Experimental and modelling approach to investigate the mechanisms of formation damage due to calcium carbonate precipitation in carbonate reservoirs

Qazvini, Sajjad; Golkari, Abdolah; Azdarpour, Amin; Safavi, Mir Saeid; Norouzpour, Milad

doi:10.1016/j.petrol.2021.108801

Cited by 21 publications

(8 citation statements)

References 50 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Furthermore, asphaltene particles are very heavy and polar and prefer to stick onto the rock surface (solid surface) instead of dispersing into the liquid phase (oleic or aqueous phases) when conditions become thermodynamically unstable for them. On the other hand, pore blocking occurs when asphaltene particles are connected and form a bridge on the pore diameter, increasing the rate of asphaltene accumulation and reducing the core permeability. − The reservoir cores used in this study are slightly tight in terms of permeability (5.83–11.83 mD). On the other hand, the asphaltene content of the crude oil used was about 0.9 wt %.…”

Section: Resultsmentioning

confidence: 99%

Comparative Static and Dynamic Analyses of Solvents for Removal of Asphaltene and Wax Deposits above- and below-Surface at an Iranian Carbonate Oil Field

et al. 2023

Self Cite

View full text Add to dashboard Cite

During production from oil wells, the deposition of asphaltene and wax at surface facilities and porous media is one of the major operational challenges. The crude oil production rate is significantly reduced due to asphaltene deposition inside the reservoir. In addition, the deposition of these solids inside the surface facilities is costly to oil companies. In this study, the efficiency of different solvents in dissolving asphaltene and wax was investigated through static and dynamic tests. The analysis of solid deposits from the surface choke of one of the Iranian carbonate oil fields showed that they consisted of 41.3 wt % asphaltene, and the balance was predominantly wax. In addition, the asphaltenes obtained from the surface choke solid deposits had a more complex structure than that of asphaltenes extracted from the crude oil itself. The static tests showed that xylene, toluene, gasoline, kerosene, and gas condensate had the highest efficiencies in dissolving solid deposits; conversely, diesel had a negative impact on dissolving solid deposits. Static tests on pure asphaltene showed that, among the tested solvents, gas condensate and diesel had a negative effect on the solubility of asphaltene. The dynamic core flooding results showed that asphaltene deposition inside the cores reduced the permeability by 79−91%. Among the tested solvents, xylene, gasoline, and kerosene resulted in the highest efficacy in restoring the damaged permeability, and higher efficiency was obtained with an equivalent solvent injection rate of 1 bbl/min versus 3 bbl/min.

show abstract

Section: Resultsmentioning

confidence: 99%

Comparative Static and Dynamic Analyses of Solvents for Removal of Asphaltene and Wax Deposits above- and below-Surface at an Iranian Carbonate Oil Field

et al. 2023

Self Cite

View full text Add to dashboard Cite

show abstract

“…The experimental results show that the formation water type is NaHCO 3 , while the injection water type is MgCl 2 . According to the difference in ion and salinity of formation water and injection water, there is a potential incompatibility problem [21][22][23][24][25][26][27].…”

Section: Compatibility Test Of Injected Watermentioning

confidence: 99%

Study on Damage Mechanism of Waterflooding Development in Weizhou 11-4N Low-Permeability Oilfield

