Skip to main content

A comparative study of MEA and DEA for post-combustion CO2 capture with different process configurations

Abstract

This paper presented a comparative study of monoethanolamine (MEA) and diethanolamine (DEA) for post-combustion CO2 capture (PCC) process with different process configurations to study the interaction effect between solvent and process. The steady state process model of the conventional MEA-based PCC process was developed in Pro/II® and was validated with the experimental data. Then ten different process configurations were simulated for both MEA and DEA. Their performances in energy consumption were compared in terms of reboiler duty and total equivalent work. The results show that DEA generally has better thermal performances than MEA for all these ten process configurations. Seven process configurations provide 0.38%–4.61% total energy saving compared with the conventional PCC process for MEA, and other two configurations are not favourable. For DEA, except one configuration, other process configurations have 0.27%–4.50% total energy saving. This work also analyzed the sensitivities of three key parameters (amine concentration, stripper pressure and lean solvent loading) in conventional process and five process modifications to show optimization strategy.

Introduction

Carbon capture and storage (CCS) technology is considered to be the most effective technology to reduce greenhouse gas emissions in the future. The cost of CCS technology applied in fossil fuel power plant is about 40 to 60 $/t CO2 (Barry 2001), and the electricity price will increase by 45% when coupled with CCS (Le Moullec and Kanniche 2011b). Obviously, the application of CCS technology is limited by high energy consumption and high cost of capture process. Post-combustion CO2 capture (PCC) technology is widely studied now because it can be applied to most fossil fuel power plants, and among all kinds of PCC technology, chemical absorption with amine solutions is the most reliable and efficient method of CO2 capture. Many studies are found in the literature that discuss the two main paths to reduce energy consumption in CO2 capture process, developing new solvents and optimization of the process configurations (Oyenekan and Rochelle 2007; Aroonwilas and Veawab 2007; Le Moullec and Kanniche 2011a; Cousins et al. 2011).

Many kinds of amine have been studied in CO2 capture process, such as monoethanolamine (primary amine, MEA), diethanoamine (secondary amine, DEA) (Diab et al. 2013), methyldiethanoamine (tertiary amine, MDEA) (Zhang and Chen 2010) and aminomethylpropanol (sterically hindered primary amine, AMP) (Li et al. 2013), piperazine (heterocyclic amine, PZ) (Li et al. 2014) and so on. At present, MEA is still considered to be the main solvent in aqueous alkanolamine based capture processes because of its high absorption rate and low solvent cost as well as low regeneration heat requirement (Aaron and Tsouris 2005). Nevertheless, high energy requirement for stripping still exists due to the high heat of reaction with CO2 using MEA (around 85 kJ/mol CO2). Consequently, DEA could be taken into account for low pressure operations and it has a lower heat of reaction with CO2 (around 70 kJ/mol CO2). Secondary amines, like DEA, are much less reactive to sulphur components and their reaction products are not particularly corrosive. These all make DEA to be an attractive option for CO2 capture. However, A disadvantage of DEA is that it exhibits slow kinetics (Kohl and Nielsen 1997; Carson et al. 2000; Gabrielsen et al. 2005; Galindo et al. 2012; Warudkar et al. 2013).

However, most studies only evaluate process configurations for MEA solvent and the interaction between solvent and process is ignored (Le Moullec et al. 2014). Therefore, it is worth investigating the energy consumption of different amine solvents in different process. As a result, this work proposes a comparative study on CO2 capture process configurations between MEA and DEA, which is aiming to compare the thermal performances between MEA and DEA, as well as investigating the energy saving by different process configurations using MEA and DEA. Including the conventional capture process, ten process configurations are evaluated, which are inspired by the work of Le Moullec et al. (2014). The simulations are carried out with commercial software to calculate energy consumption for different process configurations with a CO2 compression process. For the further study and discussion, a detailed analysis is presented to study the effect of some significant parameters in capture process and the total energy consumptions of each condition are evaluated and compared.

