Download Hi-Res ImageDownload to MS-PowerPointCite This:Energy Fuels 2023, 37, 16, 12030-12044

Environmental and Carbon Dioxide IssuesAugust 7, 2023

Prospects of the Novel CSAR Concept for Fully Electric or Flexible Electric–Thermal Hybrid CO₂ Capture from CHP Plants
Click to copy article linkArticle link copied!

Schalk Cloete
Schalk Cloete
Process Technology Department, SINTEF Industry, Trondheim 7034, Norway
More by Schalk Cloete
Chaitanya Dhoke
Chaitanya Dhoke
Process Technology Department, SINTEF Industry, Trondheim 7034, Norway
More by Chaitanya Dhoke
https://orcid.org/0000-0001-5580-1962
Davide Bonalumi
Davide Bonalumi
Department of Energy, Politecnico di Milano, Milano 20156, Italy
More by Davide Bonalumi
https://orcid.org/0000-0002-4116-0532
John Morud
John Morud
Process Technology Department, SINTEF Industry, Trondheim 7034, Norway
More by John Morud
Antonio Giuffrida
Antonio Giuffrida
Department of Energy, Politecnico di Milano, Milano 20156, Italy
More by Antonio Giuffrida
Matteo Carmelo Romano
Matteo Carmelo Romano
Department of Energy, Politecnico di Milano, Milano 20156, Italy
More by Matteo Carmelo Romano
Abdelghafour Zaabout*
Abdelghafour Zaabout
Process Technology Department, SINTEF Industry, Trondheim 7034, Norway
ACER CoE Center, University Mohammed 6 Polytechnic, Ben Guerir 43150, Morocco
*Email: [email protected]. Tel: +4793008204.
More by Abdelghafour Zaabout
https://orcid.org/0000-0002-7468-8050

Open PDF Supporting Information (1)

Energy & Fuels

Cite this: Energy Fuels 2023, 37, 16, 12030–12044

Click to copy citationCitation copied!

https://doi.org/10.1021/acs.energyfuels.3c00885

Published August 7, 2023

CC-BY 4.0 .

Abstract

Click to copy section linkSection link copied!

Momentum is gathering behind the goal of achieving net-zero CO₂ emissions by 2050 in Europe and around the world. Negative emissions via biomass or waste combustion with CO₂ capture can make net zero considerably easier to achieve. This study investigates CO₂ capture from combined heat and power (CHP) plants that often use bio-based fuels. However, most CO₂ capture processes require large amounts of heat, potentially consuming most of the CHP plant’s primary product. The novel continuous swing adsorption reactor (CSAR) concept provides a promising solution by capturing CO₂ using electrically driven heat and vacuum pumps. Techno-economic assessments conducted in this work illustrate that CSAR clearly outperforms an MEA benchmark when the CHP plant sells heat throughout the year (MEA would need a heat price below 10 €/MWh at an electricity price of 60 €/MWh to compete). When large amounts of free heat are available in summer months, MEA becomes more attractive, but a flexible CSAR configuration utilizing free heat during summer maintains a clear advantage for CSAR (MEA needs a heat price below 15 €/MWh at an electricity price of 60 €/MWh). Stronger competition arises from advanced solvents such as PZ/AMP that can match CSAR at almost double the heat price of MEA. Still, CSAR will remain attractive in most cases, especially for retrofits where considerable capital expenditures would be required to provide existing heat customers with an alternative heat supply if solvent technologies are used. Thus, CSAR appears to be a promising technology for achieving negative emissions from CHP plants.

This publication is licensed under

CC-BY 4.0 .

