The Experts below are selected from a list of 144 Experts worldwide ranked by ideXlab platform
Neil Hewitt - One of the best experts on this subject based on the ideXlab platform.
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process design of co2 desorption from Physical Solvent di methyl ether of poly ethylene glycol
Materials Science for Energy Technologies, 2020Co-Authors: Ashok Dave, Medha Dave, Ye Huang, S. Rezvani, Bhumika Pathak, Neil HewittAbstract:Abstract Integrated Gasification Combined Cycle (IGCC) is a promising technology for effective control of green-house gas emission through CO2 capture pre-combustion process. This article describes the relative advantage of a novel energy efficient process configuration for desorption and compression of CO2 (previously absorbed by Physical Solvent Di-Methyl-Ether of poly-Ethylene-Glycol (DMEPEG)). DMEPEG is a blend of several polymeric chain length (n = 3 to 9) of CH3-O-[C2H4O]n-CH3 which is a polar organic liquid Solvent. Desorption of dissolved CO2 from Solvent at highest possible pressure is helpful to minimize the power consumption for subsequent compression of CO2. This article quantifies the effect of heating the DMEPEG Solvent to 120 °C for CO2 desorption (compared to CO2 desorption at 35 °C) on the regeneration (desorption) of CO2 at various pressure stages. CO2 desorption performance of DMEPEG Solvent is assessed using ProTreat® simulation software. Depressurization of 4.455 kmol/s DMEPEG Solvent (with dissolved gas) beginning at 120 °C results in desorption of 2.077 kmol/s CO2 capture (91.4 kg/s) out of initially dissolved 2.194 kmol/s CO2 (94.66%). Solvent heating upto 120 °C (instead of 35 °C) can compress the 97.1 kg/s CO2 from 3 barA to 34.7 barA consuming 6 MW (instead of 8.15 MW) power for CO2 compression, thus resulting in 15% saving for CO2 compression upto 120 barA consuming 14.1 MW power consumption.
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process design of thermal stripper for desorption of dissolved h2s from Physical Solvent di methyl ether of poly ethylene glycol
Materials Science for Energy Technologies, 2020Co-Authors: Ashok Dave, Medha Dave, Ye Huang, S. Rezvani, Bhumika Pathak, Neil HewittAbstract:Abstract Acid gas removal from syngas is an important process step upstream of its further processing for combustion or further processing of syngas. Integrated Gasification Combined Cycle (IGCC) power plant or chemical production (such as urea or petrochemicals, etc.). The process of absorbing the H2S in Di-Methyl-Ether of poly-Ethylene-Glycol (DMEPEG) Solvent and the process of enriching the DMEPEG Solvent with dissolved H2S has been described in literature (including the publications by the Author). This publication describe the process of stripping out the dissolved H2S from the DMEPEG Solvent using a thermal stripper designed using the rate based mass transfer simulations carried out using ProTreat software. Basic process design and equipment size is described in this publication. 20 MW heat input is needed to strip out 19.13 kmol/s H2S from the 1.136 kmol/s DMEPEG Solvent thus resulting in overall heat consumption of 30.7 GJ/Ton H2S capture. Limitations of this process design are also described. Various options of packed tower configuration have been suggested for tower internals resulting in similar performance.
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process design for h2s enrichment in Physical Solvent dmepeg
International Journal of Greenhouse Gas Control, 2016Co-Authors: Ashok Dave, Medha Dave, Ye Huang, S. Rezvani, Neil HewittAbstract:Acid gas removal from syngas is an important process upstream of CO2 capture in a pre-combustion IGCC power plant. Enrichment of previously absorbed H2S in DMEPEG Solvent (by stripping out the CO2 co-absorbed with H2S) is described in this publication. The unique capability of ProTreat software to conduct rate based mass transfer simulation is described and applied for H2S Enrichment simulation. Non-ionic liquid property model and its implementation in ProTreat software is described. Solubility of CO2 and H2S in DMEPEG Solvent is described. Process condition for H2S Enrichment is justified in terms of its integration within the overall IGCC power plant. Sensitivity study is conducted for various important process parameters. systematic development and optimizations of H2S Enrichment process is described considering optimization of techno-economic performance parameters. Interaction and integration of H2S Enrichment with H2S absorption and H2S Stripper is analyzed. Performance and mass balance across H2S Enrichment is described. Limitations of this process design are also described. Various options are suggested for tower internals resulting in similar performance. This kind of detailed process design is necessary for accurate detailed CAPEX assessment (by bottom-up approach) and techno-economic assessment.