Model development and validation

Chemical equilibrium of amine system

The chemistry of aqueous primary and secondary amines scrubbing CO2, like MEA and DEA, behave similarly in thermodynamics. In aqueous solutions, CO2 react in an acid–base buffer mechanism with alkanolamines. The acid–base equilibrium reactions in PRO/II are written as chemical dissociations following the approach taken by Kent and Eisenberg (1976):

$$ {\text{H}}_{ 2} {\text{O}} \leftrightarrow {\text{H}}^{ + } + {\text{OH}}^{ - } $$
$$ {\text{CO}}_{2} + {\text{H}}_{ 2} {\text{O}} \leftrightarrow {\text{HCO}}_{3}^{ - } + {\text{H}}^{ + } $$
$$ {\text{HCO}}_{3}^{ - } \leftrightarrow {\text{CO}}_{3}^{2 - } + {\text{H}}^{ + } $$
$$ {\text{REACOO}}^{ - } + {\text{H}}_{ 2} {\text{O}} \leftrightarrow {\text{REAH}} + {\text{HCO}}_{3}^{ - } $$
$$ {\text{REAH}} + {\text{H}}^{ + } \leftrightarrow {\text{MEAH}}_{2}^{ + } $$

where R represents an alkyl group, and REA equals to MEA, DEA here.

The chemical equilibrium constants for the dissociation reactions are represented by polynomials in temperature as follow:

$$ \ln K_{i} = A + \frac{B}{T} + \frac{C}{{T^{2} }} + \frac{D}{{T^{3} }}. $$

Process model development in PRO/II

As many commercial simulation softwares perform well in process simulation such as Aspen Plus, ProMax, PRO/II, CO2SIM and so on, PRO/II (version 9.0) is selected to be the simulation software in this work due to the simplicity and usability which fulfil the purpose of this study. In the simulation, the property system uses the amine packages in PRO/II and electrolyte algorithm is for calculation. An equilibrium stage is assumed in absorber and stripper of all the processes. With the amine packages already implemented in PRO/II, results obtained for MEA and DEA are valuable as the parameters have been regressed from a large number of sources for MEA and DEA systems and resulting in good prediction of phase equilibrium. The accuracy of the simulations using PRO/II can also be validated in the following part. Although equilibrium models are known to give quantitatively different results from rate-based models, the first step of approximation is equilibrium models and proposed methodology will be then extended to rate-based models (Rodríguez et al. 2011).

A typical CO2 capture process shows in Fig. 1, which is mainly consist of absorber, stripper and heat exchanger. The flue gas enters into the bottom of absorber and contacts with the counter-current lean CO2 loading solvent flow introduced from the top of the column. After CO2 absorption, the amine solvent becomes a rich CO2 loading flow, which exits absorber from the bottom and is pumped to stripper. Before being injected, the cold rich solvent will be pre-heated by hot lean solvent exiting from the bottom of stripper. Heated rich solvent enters into stripper to release CO2 and then becomes lean solvent again. Pure CO2 flow can be collected from the top of stripper for further processing and the amine solvent is cycled in two columns to capture CO2 continuously.

Fig. 1
figure 1

Conventional CO2 capture process

In process simulation of this work, the flue gas is made up of 10% CO2, 6% H2O, 84% N2 in volume, and the flue gas enters at 40 °C, 1.2 bar. As mentioned before, ideal equilibrium stages are used in simulating both absorber and stripper, and the stage number is 10, which is a feasible amount of stages proved in previous work (Warudkar et al. 2013). The operating pressure of absorber and stripper is 1 bar and 1.5 bar, respectively. A 0.1 bar pressure drop is set in two columns. The temperature pinch of heat exchanger is 10 °C. For reference simulation, 30 wt% MEA and 40 wt% DEA aqueous amine are used to capture 90% CO2 of flue gas, and the CO2 lean loading is set at 0.25 mol CO2/mol MEA and 0.1 mol CO2/mol DEA, which are all at their typical concentrations in various literatures and practice. All of these parameters are kept constant in the simulation of following process configurations in order to make effective comparison in energy consumption. For further study and discussion in this work, parameter changes will be highlighted individually.

Model validation

The work of Cousins et al. (2012) presented a lot of experimental data on CO2 capture pilot plant. This work selected the pilot plant data of 1/02/2011, 11/02/2011, 31/03/2011 to validate the process model, and the comparison of simulation and experiment is shown in Table 1. As all the parameters were kept the same with literature, a good agreement between simulation and experiment is obtained. Because of the neglect of kinetics, deviations around 5% on rich loading and CO2 capture ratio are acceptable. These results can validate the accuracy of process simulation.