License Summary*
You are free to share(copy and redistribute) this article in any medium or format and to adapt(remix, transform, and build upon) the material for any purpose, even commercially within the parameters below:
- Creative Commons (CC): This is a Creative Commons license.
- Attribution (BY): Credit must be given to the creator.
View full license
*Disclaimer
This summary highlights only some of the key features and terms of the actual license. It is not a license and has no legal value. Carefully review the actual license before using these materials.
License Summary*
You are free to share(copy and redistribute) this article in any medium or format and to adapt(remix, transform, and build upon) the material for any purpose, even commercially within the parameters below:
- Creative Commons (CC): This is a Creative Commons license.
- Attribution (BY): Credit must be given to the creator.
View full license
*Disclaimer
This summary highlights only some of the key features and terms of the actual license. It is not a license and has no legal value. Carefully review the actual license before using these materials.

Subjects

1. Introduction

Click to copy section linkSection link copied!

CO₂ capture and storage (CCS) can play a prominent role in reducing global CO₂ emissions. The application of CCS to fossil fuel energy infrastructure can avoid most of the greenhouse gases that would otherwise accumulate in the atmosphere. Furthermore, CCS can enable net greenhouse gas removal if the captured CO₂ originates from biomass or directly from the atmosphere. The potential negative emission enabled by CCS is a key reason why the IPCC found that achieving decarbonization pathways consistent with the Paris Agreement (1) will be more than twice as costly (and possibly not even practically achievable) without CCS. (2) The recent IEA special report on CCS agrees that reaching net-zero emissions without CCS will be virtually impossible. (3) Most of the scenarios in the IPCC report on 1.5° of global warming also rely on large amounts of negative emissions. (4) Scenarios without negative emissions tend to require substantial reductions in global energy demand that are not realistic in a world where almost 5 billion people still live on less than 10 $/day. (5)

CCS from biomass combustion (BECCS) is generally viewed as the most economical pathway to large-scale CO₂ removal and is relied upon heavily in the aforementioned assessments. However, biomass production has large land-use impacts that can strongly reduce its CO₂ avoidance and increase its overall environmental impact. Depending on the assumptions regarding direct and indirect land-use changes associated with BECCS, life cycle CO₂ emissions could even remain positive after 50 years of operation. A sensitivity analysis by Fajardy and Dowell (6) indicates a range of CO₂ emissions of −1000 to 200 ton/ha over a 50-year operating life, depending on various assumptions when miscanthus is used. Woody biomass from willow performs worse, returning mostly positive lifecycle emissions.

An alternative is waste-to-energy (WTE) where lifecycle emissions can be low or even slightly negative before any CCS is applied due to the CO₂ avoided by energy recovery from this fuel that would otherwise end up in landfills (which is associated with CH₄ emissions) or be incinerated without energy recovery. (7) Here, a distinction should be drawn between negative life cycle emissions and CO₂ removal: WTE can achieve negative emissions by avoiding emissions from alternative fossil-based energy supply and methane from landfills that would otherwise occur, but it cannot remove CO₂ from the atmosphere. However, the addition of CCS to WTE plants can unlock not only negative life cycle emissions but also net CO₂ removal if the CO₂ capture ratio and the biogenic fraction in the waste are sufficiently high.

From an economic viewpoint, applying CCS to WTE plants that produce only electricity has a severe negative effect on levelized costs. Due to the challenging nature of the fuel, these plants typically operate at low efficiencies, producing large amounts of CO₂ per unit of electricity produced. Capturing and compressing all this CO₂ consumes more than half of the power output, causing high costs. (8,9) More efficient CO₂ capture can lower these high costs, prompting investigations involving various advanced CO₂ capture technologies, including moving bed temperature swing adsorption, (10) calcium looping, (11) and vacuum swing adsorption. (12)