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Process design for CO2 absorption from syngas using Physical Solvent DMEPEG
International Journal of Greenhouse Gas Control, 2016Co-Authors: Ashok Dave, Medha Dave, Ye Huang, S. Rezvani, Neil HewittAbstract:Abstract Pre-combustion IGCC is one of the leading technologies having potential for effective control of greenhouse gas emission. Process design for CO 2 Capture from power plant is becoming increasingly important in the past decades in view of the need for optimization of Capital Cost and Utility consumption. In this article, a configuration of the process design for CO 2 absorption using Physical Solvent DMEPEG is proposed, which is described using the process flow diagram (PFD) and the Flowsheet. CO 2 absorption performance of DMEPEG Solvent is assessed based on a rate based mass transfer model using ProTreat ® simulation software. The rate based mass transfer simulation by ProTreat software adds to the reliability of the simulation result (as evident by its acceptance within industry). The trade-off between H 2 recovery (by syngas recycle) and CO 2 re-absorption is described which reveals that more than 55% H 2 recovery may significantly increase the load on the system (in terms of syngas processing and CO 2 re-absorption). Objective of this research is to develop a detailed process model for CO 2 absorption by DMEPEG Solvent (to enable detailed techno-economic assessment by bottom up approach). In the second section of this article, the process of CO 2 capture by Physical Solvent DMEPEG is explained. In the fourth section, the boundary conditions such as the inlet pressure, temperature and composition of syngas and Solvent feed are defined. In the fourth and fifth section, the design and performance of the packed tower is described and the utility consumption is estimated. Moreover, the outlet condition of the Solvent is described and its saturation (by CO 2 ) is estimated. In the fourth section, the strategy of Solvent heating to recycle the syngas to CO 2 absorber (for H 2 recovery) is described. Importance of CO 2 absorption in Solvent (at high concentration) for minimization of equipment size and utility consumption for CO 2 capture is explained. Using RSR packing (6.4 m Dia., 16 m Ht. (9 + 6 + 1)) results in 90.7% CO 2 absorption and 89% saturation of CO 2 dissolved in DMEPEG Solvent. Out of 3.34 kmol/s H 2 fed to the CO 2 Absorber (as part of syngas), 1.464% (equivalent 5.9 MW power generation by Gas Turbine in open cycle) is co-absorbed (along with CO 2 ) in DMEPEG Solvent. Out of this co-absorbed H 2 , 55.7% is recovered which is equivalent to 3.267 MW Power Generation. In terms of hydraulic design, the CO 2 Absorber using RSR packing operating at 72.5% flood condition results in packing pressure drop of 87.5 Pa/m (1.4 kPa). Packed section diameter and height is suggested for various random packing materials (tower internal) to achieve almost comparable gas absorption performance.
Gary T Rochelle - One of the best experts on this subject based on the ideXlab platform.