Table 1 Comparison of pilot plant results with the simulation results for MEA

Process simulation results

Many studies and reviews of process modification have already been published in open literatures (Oyenekan and Rochelle 2007; Le Moullec and Kanniche 2011a; Cousins et al. 2011; Ahn et al. 2013; Le Moullec et al. 2014), which contain a variety of amine based capture process modifications for the purpose of energy consumption reduction. However, most studies only evaluate process configurations for MEA solvent and the interaction between solvent and process is ignored (Le Moullec et al. 2014). Therefore, it is worth investigating the energy consumption of different amine solvents in different processes. In this work, ten different process configurations are simulated using MEA and DEA solvent to compare their thermal performances and investigate the energy saving by different process configurations. To make a more valuable and comprehensive evaluation on energy consumption reduction, the performance is presented in terms of reboiler duty as well as the total equivalent work. The reboiler duty is calculated in process simulation with PROII based on given process parameters. And the calculation method for the total equivalent work will be described in the following Sect. 4.1. It is worth mentioning that all simulations are restrained to maintain the temperature of amine solution below 120 °C, which is to avoid the degradation of MEA and DEA. The lean solution temperature is 40 °C.

Intercooled absorber (ICA)

Intercooled absorber is a widely studied and used modification (Aroonwilas and Veawab 2007; Karimi et al. 2011). Absorption of CO2 is an exothermic process which will lead to the temperature rise in the absorber. This has a negative effect on thermodynamic driving force for absorption and it results to lower the solvent absorption capacity. Figure 2 illustrates that this modification is to remove a part or all of the liquid flow from the absorber at one of its stages, cooling it and then injecting it back at the same part. Intercooled absorber is efficient in control of the temperature in the absorber column which can increase the carrying capacity of the solvent and hence reduce the required amount of recycling solvent as well as the size of equipment. In simulation work, 5th stage temperature is cooled down to 45 °C for MEA and DEA. As a result, the rich CO2 loading reaches 0.492 mol CO2/mol MEA, which is 0.465 mol CO2/mol MEA in conventional process. For DEA, 0.468 mol CO2/mol DEA is obtained as only 0.447 mol CO2/mol DEA before. It is found that the cycled lean amine solvent is reduced by 11.5% for MEA and 4.7% for DEA. Thus, 7.1% of reboiler duty is saved by MEA and DEA gains 2.8%. ICA is more efficient for MEA than DEA due to the heat of reaction with CO2 is higher for MEA. In such favourable process in thermodynamics, MEA gains more benefits by cooling in absorber.

Fig. 2
figure 2

Intercooled absorber (ICA)

Flue gas pre-cooling (FGP)

Flue gas pre-cooling is a simple modification discussed in the work of Tobiesen et al. (2007) and Le Moullec and Kanniche (2011a). As Fig. 3 shows, flue gas is cooled to a lower temperature before introduced to absorber. The principle of flue gas pre-cooled is similar with the intercooled absorber to some extent, which also lowers the temperature of vapour-liquid mixture in absorber and enhances CO2 absorption in thermodynamic aspect. Thus, higher rich loading solvent and less reboiler duty are foreseeable. Flue gas is cooled to 30 °C in simulation, and around 5% reduction in reboiler duty is achieved with MEA, compared with a 2% saving with DEA.

Fig. 3
figure 3

Flue gas pre-cooling (FGP)

Rich solvent split (RSS)

This process modification is suggested as long ago as Eisenberg and Johnson (1979). In Fig. 4, it splits the cold rich loaded solvent into two flows, and the split one remains unheated when it enters the top of the stripper, while the other one is heated in the lean/rich heat exchanger and it is injected at lower stage. With the rich split modification, the heated rich solvent can reach a higher temperature at which CO2 can desorb more easily. Meanwhile, the vapour released from the rich solvent meets with the cold solvent injected above, which is able to strip a little CO2 from it. Thus, there is a reduction in reboiler duty. 10% of the rich solvent unheated is split to the top of stripper in simulation. There is a saving in reboiler duty of 7.7% by MEA and 7% by DEA. RSS has neutral effect on rich loading and solvent required as the absorption process remains the same. Different split rates larger than 10% are necessary to be used for further simulation.

Fig. 4
figure 4

Rich solvent split (RSS)

Rich solvent pre-heating (RSP)

As Herrin (1989) proposed, the cold rich solvent can be heated by the hot vapour exiting the stripper as Fig. 5 shows, which can make use of the latent heat and reduce the cooling water required in stripper condenser. It seems to be efficient because the rich solvent can be heated twice, however, due to the temperature of the hot vapour is exactly similar with the rich solvent temperature after heated by hot lean solvent, even a little lower, the heat transfer cannot exist if all rich solvent is heated. No energy reduction obtained in the simulation of MEA or DEA. But obvious benefits will be gained if combining rich solvent pre-heating with rich solvent split because heat can be transferred to the split cold rich solvent (Ahn et al. 2013). Then the wasted heat can be used and other principles of energy saving are the same with rich solvent split, no more tautology or simulation here.

