Natural gas sweetening process simulation and optimization: A case study of Khurmala field in Iraqi Kurdistan region

Abdul-Rahman, R.; Sebastine, I.M.

doi:10.1016/j.jngse.2013.06.005

Cited by 85 publications

(55 citation statements)

References 2 publications

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“…As the freezing point of the solvents is affected by temperature, winterization creates a problem in the smooth running of the plant. Abdulrahman and Sebastine have also studied on natural gas sweetening and optimization of a natural gas plant in the Khurmala field in the Iraqi Kurdistan region. The aim of the study was to simulate a sweetening process for the removal of high acid gas contents and to investigate the process optimization, suitable selection of amines, and its economic consideration.…”

Section: Resultsmentioning

confidence: 99%

Mathematical Modeling, Parametric Estimation, and Operational Control for Natural Gas Sweetening Processes

Selvan

Panda

2017

ChemBioEng Reviews

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As a result of the increased energy demand and the required environmental compliance, purification of natural gas (NG) need to be processed through more efficient technologies. Most the NG sources contain H2S and CO2 as acidic contaminants causing corrosion, reduction in the calorific value of the fuel, and toxicity. Removal of these gases (gas sweetening) is mostly performed in a reactive absorber followed by a stripper for solvents regeneration. Amine solvents are very suitable due to their natural affinity towards the acid gases. In the setting‐up of newer plants or retrofitting of old units in existing plants to improve the efficiency of the sweetening process, modeling, optimization, and safer operational control of the process have drawn the attention of many researchers. The development of better models must take into account the synthesis and implementation of proper control strategies. Rate‐based, equilibrium, and kinetic models supported by thermodynamic properties of the components have been discussed here and experiments carried out to identify new process models have also been presented.

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Section: Resultsmentioning

confidence: 99%

Mathematical Modeling, Parametric Estimation, and Operational Control for Natural Gas Sweetening Processes

Selvan

Panda

2017

ChemBioEng Reviews

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“…Among these contaminants, hydrogen sulfide and carbon dioxide possess a greater concern. Therefore, this paper focuses on removing these contaminants from the feed [1]. The process of using chemical or physical solvents to remove these gases from the raw gas feed is referred to as natural gas sweetening, and its key focus is to meet the sales gas specification [1,11].…”

Section: Introductionmentioning

confidence: 99%

Sulfolane and di-iso-propanol lean amine blend operating temperature and pressure effect to natural gas sweetening using process simulation

2020

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Blending physical and chemical solvents has shown to be promising for removing hydrogen sulfide, carbon dioxide and mercaptan from natural gas effectively. Studies show that using sulfolane and methyl di-ethylene amine blend yields better performance than traditional methods. However, the Shell process depicts that blending sulfolane with di-isopropanol amine significantly minimizes the problem associated with amine re-circulation efficiency observed with the application of sulfolane and methyl di-ethylene amine. This study aimed at investigating the effect of temperature and pressure to the acid gas removal performance of sulfolane and di-iso-propanol lean solvent using Aspen HYSYS software. In addition, the determination of optimum blend ratio was considered. The acid gas composition of the natural gas stream was 16.9%. This is a hypothetical data used to mimic a relatively high acid gas content in a typical raw natural gas feed. During the process simulation, the lean solvent temperature and pressure were varied between 5 and 210 °C, and 20 and 250 bar, respectively, while maintaining the reactant flow rate at 819.5 kg/h. Findings informs that the optimum blend formulation obtained was 15% water, 15% sulfolane and 70% di-iso-propanol amine at operating temperature and pressure of 50 °C and 45.5 bar, respectively. At the end of the process, the acid gas composition reduced from 16.9 to 0.26%, with an increase in the methane composition by 16.12%. This was as a result of the reduction in the vapor point of the lean solvent, which significantly contributed to enhancing the contact time and efficiency between the gas feed and lean solvent. Hence, the sales gas specification for natural gas was met at lower operating temperature and pressure below 10 °C and 25 bar, respectively.

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“…Many processes have been developed for the removal of CO 2 and H 2 S from the natural gas in various operating conditions and various CO 2 and H 2 S concentrations in the sour gas (Kohl and Nielsen, 1997;Processors, 2004;Rufford et al, 2012;Abdulrahman and Sebastine, 2013;Muhammad and GadelHak, 2014;Tavan and Tavan, 2014). One of these processes is the gas purification process by amine.…”

Section: Introductionmentioning

confidence: 99%

“…Table 1 shows the allowable of H 2 S concentrations for human contact time (Maddox, 1982). Abdulrahman and Sebastine (2013) studied the effect of amine solvents types on the percent of CO 2 and H 2 S in the sweet gas stream. In their simulation, the optimization of process studied by using several amine types and blends of them, for example, MEA and MDEA.…”

Section: Introductionmentioning

confidence: 99%

Effect of the Tower Type on the Gas Sweetening Process

Sharifi¹,

Amiri²

2017

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

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-The removal of acid gases, CO 2 and H 2 S from natural gas streams is essential for environmental and health reasons. In this work, the simulated gas sweetening unit with MethylDiEthanolAmine (MDEA) solvent was studied to improve quality. Firstly, the effect of trays types and then, the effect of various packing and the effect of the packing size were considered on the flow rate of CO 2 and H 2 S in the main streams. Results show that with considering the different trays types in the regenerator tower, the flow rate of CO 2 in the sweet gas stream with bubble cap tray is lower than other trays types. Also, with considering the different trays types in the absorber tower, the flow rate of CO 2 in the sweet gas stream with bubble cap tray is lower than other trays types in the absorber tower. In considering with different types of packing, results show that the flow rate of CO 2 with ballast ring packing and the flow rate of H 2 S with Raschig ring packing are lower than other types of packing. However, in some types such as cascade miniring, Intalox Saddles and pall ring, there is no difference for the flow rate of CO 2 or H 2 S. In all cases, with increasing the size of the packing, the flow rate of CO 2 and H 2 S in the sweet gas stream increases, however, this increasing in the metal packing is very small.

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Natural gas sweetening process simulation and optimization: A case study of Khurmala field in Iraqi Kurdistan region

Cited by 85 publications

References 2 publications

Mathematical Modeling, Parametric Estimation, and Operational Control for Natural Gas Sweetening Processes

Mathematical Modeling, Parametric Estimation, and Operational Control for Natural Gas Sweetening Processes

Sulfolane and di-iso-propanol lean amine blend operating temperature and pressure effect to natural gas sweetening using process simulation

Effect of the Tower Type on the Gas Sweetening Process

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