Inflow characteristics of horizontal wells in sulfur gas reservoirs: A comprehensive experimental investigation

Tan, Yamin; Li, Haitao; Zhou, Xiang; Wang, Ke; Jiang, Beibei; Zhang, Nan

doi:10.1016/j.fuel.2018.10.097

Cited by 15 publications

(7 citation statements)

References 31 publications

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“…Meanwhile, the CO 2 solubility obtained from Eqn ( 9) is in accordance with the experimental results in the range of 0-20 MPa, which shows that the model used in this paper is suitable for the prediction of the CO 2 solubility of brine in the Tahe oilfield. Figure 10 shows the dependence of the CO 2 sequestration capacity of the core on temperature and pressure obtained from Eqn (9). As shown in Fig.…”

Section: Co 2 Sequestration Capacity By Co 2 Solubility In Brine and ...mentioning

confidence: 99%

CO₂–Brine–rock interaction and sequestration capacity in carbonate reservoirs of the Tahe Oilfield, Xinjiang, China

Tan

et al. 2022

Greenhouse Gases

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The characteristics of each carbonate reservoir are greatly different, and current databases are insufficient to support engineering scheme design and optimization of carbon dioxide (CO2) sequestration and enhanced oil recovery. In this paper, the behavior of CO2‐brine‐rock interactions was investigated under supercritical CO2 (50°C and 8.5 MPa) conditions. Five experiments were carried out, including CO2 solubility in brine, mass loss analysis by static reaction of CO2–brine–rock, mineralogical composition analysis by X‐ray diffraction (XRD), core surface morphology analysis by scanning electron microscopy (SEM), and wettability alteration by contact angle analysis. The experimental results showed that: (a) the CO2 solubility in brine increases with increasing pressure, but it increases slowly and gradually reaches equilibrium; (b) the mass loss of carbonate increases with reaction time, but its increments decrease with reaction time; (c) the calcite content gradually decreases and the quartz content slightly increases with reaction time, as evidenced by XRD analysis; (d) based on SEM image analysis, calcite was dissolved into brine by carbonic acid to make the pores larger, and then subsequent precipitation made the pores smaller; and (e) the carbonate rock surface became more water‐wet after CO2–brine–rock interaction experiments due to surface corrosion and increased quartz content. Using the experimental results, a mathematical model was developed to predict CO2 sequestration capacity under reservoir conditions. The results suggest that CO2 solubility in brine was the main aspect compared with mineral trapping in carbonate reservoirs, and CO2 sequestration capacity increased with increasing temperature and pressure. © 2022 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Section: Co 2 Sequestration Capacity By Co 2 Solubility In Brine and ...mentioning

confidence: 99%

CO₂–Brine–rock interaction and sequestration capacity in carbonate reservoirs of the Tahe Oilfield, Xinjiang, China

Tan

et al. 2022

Greenhouse Gases

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“…Sulfur deposition is of great significance for the development of sour gas reservoirs. 6 Many scholars have been focusing on sulfur deposition, and the models of sulfur solubility in sour gas were developed. Kuo and Colsmann 7 built the model of elemental sulfur in porous media, and the influencing factors of the model are analyzed.…”

Section: Introductionmentioning

confidence: 99%

“…Elemental sulfur blocks pores, resulting in a decrease in porosity and permeability, and then the production of sour gas wells will be reduced. Sulfur deposition is of great significance for the development of sour gas reservoirs …”

Section: Introductionmentioning

confidence: 99%

Fractal Model for Predicting Elemental Sulfur Saturation in the Presence of Natural Fracture

Shao

Yang

et al. 2021

ACS Omega

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Sour gas reservoirs are an important part of unconventional gas reservoirs, which are widely distributed in the world. However, elemental sulfur deposition, channel plugging, and productivity reduction consequentially occur in the development of high sour gas fields as pressure drops. The accurate prediction of sulfur deposition is a very important work for sour gas reservoirs. In this paper, a fractal model is presented for predicting elemental sulfur saturation in the presence of natural fracture. The model takes into consideration the effects of non-Darcy flow. In addition, the influence parameters such as fractal dimension, fractal index, and non-Darcy flow are studied. The results showed the following: (1) sulfur deposition was overestimated by Hu’s model, and this paper model is more accurate for prediction of sulfur deposition; (2) elemental sulfur deposition decreases with the increase of the fractal dimension, while elemental sulfur deposition increases with the decrease of the fractal index; and (3) non-Darcy flow should be considered because it causes a faster rate of sulfur deposition. This research will provide a basis and reference for predicting elemental sulfur saturation in the presence of natural fracture for sour gas reservoirs.