Fig. 5
figure 5

Rich solvent pre-heating (RSP)

Solvent split flow (SSF)

The modification of split flow is first proposed by Shoeld (1934), which contains a partial regeneration cycle of lean solvent. A flow of semi-lean solvent is taken from the middle of the stripper, having heat exchange with the cold rich solvent and then injected to the middle of absorber. Among all the variant of split flow modifications, the most common one is described by Leites et al. (2003) and Aroonwilas and Veawab (2007) as Fig. 6. It is a combination of two modifications, simple split flow and rich solvent split. Furthermore, as the semi-lean solvent is cooled down before entering absorber, it also takes a little bit advantage of inter-cooling. Many parameters needs to be taken into account to reach a minimal energy consumption, for example, the stages to draw off semi-lean solvent from stripper and inject into absorber, the split fraction of cold rich solvent and semi-lean solvent, and the introduced stage of hot rich solvent. In principle and simulation, the semi-lean stream is drawing off from the middle of stripper to provide the cold rich solvent split with more heat. Since less rich solvent contacts with the hot lean solvent leaving stripper, hot inlet stream reaches higher temperature, then if it is injected at lower part of stripper, energy saving is further allowed. Optimal energy savings are found in simulation when taking all these factors into account. As a result, simulation shows that SSF can lead to a 7.6% of reduction on reboiler duty in MEA case, correspondingly with 7.8% in DEA.

Fig. 6
figure 6

Solvent split flow (SSF)

It is worth mentioning that the required amount of circulating solvent becomes larger in the solvent split flow modification than in the conventional process because the average solvent working capacity is lowered. Bigger equipments such as columns and pumps are required to match with the flow rate.

Rich solvent flashing (RSF)

The principle of the modification of rich solvent flashing is to flash the inlet stream of stripper before entering, as Fig. 7 illustrates. By flashing the hot rich solvent, a little more CO2 is gained whereas vaporization lowers the temperature of liquid phase. In fact, this flashing process is same with conducting separation process at an ideal stage. The phenomenon happens everywhere in stripper. As a result, this modification does not obviously reduce energy consumption except providing one more stripping stage. The simulation result in this work is the same with what Le Moullec and Kanniche (2011a) claimed.

Fig. 7
figure 7

Rich solvent flashing (RSF)

Stripper condensate bypass (SCB)

In the modification of stripper condensate bypass, the condensate liquid is not fed back to the top of stripper. Instead, this stream is directly injected to the absorber. This modification is used in the work of Oexmann and Kaher (2009) as Fig. 8. The simulation of this work provide a 0.6% reboiler duty saving with MEA and 0.4% with DEA, that is, stripper condensate bypass almost makes no difference in limiting energy consumption. Because of the small flow rate of condensate, the duty saving for heating it in stripper is restricted.

Fig. 8
figure 8

Stripper condensate bypass (SCB)

Stripper condensate heating (SCH)

The modification of stripper condensate heating is proposed and studied in Aroonwilas and Veawab (2007) and Ahn et al. (2013) as Fig. 9. As the vapour temperature is high at the top of stripper, stripper condensate heating is to make use of this to heat the stripper condensate, and then feeding the hot condensate back to the bottom of stripper to provide a little heat recovery. Nevertheless, it has been proved by theoretical analysis and simulation in this work that there is insignificant gain in energy consumption. Only 1% of reboiler duty is reduced both for MEA and DEA.

Fig. 9
figure 9

Stripper condensate heating (SCH)

Lean vapour compression (LVC)

Lean vapour compression is one of the most widely suggested modifications in a variety of literatures and patents, such as Batteux and Godard (1983), Reddy et al. (2007), Woodhouse and Rushfeldt (2008). As Fig. 10 shows, the principle is to flash the hot lean solvent at a lower pressure, then compressing the hot vapour generated and re-injecting it into the bottom of stripper. As the vapour benefits from the sensible heat of hot lean solvent as well as recompression, it can reach a very high pressure and temperature, which can provide additional steam and heat in the column for stripping. In the simulation, the hot lean solvent is flashed to the atmospheric pressure and the adiabatic efficiency of the compressor is 80%, and this modification shows significant savings in reboiler duty. With MEA, a 12.8% of reduction is obtained, and as for DEA, LVC allows a gain of 11.9% of reduction in reboiler duty. However, it should be noted that as a compressor introduced here, it leads to the additional electricity consumption that cannot be neglected, and the performance of total energy saving compared with the conventional process will be detailed discussed in the following part.

