the major challenges during water injection into oil reservoirs is mineral scales formation. Barium sulfate is one of the hardest inorganic scales in oil fields and insoluble in chemical solvents. Therefore, in this study, the formation conditions of barium sulfate scale were investigated. The experiments were performed in two parts including static and dynamic compatibility tests and the impact of brines volume ratio, temperature, pH, and salinity of injection water were explored. In addition, the scale formation tendency was simulated and the results were compared with the measured data. The results of static experiments indicated that the maximum amount of barium sulfate scale equals 63 mg/l forms at 90% formation water. Comparing the results of static and dynamic compatibility tests revealed that the increase of pH value increases barium sulfate scale in dynamic tests while having no effect in static experiments. This finding confirms that a different scale formation mechanism prevails in the presence of reservoir rock. The experimental results also approve that the amount of barium sulfate scale decreases by reducing the salinity of injection water, so that by diluting injection water 5 times, the maximum amount of scale decreased 21% and 44% at ambient and reservoir temperatures, respectively. The findings of this study help for better determination of water properties to increase the efficiency of water injection operations, enhance oil production and simultaneously diminish formation damage. Concurrent assessment of static and dynamic tests leads to determining the dominant mechanisms of scale formation in the presence of reservoir rock which helps to select the appropriate remediation methods.

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Permeability Decline in Fractured Porous Media During Mineral Scaling: A Detailed Modeling Study

et al. 2022

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Brine injection into underground reservoirs is performed commonly in oil, natural gas, and geothermal industries. The injected fluid may contain some reactive ions that can cause mineral scaling. In addition, a porous medium may be naturally fractured or it can be fractured through hydraulic fracking. The existence of a fracture in a porous medium can facilitate the transport of reactive ions, which leads to a change in the deposition pattern and affects the permeability decline. This study presents a numerical method for modeling mineral precipitation-deposition in the fractured porous media. This study contributes to the analysis of the impact of fracture on permeability and porosity variations in porous media caused by mineral scaling. The results of the modeling indicate that deep invasion of reactive ions through fractures leads to steeper permeability reduction. This study showed that, with constant fracture length, a single fracture pattern experiences the highest permeability reduction compared to other patterns such as an internal fracture, a deviated fracture, a looped fracture, and multiple fractures. In addition, the relationship between fracture length and modeling parameters was investigated through inverse modeling. This showed that fracture length has a linear relationship with the formation damage coefficient, but it has an exponential correlation with the reaction kinetics coefficient.

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Dimensionless correlation for the prediction of permeability reduction rate due to calcium sulphate scale deposition in carbonate grain packed column

Cited by 14 publications

References 17 publications

Mitigation of Mineral Deposition in Carbonate and Sandstone Rocks Using Green Scale Inhibitors

Mitigation of Mineral Deposition in Carbonate and Sandstone Rocks Using Green Scale Inhibitors

Static and dynamic evaluation of formation damage due to barium sulfate scale during water injection in carbonate reservoirs

Permeability Decline in Fractured Porous Media During Mineral Scaling: A Detailed Modeling Study

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