Formation water evaporation induced salt precipitation and its effect on gas production in high temperature natural gas reservoirs

Cui, Guodong; Ren, Shaoran; Zhang, Liang; Ren, Bo; Zhuang, Yuan; Li, Xin; Han, Bo; Zhang, Panfeng

doi:10.1016/s1876-3804(16)30097-0

Cited by 26 publications

(6 citation statements)

References 8 publications

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“…Salt precipitation changes the reservoir porosity. Based on Cui et al's mathematical model of salting-out for reservoir water evaporation [21], the relationship between the reservoir porosity and precipitated salt accumulation was obtained by considering the influence of the precipitated salt on the reservoir porosity.…”

Section: Establishing the Connection Parameters After High Temperatur...mentioning

confidence: 99%

“…where K is the reservoir permeability (um 2 ); K 0 is the initial permeability of the reservoir (um 2 ); and b is the relational index (integer). The optimal value of b in the Kozeny-Carman equation during the salting-out process was estimated to be 4 using error analysis [21].…”

Section: Establishing the Connection Parameters After High Temperatur...mentioning

confidence: 99%

“…However, their study did not consider the effect of the plugging agent dosage on the plugging ratio. Cui et al [21] established a comprehensive salting-out model considering the reservoir water evaporation, NaCl precipitation in water, and the change in reservoir porosity/permeability, and analyzed the reservoir water evaporation and salting-out during the development of high-temperature gas reservoirs. Their model can describe the salt precipitation of high-temperature gas reservoirs and establish a relationship between salt precipitation and porosity/permeability to analyze the influence of salt precipitation on production.…”

Section: Introductionmentioning

confidence: 99%

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Optimization of the Plugging Agent Dosage for High Temperature Salt Profile Control in Heavy Oil Reservoirs

Ruan¹,

Lu²,

Zhang³

et al. 2023

Fluid Dynamics &Amp; Materials Processing

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After steam discharge in heavy oil reservoirs, the distribution of temperature, pressure, and permeability in different wells becomes irregular. Flow channels can easily be produced, which affect the sweep efficiency of the oil displacement. Previous studies have shown that the salting-out plugging method can effectively block these channels in high-temperature reservoirs, improve the suction profile, and increase oil production. In the present study, the optimal dosage of the plugging agent is determined taking into account connection transmissibility and interwell volumes. Together with the connectivity model, a water flooding simulation model is introduced. Moreover, a non-gradient stochastic disturbance algorithm is used to obtain the optimal plugging agent dosage, which provides the basis for the high-temperature salting-out plugging agent adjustment in the field.

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Section: Establishing the Connection Parameters After High Temperatur...mentioning

confidence: 99%

Section: Establishing the Connection Parameters After High Temperatur...mentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Optimization of the Plugging Agent Dosage for High Temperature Salt Profile Control in Heavy Oil Reservoirs

Ruan¹,

Lu²,

Zhang³

et al. 2023

Fluid Dynamics &Amp; Materials Processing

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“…In a few studies, only the salinity is regarded as a constant . In the process of actual gas reservoir exploitation, salt deposit is easy to occur in the near-wellbore area, causing the change of formation water salinity. − The salinity is always affected by reservoir temperature and pressure. Through field fluid sampling, the ion concentration in different periods of a well in the Wen 23 gas field is shown in Figure ; it was found that the main component of salt was NaCl.…”

Section: Introductionmentioning

confidence: 99%

Study on the Phase Behavior Simulation Method of High-Salinity Reservoirs

Ren,

Li,

Yuan

et al. 2024

ACS Omega

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The presence of salinity affects the accuracy of existing correlations used in the equation of state. Moreover, the variation of salinity is often ignored in the systematic analysis of the phase diagram, resulting in a large error in the final calculation result. It is obvious that the conventional phase equilibrium calculation is not applicable in a high-salinity reservoir. By introducing the hydrocarbon−brine binary interaction coefficient and α-function, combined with the definition of salinity, and considering the variation of salinity under different pressure and temperature conditions, a more perfect phase equilibrium calculation model was established. The complete phase diagram was drawn, and the calculation results of salinity distribution are obtained. The effect of the mole percentage of water and salt content on the phase behavior was simulated. Finally, the phase distribution simulation is carried out based on the measured data. The phase state and salinity variation law of a high-salinity reservoir are obtained. According to the fluid composition of different periods, the real phase state of the high-salinity reservoir can be monitored in real time. It can provide a theoretical basis for the gas reservoir development and the dynamic evaluation of gas storage injection and production with a hydrocarbon−brine two-phase system.

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“…Mineral scaling in porous formations has a significant impact on applications such as CO 2 capture and storage (CCS), enhanced oil recovery, geothermal processes, utilization of membranes, and so forth. − Over the past two decades, considerable research work has been focused on CCS in underground formations for the reduction of greenhouse effects. − Injection of supercritical (Sc) CO 2 into underground porous formations is often accompanied by salt precipitation because of the concomitant increase in the concentration of dissolved salts in the brine. , Experimental investigation of CaCO 3 precipitation using supersaturated solutions in 2-D glass porous media at different temperatures showed that crystal growth rates increased with increasing temperature and with increasing initial SR . During gas injection in microfluidic porous media, three domains of the precipitation rates were found: fast, medium, and slow.…”

Section: Introductionmentioning

confidence: 99%

Mineral Scaling in the Presence of Oil–Water Interfaces Combined with the Substrate’s Wettability Effect: From Batch to Microfluidic Experiments

Tzachristas

Natsi

Kanellopoulou

et al. 2021

Ind. Eng. Chem. Res.

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Calcium carbonate (CaCO 3 ) nucleation and growth in the presence of a liquid phase immiscible with water were investigated in batch reactors for a constant supersaturation ratio (SR) value and for various volume ratios of the oil to aqueous phase (V Ro/a ), under ambient conditions, at various stirring rates. Precipitation rates and induction times were measured, and surface energy was calculated according to the classical nucleation theory. The precipitates were characterized by scanning electron microscopy and X-ray diffraction. The induction times of crystal nucleation were shorter in the presence of the oil phase. Surface diffusion was the ratedetermining step in the precipitation process at high stirring rates. Moreover, the substrate's wettability effect was investigated in hydrophilic and hydrophobic microchips of Y-junction morphology. CaCO 3 precipitation from supersaturated solutions was studied over a range of SR values at residual oil saturation (S or ). Crystal growth was monitored using an optical microscope, and CaCO 3 polymorphs were characterized by Raman spectroscopy. Crystal nucleation was accelerated in the presence of oil/water interfaces, and growth rates of individual crystallites decreased. Hydrophobic microchips at S or favored the formation of smaller size crystals over the entire length of the microchannel. With increasing SR, the less stable polymorphs were reduced.

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Formation water evaporation induced salt precipitation and its effect on gas production in high temperature natural gas reservoirs

Cited by 26 publications

References 8 publications

Optimization of the Plugging Agent Dosage for High Temperature Salt Profile Control in Heavy Oil Reservoirs

Optimization of the Plugging Agent Dosage for High Temperature Salt Profile Control in Heavy Oil Reservoirs

Study on the Phase Behavior Simulation Method of High-Salinity Reservoirs

Mineral Scaling in the Presence of Oil–Water Interfaces Combined with the Substrate’s Wettability Effect: From Batch to Microfluidic Experiments

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