Fig. 10
figure 10

Lean vapour compression (LVC)

Discussions

Preliminary simulation results have been presented in previous part, and detailed simulation results and further discussion will be demonstrated in following paragraphs, including total energy consumption calculated for comparison and sensitivity analysis of three process operating key parameters.

Total work calculation

As mentioned before, the process modification of LVC introduces a compressor to generate vapour with high pressure and temperature, and the electricity consumption should not be neglected. Therefore, it is essential to investigate the total energy consumption to make a global comparison with the conventional process.

The equivalent work (W eq) is commonly used to evaluate the process configuration performance to unify the thermal and electrical energy consumptions. As there is a variety of expressions in calculating the total equivalent work, such as Le Moullec and Kanniche (2011a), Ahn et al. (2013), Van Wagener et al. (2013). The following equation from the work of Van Wagener and Rochelle (2011) and Liang et al. (2015) is chosen.

$$ {{W}_{{\rm{eq}}}} = 0.75 \times {{Q}_{{\rm{reb}}}}\left( {\frac{{{{T}_{\rm{i}}} + 10\;{\rm{K}} - {{T}_{{\rm{sink}}}}}}{{{{T}_{\rm{i}}} + 10\;{\rm{K}}}}} \right) + {{W}_{{\rm{comp}}}} + {{W}_{{\rm{add}}}}.$$

It uses a Carnot efficiency term which accounted for the increasing value of steam at high temperature. Additionally, 75% efficiency was applied to account for non-ideal expansion in the steam turbines. T i is the reboiler temperature (K); 10 K means the temperature of steam in the reboiler is 10 K higher than T i; Q reb is the reboiler duty (GJ/t CO2); T sink is the cold end temperature of Carnot engine, and set at 313 K here; W comp is the compression work (GJ/t CO2); W add is the additional equipment work such as the compressor in LVC (GJ/t CO2).

As for calculating the compression work, the following correlation from the work of Le Moullec and Kanniche (2011a) can be used.

$$ {W}_{\text{comp}} = 8.3673 + 22.216 \ln {P}_{\text{F}} - \left( 27.118 + 0.0256{P}_{\text{F}} \right) \ln {\it{P}}_{\text{S}} $$

where W comp is the compression work (kWh/t CO2); P F is the final delivery pressure, and set P F as 110 bar here; P S is the initial pressure of compression, and stripper pressure is used, 1.5 bar here. So values of W comp for all cases are 100.66 kWh/t CO2, i.e., 0.362 GJ/t CO2.

The total equivalent work of each process configurations described previously is shown in Table 2 for MEA and Table 3 for DEA. All the process modifications apart from RSF and RSP exhibit lower energy consumption for MEA. As for DEA, only RSF has negative effect.

Table 2 Total equivalent work of process configurations using MEA
Table 3 Total equivalent work of process configurations using DEA

Sensitivity analysis of key parameters

Effect of amine concentration and lean solvent loading in conventional process

The loading of the lean amine solution is a significant factor in reducing the energy consumption. More solvent is required to be circulated when the lean loading is high in order to capture the same amount of CO2. The reboiler heat duty is rather sensitive to the solvent flow rate as the vaporization of water for CO2 stripping contributes most to the reboiler duty at low solvent flow rate values. In contrast, if lean loading is extremely low, more heat is provided by the reboiler duty as the heat of reaction between amines and CO2 accounts for the majority. As for amine concentration, it will affect the solvent capture capacity because low rich loading will be obtained if a more concentrated solution is used. And the proportion of water increases when diluted solution is implemented. These will all lead to a further reduction of reboiler duty. It can be observed in Figs. 11 and 12 that the optimal lean loading increases with MEA concentration rising. The minimum of reboiler duty occurs at approximately 0.17 mol CO2/mol MEA in 30 wt% MEA. When DEA was used, it was noticed that irrespective of the concentration used, the optimal lean loading is obtained around 0.05 mol CO2/mol DEA. It also can be concluded that the reboiler duty is more sensitive to lean loading in process using MEA. And these curves reveal furthermore that at higher amine concentrations, the flexibility of process increases because change in the lean loading will have a minor effect. Galindo et al. (2012) and Dinca (2013) also claimed the same point of view.

