A Gas Kick Model that Uses the Thermodynamic Approach to Account for Gas Solubility in Synthetic-based Mud

2021 ◽  
Author(s):  
Kaushik Manikonda ◽  
Abu Rashid Hasan ◽  
Nazmul H. Rahmani ◽  
Omer Kaldirim ◽  
Chinemerem Edmond Obi ◽  
...  
Keyword(s):  
Liquid Phase ◽  
Mole Fraction ◽  
Drilling Fluid ◽  
Mechanistic Model ◽  
Simulation Software ◽  
Thermodynamic Approach ◽  
Complete Agreement ◽  
Gas Solubility ◽  
Gas Kick ◽  
Solubility Model

Abstract This paper presents a rigorous, mechanistic model for simulating a gas kick, that uses the thermodynamic approach to account for gas solubility. This thermodynamic solubility model uses the pressure and temperature data from the kick simulations and estimates the mole fraction of various gas components in the liquid phase. We validated these gas solubility results using Aspen HYSYS, a commercial chemical process simulation software. The thermodynamic solubility model presented in this paper assumes a pure-methane kick and applies the concepts of phase-equilibrium and fugacity to estimate the amount of dissolved gas in the drilling fluid. Application of fugacity equilibrium between the gas and liquid phases, in conjunction with the Peng-Robinson equation, gives the liquid phase mole fraction of methane. The analytical kick model uses the Hasan-Kabir two-phase flow modeling approach to describes the changes in pressure during kick migration, at various points in the annulus. Since the expansion of the gas bubbles depends on the variation in pressure, these studies also lead to pit gain estimates. A comparison between our model results and HYSYS values for methane liquid-phase mole fraction showed a maximum 8% deviation with complete agreement on bubble point (Pb) pressure and location estimates. Similarly, our model calculated the solution gas-oil ratio (Rs), with a maximum divergence of 3% from HYSYS estimates. From the comparison studies with other empirical Bo & Rs correlations, we note that the estimates of our model agreed best with those of O’Bryan’s (O'Bryan 1988) correlations. Many numerical kick simulators exist today, but they are notoriously time-consuming, limiting their on-field utility. Our kick simulator’s simplicity makes it potentially useful for on-field well control decisions. Most of these existing numerical simulators ignore the effects of kick solubility in synthetic-based muds. In the few models that do not ignore solubility, the approach to accounting for gas solubility and mud swelling is empirical, limiting their usage under conditions beyond the range of the source data used in developing these correlations. The mud swelling calculation approach we developed does not have these pressure and temperature range limitations.

Estimating Swelling in Oil-Based Mud due to Gas Kick Dissolution

2020 ◽  
Author(s):  
Kaushik Manikonda ◽  
Abu Rashid Hasan ◽  
Omer Kaldirim ◽  
Nazmul Rahmani ◽  
Mohammad Azizur Rahman
Keyword(s):  
Liquid Phase ◽  
Natural Gas ◽  
Drilling Fluid ◽  
Binary Interaction ◽  
Drilling Fluids ◽  
Gas Solubility ◽  
Interaction Coefficients ◽  
Volume Factor ◽  
Cubic Form ◽  
Gas Kick

Abstract Gas kick is an ever-present hazard whose importance is magnified for offshore drilling situations. Modeling gas kick is a complex problem that requires an understanding of the relevant fluid dynamics as well as the solubility of natural gas in oil-based muds (OBM). Drilling fluid swelling due to natural gas solubility in OBM significantly affects the extent of pit gain — one of the primary indicators of a kick in progress. This paper specifically addresses the issue of drilling fluid swelling from gas dissolution in OBM. Drilling fluid swelling due to gas dissolution is generally expressed the same way as oil swelling due to dissolved gas, by the volume factor, Bo. Many correlations for estimating Bo as a function of temperatures and pressures are available. We have developed a rigorous thermodynamic approach for estimating Bo. Our approach uses the Peng-Robison (1976) equation of state (EOS), van der Waals mixing rules, and binary interaction coefficients appropriate for drilling fluids to account for gas solubility. Solving the cubic form of the Peng-Robinson EOS yields a z-factor for the liquid phase of the mixture. The model uses this z-factor to estimate the liquid-phase volume of dissolved methane and, consequently, Bo. This paper validates the results of estimated Bo from this method with volume factor calculations obtained from Aspen HYSYS. Finally, this paper also presents a section where the methane mole fraction data at different P&T conditions, obtained from HYSYS simulations, is used to validate the solubility model previously developed by Manikonda et al. (2019).