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co2 absorption rate and capacity of semi aqueous piperazine for co2 capture
International Journal of Greenhouse Gas Control, 2019Co-Authors: Ye Yuan, Gary T RochelleAbstract:Abstract Aqueous piperazine (PZ) is a representative second-generation Solvent for flue gas amine scrubbing; however, the solid precipitation of aqueous PZ at lean loading needs to be addressed. Semi-aqueous piperazine composed of PZ, water, and a Physical Solvent (sulfolane or imidazole) has been characterized in a wetted wall column. No precipitation was observed in 5 m PZ in SUF/water or IMI/water in the loading range of 0.15–0.45 mol CO2/mole alkalinity at 20–60 °C. The average viscosity at 40 °C in this range is about 25 cP in 5 m PZ in 1SUF/1water, 9.5 cP in 5 m PZ in 1SUF/3water, and 15 cP in 5 m PZ in 1IMI/1water, greater than 4 cp in 5 m aqueous PZ. Adding SUF or IMI into aqueous PZ increases absorption rate (kg’) at lean and median loading but decreases kg’ at rich loading. kg’ in semi-aqueous PZ increases as temperature decreases from 60 to 20 °C. At 40 °C, kg’avg in 5 m semi-aqueous PZ is 15–35% greater for the operating range of 0.1–5 kPa P*CO2, and 20–50% greater for 0.1–1.5 kPa P*CO2 (natural gas conditions). CO2 cyclic capacity slightly increased after adding SUF or IMI.
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co 2 absorption rate in semi aqueous monoethanolamine
Chemical Engineering Science, 2018Co-Authors: Ye Yuan, Gary T RochelleAbstract:Abstract Post-combustion CO2 capture using amine scrubbing is the most promising technology to reduce CO2 emissions from coal- or gas-fired power plants. Increasing CO2 absorption rate (kg′) reduces the absorber capital cost, which is the cost center of the capture plant. By partially replacing water with N-methyl-2-pyrrolidone (NMP) in 7 m (30 wt%) aqueous monoethanolamine (MEA), the CO2 absorption rate (kg′) is significantly enhanced because of lower CO2 loading/higher free MEA at the same CO2 partial pressure (P∗CO2), greater CO2 Physical solubility, and greater MEA activity. At 40 °C, in the operating range of 100–5000 Pa P∗CO2, the average kg′ of 7 m MEA in 3 water/1 NMP, 1 water/3 NMP, and 1 water/19 NMP is 1.1 times, 2 times, and 5 times that of 7 m aqueous MEA, respectively. CO2 Physical solubility, Solvent viscosity, and MEA activity were measured. A kinetic model was built in MATLAB® to better understand the mass transfer of CO2 into semi-aqueous MEA (MEA-NMP-water). The model suggests that the diffusion and reaction of CO2 into aqueous MEA can be approximated by pseudo-first-order (PFO) behavior and adding NMP causes deviation from PFO by the depletion of MEA at the surface. The semi-aqueous Solvent provides an excellent rate of CO2 absorption, but the increased viscosity reduces normalized capacity and the volatility of the Physical Solvent must be addressed.
Ashok Dave - One of the best experts on this subject based on the ideXlab platform.
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process design of co2 desorption from Physical Solvent di methyl ether of poly ethylene glycol
Materials Science for Energy Technologies, 2020Co-Authors: Ashok Dave, Medha Dave, Ye Huang, S. Rezvani, Bhumika Pathak, Neil HewittAbstract:Abstract Integrated Gasification Combined Cycle (IGCC) is a promising technology for effective control of green-house gas emission through CO2 capture pre-combustion process. This article describes the relative advantage of a novel energy efficient process configuration for desorption and compression of CO2 (previously absorbed by Physical Solvent Di-Methyl-Ether of poly-Ethylene-Glycol (DMEPEG)). DMEPEG is a blend of several polymeric chain length (n = 3 to 9) of CH3-O-[C2H4O]n-CH3 which is a polar organic liquid Solvent. Desorption of dissolved CO2 from Solvent at highest possible pressure is helpful to minimize the power consumption for subsequent compression of CO2. This article quantifies the effect of heating the DMEPEG Solvent to 120 °C for CO2 desorption (compared to CO2 desorption at 35 °C) on the regeneration (desorption) of CO2 at various pressure stages. CO2 desorption performance of DMEPEG Solvent is assessed using ProTreat® simulation software. Depressurization of 4.455 kmol/s DMEPEG Solvent (with dissolved gas) beginning at 120 °C results in desorption of 2.077 kmol/s CO2 capture (91.4 kg/s) out of initially dissolved 2.194 kmol/s CO2 (94.66%). Solvent heating upto 120 °C (instead of 35 °C) can compress the 97.1 kg/s CO2 from 3 barA to 34.7 barA consuming 6 MW (instead of 8.15 MW) power for CO2 compression, thus resulting in 15% saving for CO2 compression upto 120 barA consuming 14.1 MW power consumption.
