Gas kick simulation in oil-based drilling fluids with the gas solubility effect during high-temperature and high-pressure well drilling

Xu, Zhengming; Song, Xianzhi; Li, Gensheng; Zhu, Zhaopeng; Zhu, Bo

doi:10.1016/j.applthermaleng.2018.12.110

Cited by 41 publications

(13 citation statements)

References 47 publications

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“…a certain well depth. And the temperature also has a significant effect on the fluid properties (Xu et al, 2019). Therefore, before solving the mass and momentum equations, we must solve the transient temperature prediction model.…”

Section: Model Couplingmentioning

confidence: 99%

“…Their model has also been used to study the phase transition of hydrate during the exploitation of natural gas hydrate Sun, 2009, 2014). Xu et al (2018Xu et al ( , 2019 developed a non-isothermal two-phase flow model to investigate the effect of major parameters on the two-phase flow behavior in the wellbore. They found that temperature, pressure, and solubility fields are mutually influential.…”

Section: Introductionmentioning

confidence: 99%

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Dynamical well-killing simulation of a vertical H₂S-containing natural gas well

Mao

Cai

Liu

et al. 2020

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

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This work aims to explore the dynamical well-killing process of a vertical H2S-containing natural gas well. A dynamical well-killing model considering an H2S solubility was established to simulate the overflow and well-killing process of a vertical H2S-containing natural gas well. The mass and momentum equations of the coupled model were solved using finite difference method, while the transient temperature prediction model was solved using finite volume method. The coupled model was validated by reproducing experimental data and field data of Well Tiandong #5. The effect of H2S content, mud displacement, drilling fluid density, and initial overflow volume on the dynamical well-killing process of an H2S-containing natural gas well were obtained and analyzed in this work. Results showed that H2S will gasify near wellhead during well killing when casing pressure decreases. To balance the bottom hole pressure, when H2S releases, the casing pressure increases as H2S content increases. As initial overflow volume increases, the annular temperature, annular pressure and the casing pressure increase significantly. When H2S gasifies, the casing pressure applied at wellhead should be higher at lower initial overflow volume to balance bottom hole pressure. In the well-killing process, the annular pressure and temperature decrease as drilling fluid density increases and a lower casing pressure is needed for balancing bottom hole pressure. The casing pressure is lower at a higher displacement for higher friction resistance. Besides, as well-killing displacement increases H2S will gasify at an earlier time. When drilling for H2S-containing natural gas well, early detection of gas kick should be more frequent to avoid severe overflow. Besides, higher displacement and density of drilling fluid should be considered to avoid stratum fracturing and prevent leakage accidents under the premise of meeting drilling requirements.

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Section: Model Couplingmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Dynamical well-killing simulation of a vertical H₂S-containing natural gas well

Mao

Cai

Liu

et al. 2020

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

View full text Add to dashboard Cite

show abstract

“…Figure shows the physics model of gas‐phase mass conservation. According to the law of mass conservation, the change in the mass of control unit is the incoming mass of the control unit minus the outgoing mass . For gas phase, the incoming mass of the control unit is:

ρ_{normalg} v_{normalg} E_{normalg} A d t + false(q_{{normalH}_{2}_{normalS}} + q_{g} false) d t d z,

…”

Section: Multiphase Flow Modelmentioning

confidence: 99%

“…They found that temperature, pressure, and solubility fields are mutually influential. The gas solubility effect and heat transfer effect influence gas kick characteristics significantly . Yang et al developed a transient hydro‐thermo‐bubble model for gas kick simulation in deepwater drilling based on oil‐based mud and found that the mass transfer, heat transfer, and bubble‐bubble interaction are mutually coupled.…”

Section: Introductionmentioning

confidence: 99%

Research on dynamical overflow characteristics of a vertical H₂S‐containing natural gas well

