Lean Amine Research Articles

Comprehensive evaluation and sensitivity analysis of regeneration energy for acid gas removal plant using single and activated-methyl diethanolamine solvents

Abstract The absorption of acid gas using reactive amines is among the most widely used types of capturing technologies. However, the absorption process requires intensive energy expenditure majorly in the solvent regeneration process. This study simultaneously evaluated the regeneration energy of MDEA and PZ/MDEA solvents in terms of heat of absorption, sensible heat, and vaporization heat. Aspen Hysys version 8.8 simulation tool is applied to model the full acid gas removal plant for the chemical absorption process. The new energy balance technique presents around the absorption and desorption columns to bring a new perspective of energy distribution in the capturing of acid gas plants. Sensitivity analysis of regeneration energy and its three contributors is performed at several operation parameters such as absorber and stripper pressures, lean amine circulation rate, solvent concentration, reflux ratio, and CO2 and H2S concentrations. The results show that the heat of absorption of PZ/MDEA system is higher than that for MDEA system for the same operating conditions. The sensible heat is the main contributor in the required regeneration energy of MDEA solvent system. The simulation results have been validated against data taken from real plant and literature. The product specifications of our simulation corroborate with real plant data in an excellent approach; additionally, the profile temperature of the absorber and the stripper columns are in good agreement with literature. The overall results highlight the direction of the effects of each parameter on the heat of absorption, sensible heat, and vaporization heat.

Comparison study of activators performance for MDEA solution of acid gases capturing from natural gas: Simulation-based on a real plant

Energy requirements and environmental regulations are the main limiting issues behind the continuous developments of amine absorption processes. Steady state simulation has been performed using the Aspen HYSYS program version 8.8 to determine the effects of adding various concentrations of activators up to 10% with maintaining the constancy of the entire amine strength of 45%. The present investigation addresses the performance of using piperazine/MDEA and sulfolane/MDEA on the absorption process in terms of energy consumption and acid gases loading. Four scenarios have been analyzed under the same operating conditions, 5% activator/ 40% MDEA has shown better performance superior to other scenarios regarding the balance between energy consumption and absorption capacity of acid gases. The results revealed that the addition of 5% piperazine improves the absorption of CO 2 and H 2 S by 92.1% and 28.2% respectively. Correspondingly, 5% sulfolane enhances the absorption efficiency of CO 2 and H 2 S by 80.48% and 48.18%. In terms of energy, the sulfolane system saved more reboiler energy compared to the piperazine system. Reboiler energy consumption was investigated by changing some effective parameters, namely sour gas temperature, lean amine temperature, reflux ratio, and rich amine temperature. Sulfolane promoter is more applicable for the study plant conditions due to its high absorption capacity for H 2 S and low reboiler duty requirements. • The performance of piperazine and sulfolane activators has been studied. • 5% sulfolane activator enhances CO 2 and H 2 S absorption by 80.48% and 48.18%. • 5% piperazine activator promotes CO 2 and H 2 S absorption by 92.1% and 28.2%. • Sulfolane is more applicable regarding the balance between energy consumption and H 2 S loading. • Some effective parameters investigated to figure out the optimum operational conditions.

Total organic acid adsorption using alginate/clay hybrid composite for industrial lean amine reclamation using fixed-bed: Parametric study coupled with foaming

The technical feasibility of removing heat stable salts (HSS) such as total organic acids (TOA) from industrial lean methyldiethanolamine (MDEA) solutions using calcium alginate/clay hybrid (CAH) composite adsorbent in a continuous fixed bed adsorber has been investigated. The effect of process parameters such as bed diameter, bed height, feed flow rate, and flow direction on breakthrough time, adsorption capacity, and exhaustion time of the fixed-bed sorption system was analyzed. Experimental results showed that higher bed diameter and height, lower flow rate along with up-flow column mode resulted in increased uptake capacity and breakthrough time. Progressive reduction in adsorption capacity from 3.6 mg/g to 2.83 mg/g after three adsorption/desorption cycles using 4.0 wt. % CaCl2 confirmed the practicability of the adsorbent. Simulation of breakthrough curves using general reaction rate models such as Bohart-Adams and Yoon-Nelson yielded a high correlation coefficient (R2 > 0.93), and thus validating the applicability of these models to predict the break through curves under various operating conditions. Furthermore, foaming experiments confirmed the vital role of CAH composite in reducing the foamability of lean MDEA solutions through the synergistic effect of successive biosorption and robustness of the saturated composites to multiple in-situ regeneration using CaCl2.