Fig. 11
figure 11

Effect of MEA concentration and CO2 loading of lean solvent on reboiler duty

Fig. 12
figure 12

Effect of DEA concentration and CO2 loading of lean solvent on reboiler duty

Effect of stripper pressure in conventional process

It is a common view that the operating pressure of the stripper is a key parameter of reboiler duty reduction, which has been reported in many publications such as Oyenekan and Rochelle (2007). There is also a process modification proposed by Oyenekan and Rochelle (2006) and Le Moullec and Kanniche (2011a), which is to operate the stripper at vacuum/sub-ambient pressure. CO2 desorption becomes easier as stripper pressure is high. From another perspective, if stripper pressure is higher, the temperature in the reboiler is also higher, and then higher pressure steam is required for solvent regeneration. Therefore, the influence of stripper pressure should be evaluated in total equivalent work to search for the optimal strategy. Figure 13 illustrates the results of simulation for conventional process, and it indicates that both for MEA and DEA, higher pressure is slightly beneficial to reducing total energy consumption because of higher reboiler temperature.

Fig. 13
figure 13

Effect of stripper pressure on total equivalent work in the conventional process

Effect of lean solvent loading for process modifications

As the principle and simulation results mentioned previously, the loading of the lean amine solution is of great significance in the energy consumption reduction. And the simulation results indicated that the reboiler heat duty is rather sensitive to the lean loading. Thus, it is essential to simulate all the processes to come up with the optimal energy saving strategies. The process modification of ICA, RSS, SCH, LVC, SSF are selected to make comparison with the conventional process according to previous simulation results and discussion, as these configurations present better performance in term of reducing energy consumption. The result shows in Fig. 14 for MEA and Fig. 15 for DEA. As for MEA, all the total equivalent work of these processes have a minimum point as the lean loading is increasing. In conventional process, ICA, and SCH, the minimums occur at approximately 0.18 mol CO2/mol MEA, and it rises to 0.22 mol CO2/mol MEA for RSS and SSF. In contrast, minimum of LVC appears at around 0.16 mol CO2/mol MEA because the heat provided by compressed vapour is pretty effective. At lower lean CO2 loading, the total equivalent work of RSS, SCH, SSF is higher than conventional process due to a larger amount of circulating solution. As a whole, the total equivalent works of these configurations for MEA are in the following order, LVC < ICA < RSS < SSF < SCH < conventional process.

Fig. 14
figure 14

Compare total equivalent work between different process configurations at different lean loading of MEA

Fig. 15
figure 15

Compare total equivalent work between different process configurations at different lean loading of DEA

Correspondingly, the results of processes using DEA appear somewhat different from MEA. The trends of conventional process, SCH, LVC are quite the same as all of them have a minimum point at the lean CO2 loading of about 0.15 mol CO2/mol DEA. ICA raises this point to 0.2 mol CO2/mol DEA while SSF lowers it to 0.1 mol CO2/mol DEA. The total equivalent work of RSS has an obvious change as the minimum point occurs at 0.15 mol CO2/mol DEA. The energy consumption of SSF is higher than the conventional process due to lower working capacity of amine and a larger amount of circulating solution. In general, the total equivalent works of these configurations for DEA are in the following order, RSS ~ SSF < LVC < ICA < SCH < conventional process. Compared with LVC is more favourable to MEA, it can be concluded that RSS or the variant of RSS are more efficient to DEA, because CO2 is easier released from DEA solution in thermodynamics.

Conclusions

In this work, ten different process configurations have been simulated both for MEA and DEA on the same operating conditions. As a result, process modifications are proved to be an efficient way to optimize the energy consumption in CO2 capture process using MEA and DEA. It has been shown that LVC, ICA, FGP, RSS, SSF are favourable in MEA, as from 3.17% to 4.61% of total equivalent work are reduced respectively in preliminary simulation. And for DEA, RSS, SSF, LVC have better performance, as from 2.70% to 4.50% are reduced.