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process design of thermal stripper for desorption of dissolved h2s from Physical Solvent di methyl ether of poly ethylene glycol
Materials Science for Energy Technologies, 2020Co-Authors: Ashok Dave, Medha Dave, Ye Huang, S. Rezvani, Bhumika Pathak, Neil HewittAbstract:Abstract Acid gas removal from syngas is an important process step upstream of its further processing for combustion or further processing of syngas. Integrated Gasification Combined Cycle (IGCC) power plant or chemical production (such as urea or petrochemicals, etc.). The process of absorbing the H2S in Di-Methyl-Ether of poly-Ethylene-Glycol (DMEPEG) Solvent and the process of enriching the DMEPEG Solvent with dissolved H2S has been described in literature (including the publications by the Author). This publication describe the process of stripping out the dissolved H2S from the DMEPEG Solvent using a thermal stripper designed using the rate based mass transfer simulations carried out using ProTreat software. Basic process design and equipment size is described in this publication. 20 MW heat input is needed to strip out 19.13 kmol/s H2S from the 1.136 kmol/s DMEPEG Solvent thus resulting in overall heat consumption of 30.7 GJ/Ton H2S capture. Limitations of this process design are also described. Various options of packed tower configuration have been suggested for tower internals resulting in similar performance.
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process design for h2s enrichment in Physical Solvent dmepeg
International Journal of Greenhouse Gas Control, 2016Co-Authors: Ashok Dave, Medha Dave, Ye Huang, S. Rezvani, Neil HewittAbstract:Acid gas removal from syngas is an important process upstream of CO2 capture in a pre-combustion IGCC power plant. Enrichment of previously absorbed H2S in DMEPEG Solvent (by stripping out the CO2 co-absorbed with H2S) is described in this publication. The unique capability of ProTreat software to conduct rate based mass transfer simulation is described and applied for H2S Enrichment simulation. Non-ionic liquid property model and its implementation in ProTreat software is described. Solubility of CO2 and H2S in DMEPEG Solvent is described. Process condition for H2S Enrichment is justified in terms of its integration within the overall IGCC power plant. Sensitivity study is conducted for various important process parameters. systematic development and optimizations of H2S Enrichment process is described considering optimization of techno-economic performance parameters. Interaction and integration of H2S Enrichment with H2S absorption and H2S Stripper is analyzed. Performance and mass balance across H2S Enrichment is described. Limitations of this process design are also described. Various options are suggested for tower internals resulting in similar performance. This kind of detailed process design is necessary for accurate detailed CAPEX assessment (by bottom-up approach) and techno-economic assessment.