A quest for electrode materials: Heat-stable salts removal from industrial lean amine solution via electro-sorption

The accumulation of heat-stable salts (HSS) deteriorate the performance of gas treatment amine units. In this work, different commercially available electrode materials such as copper, stainless steel, aluminum foil, platinized coated titanium, and nickel foam were tested in a batch mode for the electro-sorption of HSS from industrial lean methyl-diethanolamine (MDEA) solutions. Initially, salt removal was examined by using copper electrodes in two different configurations: inside and outside the designed cell; attributing direct and indirect contact with the lean amine, respectively. The results revealed that indirect electrochemical cell configuration has a zero impact on HSS removal, and hence, all the electrodes were structured inside a cell having direct contact with the MDEA solution. Remarkably, the applied voltage has a significant impact on the removal efficiency of the HSS. Among the tested materials, nickel foam (Ni) and platinized (Pt) coated titanium (Ti) electrodes were the most efficient in the removal of HSS with 6.5% and 9.6% removal at a voltage of 0.8V and 1.2V, respectively. The electrochemical characteristics including areal capacitance and cyclic voltammetry for nickel and Pt coated Ti electrode were also reported. The magnetic forces showed no impact on the removal efficiency of the HSS in the batch mode of operation.

A novel rectangular assembly for heat stable salts removal from industrial lean amine: Effect of operational parameters

Heat stable salts (HSS) formed in gas sweetening units pose many challenges such as foaming, corrosion and equipment fouling. In this work, we designed a novel electromagnetic (EM) setup which aids the removal of HSS from MDEA without degrading amine and producing secondary waste. Total organic acid (TOA) was taken as a model pollutant to represent HSS ions. TOA was successfully removed by employing electromagnetic forces based on the Lorentz principle, using rectangular setup having parallel electrodes. The direction of the electric field will be perpendicular to the flow path along the channel to enhance the separation of ions at the outlet. In the flow cell, we investigated the effect of voltage, flow rate and magnet position on the removal efficiency and found optimal operating conditions to be at an applied potential of 3 V, the flow rate of 2 mL/min and 1T magnets placed parallel to fluid flow. The experimental results showed that the introduction of electromagnetic forces led to the electrosorption of ions onto the surface of the aluminum electrode whereas polarization occurred when only the electrical field was used. The HSS removal rate with magnets and without magnets in the parallel flow cell was 7.8% and 3.2% respectively.

Busting process industry's myth no. 20: Ton for ton, toxic gases produce more fatalities than flammable gases or liquids

Worst credible release cases were evaluated for a Loss of Process Containment situation in a Gas Oil Hydro-Treater Unit's (GOHTU's) recycle gas piping, just upstream of the amine absorber where lean amine would remove most of the H2S from the recycle gas.It was found that the mass flow rate of the release was greater than the design mass flow rate through the piping where the Loss of Process Containment occurred. This made, except for possibly a short transient condition, the release impossibly high. A relatively easy way of correcting the worst credible case was to use the centrifugal compressor's surge condition as sizing criterion for the worst credible release. As a general good practice one should closely examine releases from locations where the ratio of the release mass rate over the given process mass rate has a value of one or greater. This dimensionless number, m˙rel/m˙HMB≥1 (where HMB stands for Heat and Material Balance) can be used as an early screening criterion to find release scenarios that are candidates for refinement when needed. Because most hydrotreaters/crackers have a similar unit operations layout, the given example could be used as a generalized worst case limiting criterion for such units.

