Liquid Phase Oxidation Processes for Hydrogen Sulfide Removal

Kohl, Arthur L.; Nielsen, Richard B.

doi:10.1016/b978-088415220-0/50009-4

Cited by 183 publications

(22 citation statements)

References 25 publications

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“…The SO2 and the remaining H2S then reacts in the furnace and in a series of reactors to produce elemental sulfur. The overall removal efficiency of a Claus Process is dependent on the number of catalytic reactors installed [5,6,7].…”

Section: Introductionmentioning

confidence: 99%

“…Consequently, alkali vanadates are added to the solution to promote the oxidation. Since vanadium is toxic, the main drawback to the Stre t f o rd Process is that the process must be designed to handle the sulfur cake, and the disc h a rge solution [8]. The Stre t f o rd Process is modified to avoid the generation of toxic waste by using chelated iron to promote the reaction between H2S and dissolved oxygen.…”

Section: Introductionmentioning

confidence: 99%

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Absorption of H₂S in NaOCl caustic aqueous solution

2001

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Pilot plant experimental data were collected to study the feasibility of H2S removal from air streams utilizing aqueous solutions. Solutions of NaOCl/NaOH were tested in a packed bed scrubber and found to be effective. An efficiency of 99.2% H2S removal was achieved at a gas flow rate of 790 lb/f2 ‐hr and liquid‐gas ratio of 5.06. Sodium hydroxide was found to be the active ingredient in the absorption process. A minimum alkalinity of pH 11 in the scrubbing solution was required for the H2S to be efficiently absorbed in the packed bed scrubber. For gas flow rates up to 2,100 lb/f2 hr, the height of a transfer unit (HTU) varied from 1.8 ft to 2 ft with different proportions of NaOCl and NaOH in the solution.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Absorption of H₂S in NaOCl caustic aqueous solution

2001

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“…To upgrade the crude SNG, CO 2 must be removed. There are various techniques to remove the CO 2 : absorption using either chemically active solvents or solvents that interact via physical interactions with CO 2 , adsorption on solid surfaces, membrane permeation, cryogenic fractionation and methanation [3][4][5]. Different design approaches and process layouts for CO 2 capture from crude SNG with membranes exist [6][7][8].…”

Section: Introductionmentioning

confidence: 99%

Novel pressure and temperature swing processes for CO2 capture using low viscosity ionic liquids

Zubeir

Lacroix

Meuldijk

et al. 2018

Separation and Purification Technology

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“…Chemical absorption processes employing primary alkanolamines, such as methanolamine (MEA), have already been used in several industrial processes for over 50 years [3,4]. The absorption process is based on the exothermic reaction of CO 2 from flue gas and amines in the solvent via a zwitterion mechanism to form carbamates.…”

Section: Introductionmentioning

confidence: 99%

“…The absorption process is based on the exothermic reaction of CO 2 from flue gas and amines in the solvent via a zwitterion mechanism to form carbamates. Therefore, heat is required for solvent regeneration [4], and the development and use of amine-based solvents with lower energy requirements for regeneration, along with enhanced reaction kinetics and mass transfer properties, is a major research priority. The heat required for the solvent regeneration is typically provided by means of steam extraction from the power cycle [5].…”

Section: Introductionmentioning

confidence: 99%

Techno-economic evaluation of the 2-amino-2-methyl-1-propanol (AMP) process for CO2 capture from natural gas combined cycle power plant

Osagie

Biliyok

Lorenzo

et al. 2018

International Journal of Greenhouse Gas Control

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It is widely accepted that emissions of CO 2 , which is a major greenhouse gas, are the primary cause of climate change. This has led to the development of carbon capture and storage (CCS) technologies in which CO 2 is captured from large-scale point sources such as power plants. However, retrofits of carbon capture plants result in high efficiency penalties, which have been reported to fall in the range of 7-12% points in the case of post-combustion capture from natural gas-fired power plants. Therefore, a reduction of these efficiency losses is a high priority in order to deploy CCS at a large scale. At the moment, chemical solvent scrubbing using amines, such as monoethanolamine (MEA), is considered as the most mature option for CO 2 capture from fossil fuel-fired power plants. However, due to high heat requirements for solvent regeneration, and thus high associated efficiency penalties, the use of alternative solvents has been considered to reduce the energy demand. In this study, a techno-economic assessment of the post-combustion CO 2 capture process using 2-amino-2methyl-1-propanol (AMP) for decarbonisation of a natural gas combined cycle (NGCC) power plant was performed. The thermodynamic assessment revealed that the AMP-based process resulted in 25.6% lower reboiler duty compared to that of the MEA-based process. This was primarily because the AMP solvent can be regenerated at a higher temperature (140°C) and pressure (3.5 bar) compared to that of MEA (120°C and 1.8 bar). Furthermore, the efficiency penalty due to the retrofit of the AMP-based process with the natural gas combined cycle power plant was estimated to be 7.1% points, compared to 9.1% points in the case of integration with the MEA-based process. Regardless of the superior thermodynamic performance, the economic performance of the AMP-based process was shown to be better than that of the MEA-based process only for make-up rates below 0.03%. Therefore, use of AMP as a solvent in chemical solvent scrubbing may not be the most feasible option from the economic standpoint, even though it can significantly reduce the efficiency penalty associated with CO 2 capture from NGCCs.

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Liquid Phase Oxidation Processes for Hydrogen Sulfide Removal

Cited by 183 publications

References 25 publications

Absorption of H₂S in NaOCl caustic aqueous solution

Absorption of H₂S in NaOCl caustic aqueous solution

Novel pressure and temperature swing processes for CO2 capture using low viscosity ionic liquids

Techno-economic evaluation of the 2-amino-2-methyl-1-propanol (AMP) process for CO2 capture from natural gas combined cycle power plant

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Liquid Phase Oxidation Processes for Hydrogen Sulfide Removal

Cited by 183 publications

References 25 publications

Absorption of H2S in NaOCl caustic aqueous solution

Absorption of H2S in NaOCl caustic aqueous solution

Novel pressure and temperature swing processes for CO2 capture using low viscosity ionic liquids

Techno-economic evaluation of the 2-amino-2-methyl-1-propanol (AMP) process for CO2 capture from natural gas combined cycle power plant

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Absorption of H₂S in NaOCl caustic aqueous solution

Absorption of H₂S in NaOCl caustic aqueous solution