Modeling Hydrate Dissociation Curves in the Presence of Hydrate Inhibitors with a Modified CPA EoS

Palma, André M.; Queimada, António J.; Coutinho, João A. P.

doi:10.1021/acs.iecr.9b03512

Cited by 7 publications

(4 citation statements)

References 47 publications

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“…21 An overview of the accuracy of this model, as used in this work, to represent hydrate dissociation curves for many common hydrate formers with and without inhibitors is available from the literature. 6,7 The effect of salts on the solubility of gases and gas hydrate formation was modeled using the Debye−Huckel theory, virial corrections, and Born terms. The basic principle of the electrolyte model applied to this study is similar to many published models that can be found in the literature.…”

Section: Modelsmentioning

confidence: 99%

“…Hydrates were modeled with the solid solution theory of Platteeuw and van der Waals, as developed by Parrish and Prausnitz . An overview of the accuracy of this model, as used in this work, to represent hydrate dissociation curves for many common hydrate formers with and without inhibitors is available from the literature. , …”

Section: Modelsmentioning

confidence: 99%

“…Hydrate formation is a well-known flow assurance problem in the oil and gas industry. , Hydrates can reduce output or completely damage a pipeline in extreme situations. Therefore, the industry scrutinizes the conditions of hydrate formation in pipelines and often uses hydrate inhibitors to ensure no risk of hydrate formation.…”

Section: Introductionmentioning

confidence: 99%

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Effect of Salts, Impurities, and Low Water Contents in the Formation of Gas Hydrates in CO₂-Rich Streams

Queimada,

Zhang,

Pedrosa

et al. 2024

J. Chem. Eng. Data

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Carbon capture utilization and storage (CCUS) together with natural gas production from high CO 2 -containing reservoirs has raised attention to the formation of CO 2 -rich gas hydrates. These gas mixtures can contain impurities such as Ar, O 2 , N 2 , H 2 , NxOy, CO, H 2 S, SO 2 , or mercury, some of which are also hydrate formers or potential corrosion enhancers. This paper addresses the use of thermodynamic models to predict the phase behavior of CO 2 -rich streams. It starts from the overall binary phase equilibria of CO 2 with water. Then, gas hydrates and the effect of different impurities on the hydrate phase behavior are observed. Furthermore, the effect of salts on CO 2 solubility and the influence of inhibitors such as salts on CO 2 hydrate suppression are analyzed. For modeling hydrates, the solid solution theory of van der Waals and Platteeuw, as implemented by Parrish and Prausnitz, is used coupled with the Cubic-Plus-Association equation of state (CPA EoS) for representing the fluid phases. The influence of electrolytes on hydrate formation and CO 2 solubility in brines is modeled with an add-on electrolyte term based on the Debye−Huckel theory. The main objective of this Perspective is to consider all possible phase equilibria simultaneously, as in CCUS applications we cannot detach the different phase equilibria conditions. The results demonstrate that the selected models can accurately represent the phase behavior of CO 2 -rich streams and the effect of salts and impurities on gas hydrate formation.

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Section: Modelsmentioning

confidence: 99%

Section: Modelsmentioning

confidence: 99%

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Effect of Salts, Impurities, and Low Water Contents in the Formation of Gas Hydrates in CO₂-Rich Streams

Queimada,

Zhang,

Pedrosa

et al. 2024

J. Chem. Eng. Data

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“…The generated dataset can be arbitrarily large and the data itself is noise-free as it is generated by a thermodynamically consistent method such as the solids thermodynamic model implemented in the HydraFLASH software that is integrated into Prosper. For a given acid gas mixture, HydraFLASH uses the multiphase equilibrium algorithm by Michelsen [50], the van der Waals and Platteeuw theory and the CPA EoS [51] to predict the hydrate dissociation curve for the acid gas mixture of interest.…”

Section: Classification Models Inputmentioning

confidence: 99%

Rapid Hydrate Formation Conditions Prediction in Acid Gas Streams

Samnioti,

Kanakaki,

Fotias

et al. 2023

Fluids

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Sour gas in hydrocarbon reservoirs contains significant amounts of H2S and smaller amounts of CO2. To minimize operational costs, meet air emission standards and increase oil recovery, operators revert to acid gas (re-)injection into the reservoir rather than treating H2S in Claus units. This process requires the pressurization of the acid gas, which, when combined with low-temperature conditions prevailing in subsurface pipelines, often leads to the formation of hydrates that can potentially block the fluid flow. Therefore, hydrates formation must be checked at each pipeline segment and for each timestep during a flow simulation, for any varying composition, pressure and temperature, leading to millions of calculations that become more intense when transience is considered. Such calculations are time-consuming as they incorporate the van der Walls–Platteeuw and Langmuir adsorption theory, combined with complex EoS models to account for the polarity of the fluid phases (water, inhibitors). The formation pressure is obtained by solving an iterative multiphase equilibrium problem, which takes a considerable amount of CPU time only to provide a binary answer (hydrates/no hydrates). To accelerate such calculations, a set of classifiers is developed to answer whether the prevailing conditions lie to the left (hydrates) or the right-hand (no hydrates) side of the P-T phase envelope. Results are provided in a fast, direct, non-iterative way, for any possible conditions. A set of hydrate formation “yes/no” points, generated offline using conventional approaches, are utilized for the classifier’s training. The model is applicable to any acid gas flow problem and for any prevailing conditions to eliminate the CPU time of multiphase equilibrium calculations.

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Study of the kinetic behavior of chemical inhibitors in calcium carbonate scale formation

Lobo

Serpa

Filho

et al. 2023

Braz. J. Chem. Eng.

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Modeling Hydrate Dissociation Curves in the Presence of Hydrate Inhibitors with a Modified CPA EoS

Cited by 7 publications

References 47 publications

Effect of Salts, Impurities, and Low Water Contents in the Formation of Gas Hydrates in CO₂-Rich Streams

Effect of Salts, Impurities, and Low Water Contents in the Formation of Gas Hydrates in CO₂-Rich Streams

Rapid Hydrate Formation Conditions Prediction in Acid Gas Streams

Study of the kinetic behavior of chemical inhibitors in calcium carbonate scale formation

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Modeling Hydrate Dissociation Curves in the Presence of Hydrate Inhibitors with a Modified CPA EoS

Cited by 7 publications

References 47 publications

Effect of Salts, Impurities, and Low Water Contents in the Formation of Gas Hydrates in CO2-Rich Streams

Effect of Salts, Impurities, and Low Water Contents in the Formation of Gas Hydrates in CO2-Rich Streams

Rapid Hydrate Formation Conditions Prediction in Acid Gas Streams

Study of the kinetic behavior of chemical inhibitors in calcium carbonate scale formation

Contact Info

Product

Resources

About

Effect of Salts, Impurities, and Low Water Contents in the Formation of Gas Hydrates in CO₂-Rich Streams

Effect of Salts, Impurities, and Low Water Contents in the Formation of Gas Hydrates in CO₂-Rich Streams