An experimental based optimization of a novel water lean amine solvent for post combustion CO2 capture process

The development of new amine solvents without the major drawbacks of conventional amines is crucial to industrial applications of CO2 capture. This paper presents a water-lean CO2 capture solvent having a low regeneration energy and low degradation. The water-lean solvent, K2Sol, is a sterically hindered diamine; because of the hindered amine site, K2Sol easily forms bicarbonate, resulting in a high absorption capacity. The minimum solvent regeneration energy is obtained using Gaussian process Bayesian optimization (GPBO) and bench-scale pilot plant experiments. GPBO finds the optimal solution using the input and output relationship of experiments; thus, expensive first-principle model construction can be avoided. According to the pilot plant experiment, the optimal regeneration energies of monoethanolamine (MEA) and K2Sol are 4.3 and 2.8 GJ/t CO2, respectively, indicating that K2Sol requires only 65% of the regeneration energy of MEA. Fewer than 30 experiments are required to find the optimal pilot plant operation for both the MEA and K2Sol experiments. We also describe the superior properties of K2Sol in terms of the CO2 loading, cyclic capacity, regeneration temperature, and degradation.

Modeling and optimization of an industrial hydrogen unit in a crude oil refinery

The main goal of this research is the modeling and optimization of an industrial hydrogen unit in a domestic oil refinery at steady state condition. The considered process consists of steam methane reforming furnace, low and high temperature shift converters, CO2 absorption column and methanation reactor. In the first step, the reactors are heterogeneously modeled based on the mass and energy balance equations considering heat and mass transfer resistances in the gas and catalyst phases. The CO2 absorption column is simulated based on the equilibrium non-ideal approach. In the second step, a single objective optimization problem is formulated to maximize hydrogen production in the plant considering operating and economic constraints. The feed temperature, firebox temperature, and steam flow rate in the reformer, feed temperature in shift converters, lean amine flow rate in the absorption column, and feed temperature in the methanator are selected as decision variables. The calculated effectiveness factors and mass transfer coefficients prove that the methane reforming is inertia-particle mass transfer control, while shift and methanation reactions are surface reaction control. The simulation results show that applying the optimal condition on the system increases hydrogen production capacity from 85.93 to 105.5 mol s−1.

Ethylene glycol elimination in amine loop for more efficient gas conditioning

The gas sweetening unit of phase 2 and 3 in South Pars Gas Field (Asalouyeh, Iran) was first simulated to investigate the effect of mono ethylene glycol (MEG) in the amine loop. MEG is commonly injected into the system to avoid hydrate formation while a few amounts of MEG is usually transferred to amine gas sweetening plant. This paper aims to address the points where MEG has negative effects on gas sweetening process and what the practical ways to reduce its effect are. The results showed that in the presence of 25% of MEG in amine loop, H2S absorption from the sour gas was increased from 1.09 to 3.78 ppm. Also, the reboiler temperature of the regenerator (from 129 to 135 °C), amine degradation and required steam and consequently corrosion (1.10 to 17.20 mpy) were increased. The energy consumption and the amount of amine make-up increase with increasing MEG loading in amine loop. In addition, due to increasing benzene, toluene, ethylbenzene and xylene (BTEX) and heavy hydrocarbon solubility in amine solution, foaming problems were observed. Furthermore, side effects of MEG presence in sulfur recovery unit (SRU) such as more transferring BTEX to SRU and catalyst deactivation were also investigated. The use of total and/or partial fresh MDEA, install insulation and coating on the area with the high potential of corrosion, optimization of operational parameters and reduction of MEG from the source were carried out to solve the problem. The simulated results were in good agreement with industrial findings. From the simulation, it was found that the problem issued by MEG has less effect when MEG concentration in lean amine loop was kept less than 15% (as such observed in the industrial plant). Furthermore, the allowable limit, source and effects of each contaminant in amine gas sweetening were illustrated.

