Deepwater gas kick simulation

Avelar, Carolina; Ribeiro, Paulo Leonardo Lima; Sepehrnoori, Kamy

doi:10.1016/j.petrol.2009.03.001

Cited by 78 publications

(55 citation statements)

References 4 publications

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“…Taking the derivative of the third equation of (22), multiplying by u t , and integrating in space over [0,1] we get…”

Section: We Multiply the Equation By H θ−2 ([Hq]mentioning

confidence: 99%

“…This work is devoted to a study of a one-dimensional twophase model of the drift-flux type. The model is frequently used in industry simulators to simulate unsteady, compressible flow of liquid and gas in pipes and wells [1,2,3,6,14,10,18,21]. The model consists of two mass conservation equations corresponding to each of the two phases gas (g) and liquid (l) and one equation for the conservation of the momentum of the mixture and is given in the following form:…”

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confidence: 99%

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Genuine Two-Phase Flow Dynamics with a Free Interface Separating Gas-Liquid Mixture from Gas

Evje¹

2013

SIAM J. Math. Anal.

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Abstract. In this work we deal with the no-slip drift-flux model for gas-liquid flow dynamics. We focus on a situation where there is a free interface separating the gas-liquid mixture from a pure gas region which takes a positive pressure p * . This situation is highly relevant for gas-liquid flow in the context of wellbore operations. Previous works have assumed that there is vacuum, i.e., the pressure p * is zero. The positive pressure p * > 0 creates a boundary term that must be treated in a consistent manner throughout the analysis. We derive time-independent estimates and make some observations related to the role played by p * . The estimates allow us to discuss the long-time behavior of the two-phase flow system. In particular, it is shown that the stationary solution connecting the gas-liquid mixture to the pure gas region with the specified pressure p * in a continuous manner is asymptotically stable for sufficiently small initial perturbations. The analysis clearly shows how this perturbation directly depends on the size of the outer pressure p * . A higher pressure p * allows for larger initial perturbations from steady state. One ingredient in the analysis is the rate at which the liquid mass decays to zero at the free interface. Insight into mechanisms that control the decay rate of the liquid mass at the free interface is also of interest since such transition zones often are associated with instabilities in numerical discretizations of two-phase models.

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“…Taking the derivative of the third equation of (22), multiplying by u t , and integrating in space over [0,1] we get…”

Section: We Multiply the Equation By H θ−2 ([Hq]mentioning

confidence: 99%

mentioning

confidence: 99%

Genuine Two-Phase Flow Dynamics with a Free Interface Separating Gas-Liquid Mixture from Gas

Evje¹

2013

SIAM J. Math. Anal.

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“…If the pressure in a section drops below the pore pressure, formation gas may leak into the well. This is called a kick and has to be handled with care in order to avoid a blow-out situation [1]. In this context P w corresponds to the given fracture pressure or pore pressure.…”

Section: Introductionmentioning

confidence: 99%

“…The key point leading to this result is the possibility to obtain sufficient pointwise control on the gas mass n and total mass ρ, upper as well as lower limits. More precisely, by assuming initially that the gas mass n and liquid mass m (i.e., liquid mass m = ρ − n) do not disappear or blow up on [0,1], that is,…”

Section: Introductionmentioning

confidence: 99%

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A Compressible Two-Phase Model with Pressure-Dependent Well-Reservoir Interaction

Evje¹

2013

SIAM J. Math. Anal.

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Abstract. This paper deals with a two-phase compressible gas-liquid model relevant for modeling of gas-kick flow scenarios in oil wells. To make the model more realistic we include a natural pressure-dependent well-formation interaction term allowing for modeling of dynamic gas influx/efflux. More precisely, the interaction between well and surrounding formation is controlled by a term of the form A = qw(Pw − P ) which appears in the gas continuity equation where qw is a rate constant, and Pw is a critical pressure, whereas P is pressure in the well. Consequently, an additional coupling mechanism is added to the mass and momentum equations. We obtain a global existence result for the new model. One consequence of the existence result is that as long as the well initially is filled with a mixture of gas and liquid, the system will regulate itself (in finite time) in such a way that there does not exist any point along the well where all the gas vanishes, e.g., by escaping into the formation. Similarly, the result guarantees that neither will any pure gas region appear in finite time, despite that gas is free to enter the well from the formation as long as the well pressure P is lower than the critical pressure Pw.

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Experimental study on the dissolution characteristics of ethane into oil‐based mud in complex oil and gas wellbore environments

Xuncheng,

Yongwang,

Hongqiang

et al. 2024

Energy Science & Engineering

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Accurately determining the solubility of ethane in oil‐based mud is crucial for assessing the severity of gas kicks and implementing appropriate well control procedures. The key factors influencing the solubility of ethane gas in oil‐based drilling fluids include the content of base oil, pressure, temperature, and the viscosity of the drilling fluid. This study aims to test the solubility of high‐purity ethane in oil‐based mud under simulated downhole conditions in a 5000 m deep well. The test covers a temperature range of 40–140°C and a partial pressure range of 0.17–5.92 MPa. The effects of temperature, pressure, base oil content, and drilling fluid viscosity on the solubility of ethane are analyzed using various experimental data processing methods. The results show that the variation in ethane solubility with pressure and temperature is nearly linear within the specified ranges. Furthermore, the impact of pressure (1.24–2.78%/MPa) on solubility is approximately 50 times greater than that of temperature (−0.013 to −0.049%/°C) in oil‐based drilling mud. Additionally, ethane's solubility decreases as the drilling fluid's viscosity increases. The ethane solubility in 80% and 90% oil‐based muds is roughly 1.6 times and 2.0 times higher than in 70% oil‐based mud under the same testing conditions. Models for predicting ethane solubility have been developed using screening procedures and statistical regression. These models can be incorporated into gas–liquid flow models to analyze flow behavior during gas kicks.

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Deepwater gas kick simulation

Cited by 78 publications

References 4 publications

Genuine Two-Phase Flow Dynamics with a Free Interface Separating Gas-Liquid Mixture from Gas

Genuine Two-Phase Flow Dynamics with a Free Interface Separating Gas-Liquid Mixture from Gas

A Compressible Two-Phase Model with Pressure-Dependent Well-Reservoir Interaction

Experimental study on the dissolution characteristics of ethane into oil‐based mud in complex oil and gas wellbore environments

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