The impact of sulfur precipitation in developing a sour gas reservoir with pressure-sensitive effects

Ru, Zhixing; An, Kang; Hu, Jinghong

doi:10.26804/ager.2019.03.05

Cited by 9 publications

(6 citation statements)

References 23 publications

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“…An effective permeability-based gas injectivity is a general way to evaluate the capacity of gas injection in oil and gas reservoirs (Hu et al, 2017;Ru et al, 2019;Yu et al, 2019). In this stage, the CMG STARS software is employed to couple the analytical models to evaluate gas injectivity in lean zones.…”

Section: Gas Injectivity Calculations In Reservoir Simulationmentioning

confidence: 99%

Impacts of pore size distribution on gas injection in intraformational water zones in oil sands reservoirs

Chen

2020

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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Intraformational water zones are widely reported in Canadian oil sands fields. In order to pressurize a thief zone, one of the initiatives is to inject gas. However, the evaluation of gas injectivity based on a pore size distribution is still a big challenge. This study provides a multi-scale approach to study the effect of a pore size distribution on gas injectivity in intraformational water zones. The results indicate the gas effective permeability increases in a less complex and more discrete pore network. The enhancement of gas effective permeability with increased gas saturation weakens with higher complexity and lower discreteness of a pore network. A less complex and more discrete pore network better benefits the gas injectivity index.

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Section: Gas Injectivity Calculations In Reservoir Simulationmentioning

confidence: 99%

Impacts of pore size distribution on gas injection in intraformational water zones in oil sands reservoirs

Chen

2020

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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“…(5) Incorporation of the interaction energy between particles and pore walls, as well as the interaction between particles and gas phase flow. (6) No consideration of the clay expansion effect of the reservoir itself.…”

Section: Gas Reservoir Seepage Model With Dynamic Deposition Of Sulfu...mentioning

confidence: 99%

“…Their model incorporated the gas non-Darcy seepage law and sulfur deposition theory in porous media. Ru et al (2019) established a one-dimensional radial production model using the Hu’s model . Shao et al (2021) presented a semianalytical coupled reservoir/well bore model for horizontal wells in sulfur gas reservoirs .…”

Section: Introductionmentioning

confidence: 99%

Microscopic Mechanism and Percolation Model of Dynamic Deposition of Elemental Sulfur Particles in Acidic Gas Reservoirs

Wang,

Lu,

et al. 2024

ACS Omega

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The dissolution of elemental sulfur in acidic gas leads to its precipitation as gas pressure decreases, thereby causing potential damage to the formation due to the deposition of sulfur particles. Previous sulfur deposition prediction models often relied on the solubility of sulfur in acidic gas and the stress state of sulfur particles to determine the occurrence of deposition, thus establishing predictive models. However, in the presence of complex geological conditions, the multiphase flow through porous media and the adsorption of particles on pore throat walls can also influence sulfur particle deposition to some degree. It is well known that sulfur particle deposition during gas reservoir development exhibits instability, with multiple factors influencing the deposited sulfur particles. Particularly noteworthy is the influence of airflow velocity, which can resuspend sulfur particles that are physically adsorbed on pore throat surfaces, thereby reintegrating them into the gas phase. Additionally, the dynamic deposition of larger sulfur particles involves a dynamic process. This study elucidates the dynamic process of sulfur deposition by considering the diverse transport dynamics of sulfur particles. Physical adsorption and desorption behaviors of sulfur particles are determined based on variations in reservoir conditions. The desorption status of sulfur particles with different particle sizes within the formation is established by evaluating the equilibrium between the force exerted on the pore throat wall and the suspension force generated by gas flow. The critical conditions for sulfur deposition in Yuanba gas reservoir were obtained by substituting on-site parameters into calculations. Moreover, a mathematical model is proposed to describe the dynamic deposition and migration of sulfur particles, adopting principles from continuous porous media porous flow theory, fluid flow mass conservation, as well as sulfur particle desorption and migration. The formulated model is solved, and its resulting solution process and outcomes hold significant implications for numerical simulation and predictive assessment of the development impact on gas reservoirs, particularly in later stages.

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“…Therefore, the gas-water saturation in the fracture system can be established as a function of gas-water production with time. Given the characteristics of abnormal overpressure in this area, the stress sensitivity in this area cannot be ignored [36,54,55]. Therefore, the stress-sensitive model was considered in the dynamic relative permeability function.…”

Section: Coupling Stress Sensitivity With Dynamic Relativementioning

confidence: 99%

A Comprehensive Model for Estimating Stimulated Reservoir Volume Based on Flowback Data in Shale Gas Reservoirs

et al. 2020

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Stimulated reservoir volume (SRV) which is generated by horizontal drilling with multistage hydraulic fracturing governs the production in the shale gas reservoirs. Although microseismic data has been used to estimate the SRV, it is high-priced and sometimes overestimated. Additionally, the effect of stress sensitivity on SRV is not considered in abnormal overpressure areas. Thus, the objective of this work is to characterize subsurface fracture networks with stress sensitivity of permeability through the shale gas well production data of the early flowback stage. The flowback regions are first identified with the flowback data of two shale gas wells in South China. Then, we measured the permeability stress sensitivity of the core after fracturing, coupled to the dynamic relative permeability (DRP) calculation to obtain an accurate and simple DRP curve. After that, a comprehensive model is built considering dynamic two-phase relative permeability function and stress sensitivity. Finally, we compared the calculated results with the microseismic data. The results show that the proposed model could reasonably predict the SRV using the flowback data after fracturing. Additionally, compared with the microseismic data, the stress sensitivity should be included, especially in the abnormal overpressure block. It is believed that this mathematical model is accurate and useful. The work provides an efficient approach to estimate stimulated reservoir volume in the shale gas reservoirs.

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The impact of sulfur precipitation in developing a sour gas reservoir with pressure-sensitive effects

Cited by 9 publications

References 23 publications

Impacts of pore size distribution on gas injection in intraformational water zones in oil sands reservoirs

Impacts of pore size distribution on gas injection in intraformational water zones in oil sands reservoirs

Microscopic Mechanism and Percolation Model of Dynamic Deposition of Elemental Sulfur Particles in Acidic Gas Reservoirs

A Comprehensive Model for Estimating Stimulated Reservoir Volume Based on Flowback Data in Shale Gas Reservoirs

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