CO2 capture from lime kiln using AMP-DA2MP amine solvent blend: A pilot plant study

This experimental study covered pilot plant analysis of novel AMP and 1,5–diamino–2–methylpentane (DA2MP) amine solvent blend for CO2 capture from a lime kiln. The gas flow rate (F(GAS)), amine solution flow rate (F(amine)), CO2 concentration and reboiler temperature (T(REB)) were kept at 14 SLPM, 50 mL/min, 30 vol.% CO2 (N2 balance) and 120 °C respectively. The AMP concentration was kept at 2 kmol/m3 while DA2MP was varied from 1.5 kmol/m3 to 2 kmol/m3. The MEA and AMP-DA2MP comparative analysis was based on rich amine loading (αrich, mol CO2/mol amine), lean amine loading (αlean, mol CO2/mol amine), cyclic loading (CL, mol CO2/mol amine), cyclic capacity (CC, mol CO2/L–amine soln.), CO2 absorption rate (rabs, g–CO2/hr), CO2 absorption efficiency (%), regeneration energy (Qreg, GJ/tonne CO2), absorber overall average volumetric mass transfer coefficient (KGav(ave), kmol/kPa.hr. m3), desorber mass transfer coefficient (KLav, hr–1), initial amine solution utilized (Aminesoln._utilized, g-amine soln./g-CO2) and initial amine solution cost (US$/g-CO2). The influence of sensible energy (Qsen, GJ/tonne CO2), vaporization energy (Qvap, GJ/tonne CO2), and desorption heat (ΔHdes, GJ/tonne CO2) towards regeneration energy (Qreg) was also examined. Results showed that the AMP-DA2MP blend possesses higher CO2 absorption efficiency (up to 36.17%), higher KGav(ave) (up to 65.85%), higher KLav (up to 28.29%) and lower Qreg (up to 32.54%) compared to the single solvent MEA. Also, MEA possessed higher initial amine solution utilized (28.86%) and lower initial amine solution cost (28.5%) compared to the AMP-DA2MP blend. This is an initial revelation that AMP-DA2MP can provide cost-effective CO2 capture from a lime kiln.

Mass transfer performance for CO2 absorption into aqueous blended DMEA/MEA solution with optimized molar ratio in a hollow fiber membrane contactor

Combination N,N-dimethylethanolamine(DMEA) and monoethanolamine (MEA) may represent a potential absorbent for CO2 capture due to the high absorption rate, high cyclic CO2 capacity and low energy requirement for solvent regeneration. Both the absorption and regeneration performances for 2 kmol/m3 DMEA/MEA with molar ratios of 2.0:0.0, 1.5:0.5, 1.0:1.0, 0.5:1.5, and 0.0:2.0 were estimated in terms of the absorption rate, regeneration rate and cyclic CO2 capacity using an improved rapid screening method. The experimental results showed that the highest cyclic CO2 capacities (i.e. low energy requirement) for the cyclic reaction time of 30 min and 60 min were obtained both by 1.0 M DMEA + 1.0 M MEA solution, indicating the synergistic effects existing in CO2 absorption into DMEA/MEA solution. Additionally, the mass transfer performance of CO2 absorption into 1.0 M DMEA + 1.0 M MEA solution was investigated in a hollow fiber membrane contactor. The effects of key operational parameters such as liquid velocity, inlet gas flow rate, CO2 partial pressure, feed temperature range, CO2 lean loading, amine concentration and membrane contactor height on the CO2 flux and overall gas phase mass transfer coefficient were investigated. Furthermore, a developed correlation was successfully applied for the prediction of overall gas phase mass transfer coefficient (KG) for CO2 absorption into DMEA/MEA solution, with an average absolute relative deviation (AARD) of 8.31%. Thus, a potential absorbent (i.e. DMEA/MEA) for CO2 capture was proposed in this work.

Removal of HSS from industrial amine solution by anionic resin (case study: Ilam gas refinery)

In this research, the removal of heat stable salts was considered as one of the most effective factors in the process of amine degradation. To remove this type of salts, ion-exchange method was used. A resin purification system was investigated to separate the heat stable salt ions of acetate, formaldehyde, chloride, oxalate, thiosulphate, sulphate, and sulphite from alkanolamine solution flowing in the Ilam gas refinery sweetening units. To remove the existing ions in the lean amine solution, a strong anionic resin designated as INDION GS 300 was tested. Ion-exchange systems operated in batch and continuous mode (fixed-bed column) were applied to remove these salts. The effects of different operating variables such as contact time, temperature, and amount of resin were examined. The optimum values of amount of resin and temperature found for both systems were 5 g and 25 °C, respectively. Furthermore, the optimum times for batch and continuous systems were 30 and 10 min, respectively. Results of experiments revealed that around 95.5 and 97% of salts were removed using batch and column operations, respectively. Moreover, the amine solution pH increased from 10 to 11, indicating a corrosion rate reduction in the amine system of the Ilam gas refinery.