Meanwhile, this work presents the influence of three operating parameters in energy savings, namely, amine concentration, stripper pressure, and loading of lean amine solvent. The study of amine concentration and lean loading in conventional process shows that the optimal lean loading increases with MEA concentration rising, but it basically keeps constant in DEA. Moreover, reboiler duty is more sensitive to lean loading in processes using MEA than DEA. Both for MEA and DEA, higher pressure is beneficial to reducing total energy consumption in all of the processes. The effect of lean solvent loading on process modifications for MEA and DEA is pretty different, and the minimum point of total equivalent work also depends on amine type and process. RSS or the variant of RSS are more efficient to DEA, and LVC and ICA is more favourable to MEA. Further work on blended amines weill be carried out latter.

References

  • Aaron D, Tsouris C (2005) Separation of CO2 from flue gas: a review. Sep Sci Technol 40(1–3):321–348

    Article  Google Scholar 

  • Ahn H, Luberti M, Liu Z et al (2013) Process configuration studies of the amine capture process for coal-fired power plants. Int J Greenhouse Gas Control 16:29–40

    Article  Google Scholar 

  • Aroonwilas A, Veawab A (2007) Heat recovery gas absorption process. Patent No. WO 2007/107004 A1

  • Barry H (2001) IEA report: carbon dioxide capture from power stations

  • Batteux J, Godard A (1983) Process and installation for regenerating an absorbent solution containing gaseous compounds. Patent No. US 4384875 A1

  • Carson JK, Marsh KN, Mather AE (2000) Enthalpy of solution of carbon dioxide in (water + monoethanolamine, or diethanolamine, or N-methyldiethanolamine) and (water + monoethanolamine + N-methyldiethanolamine) at T = 298.15 K. J Chem Thermodyn 32(9):1285–1296

    Article  Google Scholar 

  • Cousins A, Wardhaugh LT, Feron PHM (2011) Preliminary analysis of process flow sheet modifications for energy efficient CO2 capture from flue gases using chemical absorption. Chem Eng Res Des 89(8):1237–1251

    Article  Google Scholar 

  • Cousins A, Cottrell A, Lawson A, Huang S, Feron PHM (2012) Model verification and evaluation of the rich-split process modification at an australian-based post combustion CO2 capture pilot plant. Greenhouse Gas Sci Technol 2:329–345

    Article  Google Scholar 

  • Diab F, Provost E, Laloué N et al (2013) Effect of the incorporation of speciation data in the modeling of CO2–DEA–H2O system. Fluid Phase Equilib 353:22–30

    Article  Google Scholar 

  • Dinca C (2013) Comparative analyses of primary and secondary amines for CO2 chemical Process capture in a CFBC pilot installation. J Clean Energy Technol 1(3)

  • Eisenberg B, Johnson RR (1979) Amine regeneration process. No. US 4152217

  • Gabrielsen J, Michelsen ML, Stenby EH et al (2005) A model for estimating CO2 solubility in aqueous alkanolamines. Ind Eng Chem Res 44(9):3348–3354

    Article  Google Scholar 

  • Galindo P, Schäffer A, Brechtel K et al (2012) Experimental research on the performance of CO2-loaded solutions of MEA and DEA at regeneration conditions. Fuel 101:2–8

    Article  Google Scholar 

  • Herrin JP (1989) Process sequencing for amine regeneration: U.S. Patent 4,798,910

  • Karimi M, Hillestad M, Svendsen HF (2011) Investigation of intercooling effect in CO2 capture energy consumption. Energy Procedia 4:1601–1607

    Article  Google Scholar 

  • Kent RL, Eisenberg B (1976) Better data for amine treating. Hydrocarbon Processing 55(2):87–90

    Google Scholar 

  • Kohl AL, Nielsen R (1997) Gas purification. Gulf Professional Publishing, Houston

    Google Scholar 

  • Le Moullec Y, Kanniche M (2011a) Screening of flowsheet modifications for an efficient monoethanolamine (MEA) based post-combustion CO2 capture. Int J Greenhouse Gas Control 5(4):727–740

    Article  Google Scholar 

  • Le Moullec Y, Kanniche M (2011b) Optimization of MEA based post combustion CO2 capture process: flowsheeting and energetic integration. Energy Procedia 4:1303–1309

    Article  Google Scholar 

  • Le Moullec Y, Neveux T, Al Azki A et al (2014) Process modifications for solvent-based post-combustion CO2 capture. Int J Greenhouse Gas Control 31:96–112

    Article  Google Scholar 

  • Leites IL, Sama DA, Lior N (2003) The theory and practice of energy saving in the chemical industry: some methods for reducing thermodynamic irreversibility in chemical technology processes. Energy 28(1):55–97