Zhang

Zhu

Feng³

et al. 2023

Geofluids

View full text Add to dashboard Cite

Weizhou 11-4N oilfield is a medium-low-porosity and low-permeability reservoir. The oilfield was initially developed by edge and bottom water energy and then transferred to water injection development. Affected by poor physical properties and heterogeneity of the reservoir, the oilfield appeared in the process of water injection development. When the water injection pressure increases, the water injection volume continues to decrease, and it is difficult to meet the injection requirements. On the basis of the analysis of reservoir heterogeneity, void structure, and clay minerals of reservoir, the water injection compatibility experiment, damage evaluation experiment, and nuclear magnetic resonance-velocity sensitivity experiments were carried out to clarify the damage in the process of oilfield water flooding development. Experiments show that the main causes of damage in Weizhou 11-4N oilfield water flooding development process are water quality incompatibility and strong velocity-sensitive damage. The determination of water type shows that the injected water and formation water are MgCl2 water type and NaHCO3 water type, respectively, under the classification of Surin water type, resulting in the formation of scale with calcium carbonate as the main component in the reservoir. Incompatibility of water quality is an important cause of reservoir damage and scaling. In the reservoir-sensitive flow experiment, the experimental core showed strong velocity sensitivity, the average velocity sensitivity damage rate was 466.31%, and the average critical velocity was 2.98 m/d. Nuclear magnetic resonance experiments show that the core has a significant decrease in average pore size after water flooding. The main damage range is the tiny throat of 0-2 μm. In this paper, the main damage interval of velocity-sensitive damage in the Weizhou 11-4N area and the change trend of void structure after velocity-sensitive experiment are clarified by nuclear magnetic resonance and velocity sensitivity experiments. The main cause of block reservoir damage provides the basis for the oilfield to take targeted measures and provides a guarantee for the efficient development of the subsequent oilfield.

show abstract

“…Surfactant flooding is one of the CEOR methods that has been successfully implemented for the past few decades; however, the environmental drawbacks of these chemical-based compounds have raised serious concerns about these materials. These chemical-based surfactants are toxic and nonenvironmentally friendly, restricting them from further development [1][2][3][4][5][6][7][8][9][10][11][12].…”

Section: Introductionmentioning

confidence: 99%

“…This investigation determined the capillary number (NCa) using Equation (1). In this equation, the IFT (mN/m) and contact angle of each case were measured directly from the performed experiments, and the viscosity of the solution (Pa.s), rock porosity, and velocity (m/s) of the injected solutions were measured separately, and used for capillary number calculations.…”

mentioning

confidence: 99%

Synergism of a Novel Bio-Based Surfactant Derived from Pisum sativum and Formation Brine for Chemical Enhanced Oil Recovery in Carbonate Oil Reservoirs

et al. 2023

Self Cite

View full text Add to dashboard Cite

The Pisum sativum (PS), known as the green pea, was used in this investigation to produce a novel green surfactant. The performance of the PS green surfactant was also evaluated using various tests, including contact angle, IFT, emulsion, zeta potential, and oil recovery factor measurement in the presence of formation brine (FB) with a total dissolved solid (TDS) of 150,000 ppm. The characterization study using various tests revealed that the PS green surfactant was nonionic. The critical micelle concentration (CMC) measurement results indicated that the PS green surfactant’s CMC value is 1500 ppm. The IFT and contact angle measurements showed that the green surfactant significantly lowered the IFT and contact angles. The lowest IFT value of 3.71 mN/m and the contact angle of 57.37° were achieved at the FB concentration of 12,500 ppm (optimum salinity). The results of the emulsion tests showed that Winsor type III emulsions were achieved using PS green surfactant and crude oil. The core flooding experiments revealed that the tertiary recovery using a solution of 1500 ppm of PS green surfactant and 12,500 ppm of FB resulted in a maximum oil recovery factor of 83.55%.

show abstract

Experimental and modelling approach to investigate the mechanisms of formation damage due to calcium carbonate precipitation in carbonate reservoirs

Cited by 21 publications

References 50 publications

Comparative Static and Dynamic Analyses of Solvents for Removal of Asphaltene and Wax Deposits above- and below-Surface at an Iranian Carbonate Oil Field

Comparative Static and Dynamic Analyses of Solvents for Removal of Asphaltene and Wax Deposits above- and below-Surface at an Iranian Carbonate Oil Field

Study on Damage Mechanism of Waterflooding Development in Weizhou 11-4N Low-Permeability Oilfield

Synergism of a Novel Bio-Based Surfactant Derived from Pisum sativum and Formation Brine for Chemical Enhanced Oil Recovery in Carbonate Oil Reservoirs

Contact Info

Product

Resources

About