Capacitive deionization performance of CNTs-Si-Ag based electrodes for the removal of heat stable salts from methyldiethanolamine (MDEA) solution in natural gas sweetening units

The presence of heat stable salts (HSS) in the gas sweetening absorption columns reduces the absorption capacity of the amine solutions. For the first time, the capacitive deionization (CDI) technique is used to clean the MDEA solutions from HSS. For this purpose, the hybrid material (CNTs-Si-Ag) was synthesized by using the sol–gel process followed by chemical reduction. This hybrid material was then utilized as CDI electrode material in order to remove the HSS from the lean amine solutions. TEM and SEM confirmed the well-ordered interconnected porous network containing silanized CNTs (carbon nanotubes) along with silver (Ag) nanoparticles. Nitrogen adsorption–desorption analysis and electrochemical studies (EIS and CV) evidenced the substantial conductivity, porosity, surface area and specific capacitance of the prepared material. The specific capacitance of the hybrid material was found to be 149.1 F g−1 at 10 mV s−1 heralding substantial electrosorption capacity for the removal of HSS. The continuous CDI experiments showed that the highest SAC of the newly prepared electrode is 21.5 mg g−1 with maximum ASAR of 0.17 mg g−1 min−1 under 1.0 V and the lowest SAC is 17.3 mg g−1 with ASAR of 0.12 mg g−1 min−1 under 0.8 V. This work introduced the CDI as a potential technique that can be used to clean amine solutions advantaged with its low maintenance, easy operation and environment friendliness.

A comparative study of novel activated AMP using 1,5-diamino-2-methylpentane vs MEA solution for CO2 capture from gas-fired power plant

Bench-scale pilot plant study of AMP and 1,5-diamino-2-methylpentane (DA2MP) blend for CO2 capture from gas-fired power plant is investigated. The concentration of the amine blend is 2 kmol/m3 AMP-1.5 kmol/m3 DA2MP while that of single solvent MEA is 5 kmol/m3. Comparative analysis was based on CO2 absorption efficiency (%), absorber mass transfer coefficient (KGav(ave), kmol/kPa h m3), desorber mass transfer coefficient (KLav, h−1), rich amine loading (αrich, mol CO2/mol amine), lean amine loading (αlean, mol CO2/mol amine), cyclic loading (CL, mol CO2/mol amine), cyclic capacity (CC, mol CO2/L-amine soln.), CO2 absorption rate (rabs, g-CO2/h), and regeneration energy (Qreg, GJ/tonne CO2). The contribution of sensible energy (Qsen, GJ/tonne CO2), vaporization energy (Qvap, GJ/tonne CO2), and desorption heat (ΔHdes, GJ/tonne CO2) towards Qreg was also investigated. Results showed that the AMP-DA2MP blend possess higher KGav(ave) (11.66%), KLav (7.67% higher), and CO2 absorption efficiency (4.66% higher) than MEA. Also, the superior cyclic loading (51.5%) and cyclic capacity (6.7%), and lower regeneration energy (13.8% lower) was observed for the AMP-DA2MP blend. The desorption heat (ΔHdes) was the major contributor to the Qreg of both amine systems however the ΔHdes of AMP-DA2MP was 23% lower than MEA. It was noticed that though the water concentration of the amine blend (60.7 wt%) is lower than MEA (70 wt%), the vaporization energy of the amine blend was 32.9% higher than MEA. Therefore, besides the amount of water concentration, higher desorber temperature profile, amine solvent vapor pressure and boiling point also increases the vaporization energy. The results is a revelation of possible reduction in capital cost and operating costs for the AMP-DA2MP blend compared to the standard MEA.