For CHP plants that extract a much larger amount of useful energy from the fuel, adding CCS can be considerably cheaper. For example, addition of CCS becomes feasible at a CO₂ tax around 30–40 €/ton in a combined heating, cooling, and power plant with biomass co-firing. (13) However, such attractive costs require very-low-grade heat to be usable for district heating so that heat from exothermic CO₂ capture reactions and flue gas condensers can be productively used (in this case, (13) heated water is assumed to leave the plant at 94 °C and return at 43 °C). Another study shows 63 €/ton in CO₂ avoidance costs when the CHP plant is integrated with a geothermal heat source. (14) There is also a potentially large addressable market for CHP plants in providing heat for CO₂ capture retrofits. This strategy can be cheaper than direct CO₂ capture from coal plants with a CO₂ tax requirement of 55 $/ton (∼50 €/ton). (15) Industrial CHP offers another interesting application, where the addition of CCS can increase the average load on the plant and thus its efficiency. (16) Although not yet economically assessed, another interesting possibility involves running the CO₂ capture facility only when excess heat is available (e.g., in summer when district heating load is low), avoiding the large cost of steam for solvent regeneration. (17)

The real-world plant (Twence, the Netherlands) studied in this work produces hot water at 120 °C and has it return from the network at 60 °C. Such elevated temperatures allow the heat to be used for a wider range of purposes and transported over longer distances before becoming too cold due to heat losses. Under such conditions, it is not possible to recover very-low-grade heat from the CO₂ capture system, meaning that CO₂ capture relying on thermal regeneration of the solvent/sorbent becomes more costly as a large fraction of the valuable heat product is lost. CO₂ capture methods that operate on electricity (e.g., vacuum/pressure swing adsorption (18)) would better suit such applications. However, the relatively low CO₂ content in WTE flue gases is not well suited to CO₂ capture processes relying only on a vacuum/pressure swing, resulting in low CO₂ purities in a single-stage process. (12) Two-stage processes can achieve acceptable CO₂ purities, although the deep vacuums required for reasonable efficiency and productivity (e.g., 7.5 kPa (18)) are unlikely to be achievable in practice. (19)

The present study investigates another fully electrified option based on the swing adsorption reactor cluster (SARC) concept (20,21) that maintains efficient operation for more dilute flue gases. SARC uses a combined temperature and vacuum swing through a synergistic combination of heat and vacuum pumps. The vacuum reduces the required temperature swing, ensuring that the heat pump can transfer heat from adsorption to regeneration at a high efficiency. (22) A novel variant of the SARC process, the continuous swing adsorption reactor (CSAR) detailed in the subsequent section, will be investigated. Besides the lower energy penalty, CSAR also allows for flexible operation between electricity to power the heat and vacuum pumps or excess steam available in summer months. As an additional novelty, the present study will quantify the economic benefit of such flexibility to use excess heat, both for the novel CSAR process and the benchmark MEA process.

2. Continuous Swing Adsorption Reactor (CSAR)

Click to copy section linkSection link copied!

The SARC concept has two primary drawbacks arising from its working principle where both adsorption and regeneration steps take place in each single SARC reactor: (1) the reactor and heat transfer tubes must be heated and cooled together with the sorbent in each temperature swing, increasing the load on the heat pump and (2) sorbent in the lower regions of the reactor experiences a higher pressure in regeneration reducing the achievable sorbent working capacity. These drawbacks are addressed in the CSAR concept presented in the present study. In CSAR, the sorbent is circulated between two reactors for adsorption and regeneration, where lock hoppers are used to facilitate the sorbent transfer across the pressure difference. Although lock hoppers are well-known process units, sorbent circulation between the two CSAR reactors is yet to be demonstrated and presents the most important technical uncertainty for the scale-up of the technology.

Figure 1 shows the working principle of the CSAR concept, with the main equipment being numbered to aid in the process description that follows. Warm flue gas is fed to the adsorber (1) where it is contacted in a counter-current manner with the falling sorbent to capture CO₂. Such an adsorber could be designed as a single fluidized bed with perforated plate separators (20) or as stacked fluidized beds. (23) The heat in the flue gas is transferred to the sorbent for mild preheating before it is circulated to the desorber (3) via the bottom lock hopper (2). The carbonated sorbent flows into the bottom lock hopper under gravity when it is closed to the desorber side and open to the adsorber side. When the lock hopper is full, it is closed to the adsorber side and opened to the desorber side where the vacuum pressures evacuate the sorbent from the lock hopper and initiate the release of CO₂ (and potentially H₂O if the sorbent has also the ability to adsorb H₂O such as polyethylene amine used in the SARC concept demonstration (20)). This gas release then drives the sorbent up into the desorber (2) where heat is supplied by the heat pump (6). The heat pump transfers heat from the exothermic reaction in the adsorber to the endothermic regeneration to drive additional CO₂ and H₂O release (combined temperature and vacuum swing). The released CO₂ and H₂O are extracted at vacuum pressure by the main vacuum pump (7) where water is condensed out and CO₂ is fed to the CO₂ liquefaction section.

