Simulation of acid gas removal unit using DIPA+TEA amine solvent

Ramli, Raihan Mahirah; Lock, S S M; Hussein, N; Farooqi, A S; Wajahat, S M

doi:10.1088/1757-899x/1257/1/012033

Cited by 4 publications

(3 citation statements)

References 12 publications

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“…The reason might be that fewer chemical reactions occur in high physical solvent concentrations. Less energy was required to break the bond between acid gases and amines in the stripping column. , …”

Section: Resultsmentioning

confidence: 99%

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Removal of Carbon Dioxide and Hydrogen Sulfide from Natural Gas Using a Hybrid Solvent of Monoethanolamine and N-Methyl 2-Pyrrolidone

Farooqi,

Ramli,

Lock

et al. 2024

ACS Omega

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The main goal of traditional methods for sweetening natural gas (NG) is to remove hydrogen sulfide (H 2 S) and significantly lower carbon dioxide (CO 2 ). However, when NG processes are integrated into the carbon capture and storage (CCS) framework, there is potential for synergy between these two technologies. A steady-state model utilizing a hybrid solvent consisting of N-methyl-2-pyrrolidone (NMP) and monoethanolamine (MEA) has been developed to successfully anticipate the CO 2 and H 2 S capture process from NG. The model was tested against important variables affecting process performance. This article specifically explores the impact of operational parameters such as lean amine temperature, absorber pressure, and amine flow rate on the concentrations of CO 2 and H 2 S in the sweet gas and reboiler duty. The result shows that hybrid solvents (MEA + NMP) perform better in removing acid gases and reducing reboiler duty than conventional chemical solvent MEA. The primary purpose is to meet product requirements while consuming the least energy possible, which is in line with any process plant's efficiency goals.

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Section: Resultsmentioning

confidence: 99%

“…Less energy was required to break the bond between acid gases and amines in the stripping column. 53 , 54 …”

Section: Resultsmentioning

confidence: 99%

Removal of Carbon Dioxide and Hydrogen Sulfide from Natural Gas Using a Hybrid Solvent of Monoethanolamine and N-Methyl 2-Pyrrolidone

Farooqi,

Ramli,

Lock

et al. 2024

ACS Omega

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“…Sulfinol, a combination of DIPA, tetramethylene sulfone, and H2O was the first mixed solvent employed. MDEA eventually substituted DIPA, and the solvent was renamed Sulfinol-M [11].…”

Section: Introductionmentioning

confidence: 99%

Absorption of acid gases (CO2, H2S) from natural gas using a ternary blend of N-methyldiethanolamine (MDEA), 2-amino-2-methyl-1-propanol (AMP), and Sulfolane

2023

Sustainable Processes and Clean Energy Transition

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Abstract. Natural gas (NG) must be treated to remove sulphur compounds and acid gases i.e., carbon dioxide (CO2) and hydrogen sulfide (H2S) to ensure that it complies with requirements for sale and transportation. More than 95% of the NG processing plants are operated through the acid gas removal unit (AGRU) using aqueous amine solvent in removing sour gas components from the hydrocarbon gas due to the availability of amine solvent at a low cost. However, the main limitation of this process is the high operating cost of providing sufficient thermal energy at the reboiler for solvent regeneration. Meanwhile, the reboiler duty requirement generally increases with the requirement of CO2 removal efficiency as higher energy consumption is required to strip off a more significant amount of CO2 from the rich solvent. This current study addresses the absorption performance of acid gases using ternary hybrid solvents of MDEA, AMP, and Sulfolane. A study on the effects of solubility on H2S and CO2 absorption was performed at varying pressure (1000-6000 kPa) and temperatures (25°C-50°C) using Aspen HYSYS®V12.1. The results revealed that the concentration of CO2 and H2S in sweet gas increased with the decrease in pressure, while increasing temperature increased the concentration of H2S and CO2 in sweet gas. The future study will look at the reboiler duty required for solvent regeneration using this ternary blend of MDEA, AMP, and Sulfolane.

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Kinetic and thermodynamic analysis of H2S absorption by a non-aqueous absorbent of monoethanolamine /ethylene glycol

Dong,

Wang,

Hao

et al. 2024

Journal of Environmental Chemical Engineering

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Simulation of acid gas removal unit using DIPA+TEA amine solvent

Cited by 4 publications

References 12 publications

Removal of Carbon Dioxide and Hydrogen Sulfide from Natural Gas Using a Hybrid Solvent of Monoethanolamine and N-Methyl 2-Pyrrolidone

Removal of Carbon Dioxide and Hydrogen Sulfide from Natural Gas Using a Hybrid Solvent of Monoethanolamine and N-Methyl 2-Pyrrolidone

Absorption of acid gases (CO2, H2S) from natural gas using a ternary blend of N-methyldiethanolamine (MDEA), 2-amino-2-methyl-1-propanol (AMP), and Sulfolane

Kinetic and thermodynamic analysis of H2S absorption by a non-aqueous absorbent of monoethanolamine /ethylene glycol

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