Process simulation and parametric sensitivity study of CO2 capture from 115 MW coal–fired power plant using MEA–DEA blend

This study used ProMax® 4.0 process simulator (rate–based model) to conduct a parametric sensitivity of carbon dioxide (CO2) capture from a 115 MW coal–fired power plant (Boundary Dam 3 power plant) using monoethanolamine (MEA) and diethanolamine (DEA) blend. Saskatchewan Power Corporation (SaskPower), Canada provided the flue gas composition used in this study. The validated simulation was used to determine the effects of some process variables (independent process variables) on different dependent process variables. The independent process variables are flue gas temperature (TFG, oC), lean amine temperature (TLA, oC), lean amine flow rate (FLA, tonne/day), lean amine concentration difference (CMEA–DEA, kmol/m3) and reboiler temperature (TREB, oC). The dependent process variables are MEA and DEA vaporization from the absorber, CO2 absorption efficiency (%), regeneration energy (GJ/tonne CO2), rich amine loading (RAL, mol CO2/mol amine) and lean amine loading (LAL, mol CO2/mol amine). Amine degradation was investigated by the O2 absorption rate (tonne O2/day), NO absorption rate (tonne NO/day) and NO2 absorption rate (tonne NO2/day). The vaporization rates of MEA (tonne MEA/day) and DEA (tonne DEA/day) were also investigated. The contribution of amine and water make–up costs, regeneration energy, pump electrical energy, blower electrical energy and compressor electrical energy towards variable operating expenditure (V–OPEX) were also investigated. Results showed that NO also contributes to amine degradation. From the parametric analysis it was observed that TREB has the greatest influence on most of the dependent process variables. It was also discovered that the regeneration energy, compressor electrical energy and amine, water make–up cost and cooling water contributed 82.5%, 12.3%, 1.1%, 0.9% and 0.5% of the V–OPEX respectively.

Revamping of an acid gas absorption unit: An industrial case study

This work evaluates the efficiency of the aqueous mixture of Methyl Diethanolamine (MDEA) and Diethanolamine (DEA) at various mass concentrations to remove CO2 and H2S from natural gas in an industrial sweetening unit in Fajr Jam Gas Refining Company located in the south of Iran and gives recommendations for modifying the process. The sweetening unit includes absorber and desorption towers, flash drum, lean and rich amine exchanger, kettle type reboiler and a reflux drum. The considered process is simulated by Promax simulator (version 3.2) taking into account operational constraints and sustainability of the environment. The validity of simulation has been evaluated by comparison between simulation results and the plant data. The main objective of this work is the modification of natural gas sweetening unit to achieve lower energy consumption. Thus, the effect of amine circulating rate and MDEA to DEA ratio on steam consumption in the regeneration tower, CO2 and H2S concentration in the treated gas, and the acid gas loadings have been investigated. Therefore, substitution of DEA solvent in the unit with the aqueous mixture of DEA and MDEA is proposed. In the examined cases, the mass concentration of MDEA and DEA lies between 15 and 45 wt% and 0–30 wt%, respectively, with the reference cases having MDEA 0 wt% and DEA 31.6 wt%. The results show that in the proposed cases of alternative mixtures including cases 1 (MDEA15 wt% and DEA 30 wt%), 2 (MDEA 20 wt% and DEA 25 wt%), and 3 (MDEA 25 wt% and DEA 20 wt%) the amount of reduction in amine circulation rate are between 11.1%v/v and 19.4%v/v compared to the original amine circulation rate. Likewise, steam consumption decreases between 24.4 %wt/wt and 27 %wt/wt. Influence of anti-foam injection for the different cases were also studied and it was found that anti-foam with the concentration of 5000 ppmv is more suitable for the optimum operation and is a more cost effective.