    Article  Google Scholar 

  • Li H, Li L, Nguyen T et al (2013) Characterization of piperazine/2-aminomethylpropanol for carbon dioxide capture. Energy Procedia 37:340–352

    Article  Google Scholar 

  • Li H, Frailie PT, Rochelle GT et al (2014) Thermodynamic modeling of piperazine/2-aminomethylpropanol/CO2/water. Chem Eng Sci 117:331–341

    Article  Google Scholar 

  • Liang Z, Gao H, Rongwong W et al (2015) Comparative studies of stripper overhead vapor integration-based configurations for post-combustion CO2 capture. Int J Greenhouse Gas Control 34:75–84

    Article  Google Scholar 

  • Oexmann J, Kather A (2009) Post-combustion CO2 capture in coal-fired power plants: comparison of integrated chemical absorption processes with piperazine promoted potassium carbonate and MEA. Energy Procedia 1(1):799–806

    Article  Google Scholar 

  • Oyenekan BA, Rochelle GT (2006) Energy performance of stripper configurations for CO2 capture by aqueous amines. Ind Eng Chem Res 45(8):2457–2464

    Article  Google Scholar 

  • Oyenekan BA, Rochelle GT (2007) Alternative stripper configurations for CO2 capture by aqueous amines. AIChE J 53(12):3144–3154

    Article  Google Scholar 

  • Reddy S, Gilmartin J, Francuz V (2007) Integrated compressor/stripper configurations and methods. Patent No. WO/2007/075466, Fluor Technologies Corporation

  • Rodríguez N, Mussati S, Scenna N (2011) Optimization of post-combustion CO2 process using DEA–MDEA mixtures. Chem Eng Res Des 89(9):1763–1773

    Article  Google Scholar 

  • Shoeld M (1934) Purification and separation of gaseous mixtures. Patent No. US 1971798

  • Tobiesen FA, Svendsen HF, Mejdell T (2007) Modeling of blast furnace CO2 capture using amine absorbents. Ind Eng Chem Res 46(23):7811–7819

    Article  Google Scholar 

  • Van Wagener DH, Rochelle GT (2011) Stripper configurations for CO2 capture by aqueous monoethanolamine. Chem Eng Res Des 89(9):1639–1646

    Article  Google Scholar 

  • Van Wagener DH, Rochelle GT, Chen E (2013) Modeling of pilot stripper results for CO2 capture by aqueous piperazine. Int J Greenhouse Gas Control 12:280–287

    Article  Google Scholar 

  • Warudkar SS, Cox KR, Wong MS et al (2013) Influence of stripper operating parameters on the performance of amine absorption systems for post-combustion carbon capture: part I. High pressure strippers. Int J Greenhouse Gas Control 16:342–350

    Article  Google Scholar 

  • Woodhouse S, Rushfeldt P (2008) Improved absorbent regeneration. Patent No. WO, 2008, 63079: A2

  • Zhang Y, Chen CC (2010) Thermodynamic modeling for CO2 absorption in aqueous MDEA solution with electrolyte NRTL model. Ind Eng Chem Res 50(1):163–175

    Article  Google Scholar 

Download references

Acknowledgements

This work was supported by National Science and Technology Support Program of China (No. 2015BAC04B01), EU FP7 Marie Curie International Research Staff Exchange Scheme (Ref: PIRSES-GA-2013-612230).

Author information

Affiliations

Authors

Corresponding author

Correspondence to Jian Chen.

Rights and permissions

Open Access This article is distributed under the terms of the Creative Commons Attribution 4.0 International License (http://creativecommons.org/licenses/by/4.0/), which permits unrestricted use, distribution, and reproduction in any medium, provided you give appropriate credit to the original author(s) and the source, provide a link to the Creative Commons license, and indicate if changes were made.

Reprints and Permissions

About this article

Verify currency and authenticity via CrossMark

Cite this article

Xue, B., Yu, Y., Chen, J. et al. A comparative study of MEA and DEA for post-combustion CO2 capture with different process configurations. Int J Coal Sci Technol 4, 15–24 (2017). https://doi.org/10.1007/s40789-016-0149-7

Download citation

  • Received:

  • Revised:

  • Accepted:

  • Published:

  • Issue Date:

  • DOI: https://doi.org/10.1007/s40789-016-0149-7

Keywords

  • Process simulation
  • CO2 capture
  • Energy consumption
  • MEA
  • DEA