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Process design for CO2 absorption from syngas using Physical Solvent DMEPEG
International Journal of Greenhouse Gas Control, 2016Co-Authors: Ashok Dave, Medha Dave, Ye Huang, S. Rezvani, Neil HewittAbstract:Abstract Pre-combustion IGCC is one of the leading technologies having potential for effective control of greenhouse gas emission. Process design for CO 2 Capture from power plant is becoming increasingly important in the past decades in view of the need for optimization of Capital Cost and Utility consumption. In this article, a configuration of the process design for CO 2 absorption using Physical Solvent DMEPEG is proposed, which is described using the process flow diagram (PFD) and the Flowsheet. CO 2 absorption performance of DMEPEG Solvent is assessed based on a rate based mass transfer model using ProTreat ® simulation software. The rate based mass transfer simulation by ProTreat software adds to the reliability of the simulation result (as evident by its acceptance within industry). The trade-off between H 2 recovery (by syngas recycle) and CO 2 re-absorption is described which reveals that more than 55% H 2 recovery may significantly increase the load on the system (in terms of syngas processing and CO 2 re-absorption). Objective of this research is to develop a detailed process model for CO 2 absorption by DMEPEG Solvent (to enable detailed techno-economic assessment by bottom up approach). In the second section of this article, the process of CO 2 capture by Physical Solvent DMEPEG is explained. In the fourth section, the boundary conditions such as the inlet pressure, temperature and composition of syngas and Solvent feed are defined. In the fourth and fifth section, the design and performance of the packed tower is described and the utility consumption is estimated. Moreover, the outlet condition of the Solvent is described and its saturation (by CO 2 ) is estimated. In the fourth section, the strategy of Solvent heating to recycle the syngas to CO 2 absorber (for H 2 recovery) is described. Importance of CO 2 absorption in Solvent (at high concentration) for minimization of equipment size and utility consumption for CO 2 capture is explained. Using RSR packing (6.4 m Dia., 16 m Ht. (9 + 6 + 1)) results in 90.7% CO 2 absorption and 89% saturation of CO 2 dissolved in DMEPEG Solvent. Out of 3.34 kmol/s H 2 fed to the CO 2 Absorber (as part of syngas), 1.464% (equivalent 5.9 MW power generation by Gas Turbine in open cycle) is co-absorbed (along with CO 2 ) in DMEPEG Solvent. Out of this co-absorbed H 2 , 55.7% is recovered which is equivalent to 3.267 MW Power Generation. In terms of hydraulic design, the CO 2 Absorber using RSR packing operating at 72.5% flood condition results in packing pressure drop of 87.5 Pa/m (1.4 kPa). Packed section diameter and height is suggested for various random packing materials (tower internal) to achieve almost comparable gas absorption performance.
Sandra E Kentish - One of the best experts on this subject based on the ideXlab platform.
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membrane gas separation Physical Solvent absorption combined plant simulations for pre combustion capture
Energy Procedia, 2013Co-Authors: Colin A. Scholes, Clare Anderson, Geoff W. Stevens, Sandra E KentishAbstract:Abstract Removal of carbon dioxide (CO 2 ) from syngas generated by coal gasification is often currently achieved by absorption into Physical Solvents such as in the Rectisol Process. The vented gas from this process often does not have the CO 2 purity required for carbon capture and storage purposes, because the focus is on recovery and recycling valuable syngas components, such as H 2 . It is shown here that this can be rectified through the use of a CO 2 -selective membrane. For an existing Rectisol process, a CO 2 -selective membrane unit on the vented waste gas can achieve the necessary CO 2 purity with a low CO 2 /H 2 selectivity polymer. This provides a simple and effective method to retrofit such a process to provide a CO 2 stream suitable for storage. Alternatively, the standard multiple flash stages can be replaced by a single flash stage with a gas-separation membrane on the gas recycle. This Rectisol – membrane hybrid design can achieve high purity CO 2 product streams with reasonable membrane CO 2 /H 2 selectivities, dependent on the Solvent flash pressure. However, maximizing CO 2 flux across the membrane means a high flashing pressure and therefore only partial Solvent regeneration before recycle to the absorber. This results in a significant increase in Solvent flowrate and hence absorber size to ensure high CO 2 recovery.
Badie I. Morsi - One of the best experts on this subject based on the ideXlab platform.