Analysis of energy demand for natural gas sweetening process using a new energy balance technique

ABSTRACTAbsorption by alkanolamine solvents is widely used for acid gas removal in natural gas sweetening plant. In the present research, one of the Iranian gas treating unit, Ilam Gas Treating Company (IGTC), with 3.27 mole % H2S and 3.76 mole % CO2 in the inlet feed gas was simulated using HYSYS V8.8. Piperazine activated solution of MDEA (PZ-MDEA) at various process operating conditions was examined to yield energy demand of natural gas sweetening process using a new energy balance technique. In this technique, the total required energy demand was related to three sections: 1. heat of vaporization, 2. sensible heat and 3. heat of the absorption. Energy balance of the absorption and regeneration columns brings a perspective of energy distribution in the sweetening plant. The effects of CO2 and H2S concentration at inlet feed, PZ mass fraction in activated solution of MDEA and lean amine temperature on energy distribution of the natural gas sweetening process and reboiler duty were investigated. It was finally elucidated that energy demand in the gas sweetening process or duty of reboiler is greatly influenced by heat of vaporization rate. It was also found that the heat of absorption and sensible heat have minor impacts on the energy demand.

Effect of hydrogen sulfide concentration in circulated amine solution on the treated gas in gas treatment plant

The concentration of dissolved hydrogen sulfide in circulated amine is necessary to be determined and calculated that useful to make a relationship with hydrogen sulfide in the treated gas after passing through the sweetening process in order to help to control the regeneration process when the research is containing the control system to improve the amine absorption capacity, regeneration efficiency and the concentration of H2S in treated gas for maintaining it under the specification value , Measurement of H2S in treated gas by GC-PFPD Shimadzu-2014 and determination of H2S loading by iodimetric titration in lean amine solution, the relationship between variables were satisfactory, means there is a directly proportional relationship between H2S in both Lean amine and Treated Gas according to increasing and decreasing.

The effect of increasing CO2concentration and flow rate on amine still performance in meeting gas sale specifications

The main purpose of this study is to examine the effect of increasing CO2removal and flow rate on performance of an amine still. The amine still is located in Field X in South East Sumatra at a new gas well producing gases with a rich CO2content. The still uses activated MDEA as the amine and has an IMTP 40-type packing column. Two film and desorption equilibrium curve theories were employed to analyse the amine still design conditions. Design equations were utilized to find the slope of the equilibrium curve. A slope of the equilibrium curve of 45° in the amine still is obtained in this study. The maximum liquid CO2composition of the amine still feedstock (xo) which can be separated to produce lean amine according to the specification design flow rate is 0.0307. The total flow rate of CO2-rich amine at xo= 0.029 is 761,157.6 kg/hour; the total flow rate of CO2-rich amine atxo= 0.0295 is 628,861.1 kg/hour; the total flow rate of CO2- rich amine at xo= 0.03 is 513,962.6 kg/hour; and the total flow rate of CO2-rich amine at xo= 0.0305 is 409,575.3 kg/hour.

Process simulation, parametric sensitivity analysis and ANFIS modeling of CO2 capture from natural gas using aqueous MDEA–PZ blend solution

Carbon dioxide (CO2) capture from natural gas is integral towards meeting pipeline sales gas specifications and avoiding operational problems during natural gas liquefaction. Therefore, it is important to understand how different process parameters would affect the performance of the CO2 capture process plant. In this research, CO2 capture from a typical Nigerian natural gas composition was simulated using ProMax® 4.0. The validated simulation was used to generate 3125 datasets while varying a number of process parameters. A parametric sensitivity analysis was conducted by varying lean amine flow rate (LAF, 3500–4300t/day), lean amine temperature (LAT, 40–60°C), lean amine pressure (LAP, 60–75bar), MDEA–PZ concentration difference (CMDEA–PZ, 36–44wt.%) and heat duty (HD, 50.4–56.52 GJ/h) to determine their effects on CO2 capture efficiency alongside foaming and amine vaporization. The parametric analysis showed that the LAF and MDEA–PZ concentration have the highest effect on the CO2 capture plant. In addition, 70% of the generated datasets was used to train the intelligent model named adaptive neuro–fuzzy inference system (ANFIS) while 30% was used for validation. Results revealed that the ANFIS model accurately predicted the simulation results with 2.4%AAD and RMSE of 4.0E-03, respectively.