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“…Zhai Lusheng studies the correction algorithm of liquid holdup in a static oil-water two-phase stratified flow (Lian et al, 2015). In recent years, many scholars have put forward some interpretation models for horizontal well production logging interpretation, such as the variable coefficient drift model by Lovick and Angeli and the Vedapuri threelayer flow model of an oil-water mixture (Tan et al, 2019). These also include Peebles and Garber's improved one horizontal well slippage speed calculation model (Li et al, 2018), the Harmthy slippage speed calculation model (Luo et al, 2015), Duckler's (Luo et al, 2020a) liquid gas correction model (Luo et al, 2020b), the Nicolas correction model (Yue et al, 2020), the Choquette correction model (Pang et al, 2020), the Abb deviated model (Xie et al, 2020), the Beggs and Brill model (Wu et al, 2020), the CTE slippage model (Jinghong et al, 2020), and the statistical model prediction split phase flow calculation method.…”

Section: Introductionmentioning

confidence: 99%

An Interpretation Model for the Production Profile on the Same Angle of a Horizontal Well Trajectory

2020

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An accurate interpretation of the fluid production profile is the essential scientific step required for the dynamic monitoring and management of a reservoir. Currently, an accurate interpretation of conventional logging is generally available for vertical wells. However, high-accuracy interpretation is still a blank for horizontal wells, especially for those wells with low production. Therefore, it is of great importance to develop a new model that can efficiently improve the interpretation accuracy of horizontal wells' production profiles. Practically, it was observed from experiments that, for multiphase flow in a horizontal well, the flow pattern changes significantly with the varied inclination angle along the well trajectory. This is because the flow pattern is critically related to the flow rate and the measured phase flow data (i.e., the production data of oil, gas, and water), which varies with the inclination angle along the horizontal well trajectory. Based on the above observations, a new methodology is proposed to interpret horizontal wells' production profiles with the same inclination angle. A comparison of the measured data and numerically calculated results indicates that the newly established method can significantly improve the interpretation accuracy of horizontal wells' production fluid profile. The interpretation method is, therefore, enriched by production logging for different types of wells. By comparing the experimentally measured data and the calculated results, the newly established method is indicated to be capable of significantly improving the interpretation accuracy of horizontal wells' fluid production profile. The interpretation method is further extended to production logging for different well types. By applying this new methodology, the main water-producing layer can be precisely identified to prevent and control the water burst from horizontal wells as well as the formation of water plugging. Consequently, oil and gas recovery can be effectively enhanced.

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Inflow characteristics of horizontal wells in sulfur gas reservoirs: A comprehensive experimental investigation

Cited by 15 publications

References 31 publications

CO₂–Brine–rock interaction and sequestration capacity in carbonate reservoirs of the Tahe Oilfield, Xinjiang, China

CO₂–Brine–rock interaction and sequestration capacity in carbonate reservoirs of the Tahe Oilfield, Xinjiang, China

Fractal Model for Predicting Elemental Sulfur Saturation in the Presence of Natural Fracture

An Interpretation Model for the Production Profile on the Same Angle of a Horizontal Well Trajectory

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Inflow characteristics of horizontal wells in sulfur gas reservoirs: A comprehensive experimental investigation

Cited by 15 publications

References 31 publications

CO2–Brine–rock interaction and sequestration capacity in carbonate reservoirs of the Tahe Oilfield, Xinjiang, China

CO2–Brine–rock interaction and sequestration capacity in carbonate reservoirs of the Tahe Oilfield, Xinjiang, China

Fractal Model for Predicting Elemental Sulfur Saturation in the Presence of Natural Fracture

An Interpretation Model for the Production Profile on the Same Angle of a Horizontal Well Trajectory

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CO₂–Brine–rock interaction and sequestration capacity in carbonate reservoirs of the Tahe Oilfield, Xinjiang, China

CO₂–Brine–rock interaction and sequestration capacity in carbonate reservoirs of the Tahe Oilfield, Xinjiang, China