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development of a conceptual process for selective co2 capture from fuel gas streams using hmim tf2n ionic liquid as a Physical Solvent
Energy & Fuels, 2013Co-Authors: Omar M Basha, David R Luebke, Murphy J Keller, Kevin P Resnik, Badie I. MorsiAbstract:The ionic liquid (IL) [hmim][Tf2N] was used as a Physical Solvent in an Aspen Plus simulation, employing the Peng–Robinson Equation of State (PR-EOS) with Boston–Mathias (BM) α-function and standard mixing rules, to develop a conceptual process for CO2 capture from a shifted (undergone the water–gas shift reaction) warm fuel gas stream produced from Pittsburgh #8 coal for a 400 MWe IGCC power plant. The Physical properties of the IL, including density, viscosity, surface tension, vapor pressure, and heat capacity were obtained from literature and modeled as a function of temperature. Also, available experimental solubility values for CO2, H2, H2S, CO, and CH4 in this IL were compiled, and their binary interaction parameters (δij and lij) were optimized and correlated as functions of temperature. The Span–Wager EOS was also employed to generate CO2 solubilities in [hmim][Tf2N] at high pressures (up to 10 MPa) and temperatures (up to 510 K). The conceptual process developed consists of four adiabatic absorb...
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hydrogen sulfide and carbon dioxide removal from dry fuel gas streams using an ionic liquid as a Physical Solvent
Energy & Fuels, 2009Co-Authors: Yannick J Heintz, Badie I. Morsi, David R Luebke, Kenneth L Jones, Laurent Sehabiague, Henry W. PennlineAbstract:The mole fraction solubilities (x*) and volumetric liquid-side mass-transfer coefficients (kLa) for H2S and CO2 in the ionic liquid, TEGO IL K5, (a quaternary ammonium polyether) were measured under different pressures (up to 30 bar) and temperatures (up to 500 K) in a 4 L ZipperClave agitated reactor. CO2 and N2, as single gases, and a H2S/N2 gaseous mixture were used in the experiments. The solubilities of H2S and CO2 were found to increase with pressure and decrease with temperature within the experimental conditions used. The H2S solubilities in the ionic liquid (IL) were greater than those of CO2 within the temperature range investigated (300−500 K) up to a H2S partial pressure of 2.33 bar. Hence, the IL can be effectively used to capture both H2S and CO2 from dry fuel gas stream within the temperature range from 300 to 500 K under a total pressure up to 30 bar. The presence of H2S in the H2S/N2 mixture created mass-transfer resistance, which decreased kLa values for N2. The kLa and x* values of CO2 ...
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progress in carbon dioxide capture and separation research for gasification based power generation point sources
Fuel Processing Technology, 2008Co-Authors: Henry W. Pennline, Badie I. Morsi, David R Luebke, Kenneth L Jones, Y.j. Heintz, Christina R Myers, J.b. IlconichAbstract:The purpose of the present work is to investigate novel approaches, materials, and molecules for the abatement of carbon dioxide (CO2) at the pre-combustion stage of gasification-based power generation point sources. The capture/separation step for CO2 from large point sources is a critical one with respect to the technical feasibility and cost of the overall carbon sequestration scenario. For large point sources, such as those found in power generation, the carbon dioxide capture techniques being investigated by the Office of Research and Development of the National Energy Technology Laboratory possess the potential for improved efficiency and reduced costs as compared to more conventional technologies. The investigated techniques can have wide applications, but the present research is focused on the capture/separation of carbon dioxide from fuel gas (pre-combustion gas) from processes such as the Integrated Gasification Combined Cycle (IGCC) process. For such applications, novel concepts are being developed in wet scrubbing with Physical sorption, chemical sorption with solid sorbents, and separation by membranes. In one concept, a wet scrubbing technique is being investigated that uses a Physical Solvent process to remove CO2 from fuel gas of an IGCC system at elevated temperature and pressure. The need to define an “ideal” Solvent has led to the study of the solubility and mass transfer properties of various Solvents. Pertaining to another separation technology, fabrication techniques and mechanistic studies for membranes separating CO2 from the fuel gas produced by coal gasification are also being performed. Membranes that consist of CO2-philic ionic liquids encapsulated into a polymeric substrate have been investigated for permeability and selectivity. Finally, processes based on dry, regenerable sorbents are additional techniques for CO2 capture from fuel gas. An overview of these novel techniques is presented along with a research progress status of technologies related to membranes and Physical Solvents.