Phase diagram for ethylene glycol and triethylamine

1967 ◽  
Vol 20 (7) ◽  
pp. 1343
Author(s):  
EL Davids ◽  
TJV Findlay
Keyword(s):  
Carbon Dioxide ◽  
Phase Diagram ◽  
Liquid Phase ◽  
Ethylene Glycol ◽  
Mole Fraction ◽  
Consolute Temperature

The liquid-liquid phase diagram for ethylene glycol and triethylamine has been determined. This mixture has a lower consolute temperature of 57.7 � 0.1� at 0.45 � 0.1 mole fraction triethylamine. Both carbon dioxide and water lower the lower consolute temperature. The densities and viscosities of solutions just below the lower consolute temperature do not exhibit any abnormalities.

scholarly journals Study on Liquid Phase Hydrogenation Technology of White Oil

2021 ◽  
Vol 6 (1) ◽  
Author(s):  
Tiezhen Zhang ◽  
◽  
Famin Sun ◽  
Yungang Jia ◽  
Fangming Xie ◽  
...  
Keyword(s):  
Liquid Phase ◽  
Raw Materials ◽  
Copper Plate ◽  
Simulation Software ◽  
Quality Requirements ◽  
Food Grade ◽  
Ultraviolet Absorbance ◽  
Liquid Phase Hydrogenation ◽  
The Stability ◽  
Aromatic Hydrogen

Using Aspen Plus simulation software to simulate the hydrogen solubility of white oil raw materials, and calculate the de-aromatic hydrogen consumption. The liquid hydrogenation technology of white oil was studied by using 100mL uplink liquid hydrogenation evaluation device. The research results show that the ultraviolet absorbance of the liquid phase hydrogenation product is no more than 0.1, and saybolt color, copper plate corrosion, readily carbonizable substance can meet the quality requirements under the conditions of 230℃, 17 Mpa and LHSV 0.5 h-1. 2000 hours liquid phase hydrogenation test shows the stability of product quality which meets the food grade standard, and the liquid phase hydrogenation technology is feasible.

scholarly journals Numerical Investigation on Gas Accumulation and Gas Migration in the Wavy Horizontal Sections of Horizontal Gas Wells

2020 ◽  
Vol 2020 ◽  
pp. 1-9
Author(s):  
Yi Huang ◽  
Jin Yang ◽  
Lingyu Meng ◽  
Xuyue Chen ◽  
Ming Luo ◽  
...  
Keyword(s):  
Fluid Flow ◽  
Flow Velocity ◽  
Vertical Section ◽  
Drilling Fluid ◽  
Gas Migration ◽  
Gas Wells ◽  
Gas Well ◽  
Gas Accumulation ◽  
Fluid Flow Velocity ◽  
Gas Kick

Wavy horizontal sections are typically encountered in horizontal gas wells, which will result in gas accumulation on top of the wavy horizontal sections. This gas accumulation can be a problem and may trigger gas kick or blowout accident while tripping and pulling this gas into the vertical section. In this paper, a numerical model for gas accumulation and gas migration in the wavy horizontal sections of the horizontal gas well is developed; meanwhile, the gas accumulation and gas migration process is numerically investigated. The results show that the gas exhausting time in the wavy horizontal section increases with the increase of the wellbore curvature and the critical drilling fluid flow velocity for gas exhausting increases with the increase of the wellbore curvature. When the drilling fluid flow velocity is higher than the critical drilling fluid flow velocity for gas exhausting, no gas accumulation will occur. With all other parameter values set constant, the number of the wavy horizontal sections has a great effect on the gas-liquid flow pattern while it has little effect on the efficiency of the gas exhausting. This work provides drilling engineers with a practical tool for designing the drilling fluid flow velocity to avoid gas kick or blowout accident in horizontal gas well drilling.