Mao

Cai

Liu

et al. 2019

Energy Science & Engineering

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This work aims to explore the overflow characteristics of a vertical H2S‐containing natural gas well. A two‐phase flow model for H2S‐containing natural gas well combining with a transient temperature prediction model was established to simulate the overflow process of a vertical H2S‐containing natural gas well. The model was validated by reproducing the field data of Well Longhui #2. The effects of H2S content, mud displacement, drilling fluid density, geothermal gradient, and reservoir permeability on the overflow characteristics of a vertical H2S‐containing natural gas well were studied and analyzed in this work. Results indicate that bubble, slug, and churn flows constitute the main flow patterns in the whole overflow process. The higher the H2S content is, the more obviously the gas void fraction increases. The phase change position of H2S is closer to the wellhead at lower H2S content. An increase in mud displacement indicates the decreases in overflow time. As drilling fluid density increases, the release position of H2S moves up, and the overflow time and shut‐in casing pressure increase. The initial gas void fraction is higher and the gas invasion volume will be larger in gas reservoirs with higher permeability. As the reservoir permeability increases, the shut‐in casing pressure rises while the overflow time declines. With higher geothermal gradient, the wellbore temperature tends to be higher at the same depth, leading to an increase in the H2S solubility. The gasification starting position is further away from the wellhead at higher geothermal gradient. The results of this work could provide important theoretical basis and technical guidance for drilling engineers to reduce a blowout risk during drilling of H2S‐containing natural gas well.

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“…Xu et al (2018) used the standing bubble point formula to calculate the solubility of gas in oil. Neglecting the gas dissolution effect, the bottom-hole temperature was overestimated by 3.74 °C, and the bottomhole pressure increased by 2.92 MPa [14].…”

Section: Introductionmentioning

confidence: 97%

Study on flow characteristics of natural gas containing CO2 invading wellbore during drilling

Sun²,

Sun³

et al. 2022

Front. Phys.

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The dissolution of invaded gas in the drilling fluid during drilling results in an increase in the gas invasion concealment. This is of great significance for the development of acid gas reservoirs to determine the solubility change and multiphase flow law in an annulus after invasion by natural gas with high CO2 content. In this study, control equations of gas–liquid flow during drilling gas invasion are established considering the influence of gas solubility. For the prediction of gas solubility, the interaction parameters of CH4 and water in the Peng–Robinson equation of state are optimised to establish a gas solubility prediction model. The solubility of natural gas with high CO2 content in water and brine solution is measured through phase-equilibrium experiments. The results indicate that the newly optimised solubility model can accurately predict the solubility of CH4 and CO2 in water, and the prediction error is within 5%. Moreover, the prediction error for the solubility of CH4 and CO2 mixed gas is within 15%. The analysis of gas invasion in example engineering drilling applications reveals that an increase in the CO2 content in the invaded gas leads to a slow change in the mud-pit increment, and the concealment strengthens as the distance between the gas-migration front and the wellhead increases. Gas solubility has a significant impact on the monitoring of gas invasion in low permeability reservoirs.

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Gas kick simulation in oil-based drilling fluids with the gas solubility effect during high-temperature and high-pressure well drilling

Cited by 41 publications

References 47 publications

Dynamical well-killing simulation of a vertical H₂S-containing natural gas well

Dynamical well-killing simulation of a vertical H₂S-containing natural gas well

Research on dynamical overflow characteristics of a vertical H₂S‐containing natural gas well

Study on flow characteristics of natural gas containing CO2 invading wellbore during drilling

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Gas kick simulation in oil-based drilling fluids with the gas solubility effect during high-temperature and high-pressure well drilling

Cited by 41 publications

References 47 publications

Dynamical well-killing simulation of a vertical H2S-containing natural gas well

Dynamical well-killing simulation of a vertical H2S-containing natural gas well

Research on dynamical overflow characteristics of a vertical H2S‐containing natural gas well

Study on flow characteristics of natural gas containing CO2 invading wellbore during drilling

Contact Info

Product

Resources

About

Dynamical well-killing simulation of a vertical H₂S-containing natural gas well

Dynamical well-killing simulation of a vertical H₂S-containing natural gas well

Research on dynamical overflow characteristics of a vertical H₂S‐containing natural gas well