scholarly journals A Flow-Dependent Fiber Orientation Model

2020 ◽  
Vol 4 (3) ◽  
pp. 96
Author(s):  
Susanne Katrin Kugler ◽  
Argha Protim Dey ◽  
Sandra Saad ◽  
Camilo Cruz ◽  
Armin Kech ◽  
...  
Keyword(s):  
Fiber Orientation ◽  
Mechanical Performance ◽  
Mechanistic Model ◽  
Elongational Flow ◽  
Simulation Software ◽  
Fiber Reinforced Polymers ◽  
Macroscopic Model ◽  
Fluid Viscosity ◽  
Fiber Reinforced ◽  
Elongational Flows

The mechanical performance of fiber reinforced polymers is dependent on the process-induced fiber orientation. In this work, we focus on the prediction of the fiber orientation in an injection-molded short fiber reinforced thermoplastic part using an original multi-scale modeling approach. A particle-based model developed for shear flows is extended to elongational flows. This mechanistic model for elongational flows is validated using an experiment, which was conducted for a long fiber reinforced polymer. The influence of several fiber descriptors and fluid viscosity on fiber orientation under elongational flow is studied at the micro-scale. Based on this sensitivity analysis, a common parameter set for a continuum-based fiber orientation macroscopic model is defined under elongational flow. We then develop a novel flow-dependent macroscopic fiber orientation, which takes into consideration the effect of both elongational and shear flow on the fiber orientation evolution during the filling of a mold cavity. The model is objective and shows better performance in comparison to state-of-the-art fiber orientation models when compared to μCT-based fiber orientation measurements for several industrial parts. The model is implemented using the simulation software Autodesk Moldflow Insight Scandium® 2019.

Well Control Technology of High Temperature and High Pressure with Different Well Shapes

2013 ◽  
Vol 316-317 ◽  
pp. 860-866
Author(s):  
Yan Jun Li ◽  
Xiang Nan He ◽  
Xiao Wei Feng ◽  
Ya Qi Zhang ◽  
Ling Wu ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Drilling Fluid ◽  
Control Process ◽  
Formation Pressure ◽  
Well Drilling ◽  
Well Control ◽  
Direct Invasion ◽  
Bottom Hole ◽  
Gas Kick

Well control safe is the prerequisite of safety drilling, especially for high temperature and high pressure horizontal wells. However, there are few papers about well control of horizontal well drilling, which mostly learn from vertical well control process. By means of analysis of the theory of gas kick, we conclude that underbalance, the bottom hole pressure is less than the formation pressure is the main means of gas invasion. During balance period, the gas also intrudes into wellbore through the way of direct invasion, diffusion invasion and replacement invasion, but the amount of gas kick is less, so the risk of well control is small. This paper also anlyses the kick tolerance, the kick tolerance decreases with the increasing of drilling fluid density when the formation pressure and drilling equipment is constant.

Considerations for Hydrodynamic Slug Analysis in Pipelines

2014 ◽  
Author(s):  
Daniela Galatro ◽  
Daniel Fürtbauer ◽  
Xiangyu Hu ◽  
David-Emilio Nerucci ◽  
Flavio Marín
Keyword(s):  
Steady State ◽  
Slip Velocity ◽  
Mechanistic Model ◽  
Simulation Software ◽  
Transient Simulation ◽  
First Approximation ◽  
Elevation Changes ◽  
Relative Errors ◽  
Superficial Gas Velocity ◽  
Made In

Hydrodynamic slugs in pipelines are usually analyzed by using a steady-state flow assurance simulator as a first approximation. The pipelines are then modeled in transient simulation software to get more accurate values. Comparisons between an empirical and a mechanistic method are made in this work by running simulations in steady-state simulators in order to explain the differences in the calculated slug properties. It has been demonstrated that both methods cannot accurately estimate the maximum slug length in pipelines since the relative errors are significant; nevertheless the mechanistic model is more accurate than the empirical one with lower relative errors. Additionally, slug sizes for operational slugging have been analyzed by using a new alternative pseudo transient approach to the Lagrangian slug tracking scheme. The model expresses an unsteady state mass balance in a pipeline, formulated utilizing the slip velocity written in terms of the void fraction and superficial gas velocity. Our model includes a constitutive equation for slip velocity, elevation changes to represent the hydraulic profile of the pipeline, a method for the calculation of the maximum slug length, a modified correlation for the slug length calculation and the variation of the fluid density along the pipeline profile. The results yielded by this model have been compared with field data and results performed by using a transient simulation software, showing fairly accurate values.

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