Figure 1. Illustration of the CSAR working principle.

The hot regenerated sorbent at the top of the desorber then falls into the top lock hopper (4) that was brought to the same vacuum pressure as the desorber by the small evacuation pump (8). Once the lock hopper is filled, it is closed, and an air valve is opened to repressurize the lock hopper. Once pressurized, the lock hopper is opened to the adsorber side to allow the sorbent to fall into the cooler (5). Here, the heat pump (6) cools the sorbent under a minimal fluidization with air (the small air stream results in minimal losses of CO₂ in the cooler outlet) so that the equilibrium CO₂ partial pressure is reduced when the sorbent is fed to the top of the adsorber.

To further reduce the equilibrium CO₂ partial pressure and ensure maximum CO₂ removal from the flue gas, cooling water at a temperature below that of the heat pump working fluid is used to extract heat at the top of the adsorber (1). From a global energy balance point of view, this heat removal is necessary to balance the heat input from the warm flue gas and the heat generation in the heat pump. In the lower regions of the adsorber, more heat is removed by the heat pump working fluid to limit the temperature rise caused by the exothermic CO₂ and H₂O adsorption.

Another interesting benefit of reducing the sensible heat load and increasing the sorbent working capacity relative to the SARC concept is that the system can also be operated in normal temperature swing adsorption (TSA) mode when cheap heat is available. This would be a relevant case for CHP plants that supply lots of heat in winter, but much less in summer. Thus, in summer, the heat that would otherwise be rejected can be used for CO₂ capture instead of consuming electricity through the heat and vacuum pumps. The present study will quantify the market conditions where a CHP plant will benefit from such seasonal flexibility as opposed to the CSAR concept operating only on electricity throughout the year and conventional MEA CO₂ capture that uses heat to regenerate the solvent.

When operating in TSA mode, a separate desorber with a much smaller cross-sectional area, a taller height, and a smaller heat transfer surface area will be required, mildly increasing the capital cost of the system. The cross-sectional area of the unit must be reduced because it will operate at atmospheric pressure, implying that a dilute fluidization regime is needed to minimize the pressure drop and allow particles to flow from the bottom of the adsorber to the bottom of the desorber. In addition, the higher pressure will strongly reduce the gas volume flowrate relative to CSAR operation. Even though a substantial quantity of heat will be required, the temperature difference between the reactor and the steam available from the WTE plant is relatively high, reducing the heat exchanger surface area required.

Heat removal from the adsorber and cooler remain similar as indicated in Figure 1. However, the heat pump working fluid is no longer compressed, but rather sent to an external fin-fan air cooler to condense the fluid and reject the heat from the exothermic adsorption. The condensed working fluid is then pumped back to the adsorber and cooler to remove heat via evaporation as in the normal CSAR operation. Heat removal by cooling water at the top of the adsorber stays unchanged. The lock hoppers will be bypassed when the unit operates in TSA mode using the dedicated regeneration column because the two reactors will operate at similar pressures.

3. Methodology

Click to copy section linkSection link copied!

The combined reactor, process, and economic modeling methods used for this study are discussed in three sections below.

3.1. CSAR Reactor Modeling

The CSAR reactor system was modeled under the following simplifying assumptions, which have been experimentally validated for the SARC process (22)

The reactor can be considered as a series of continuous stirred tank reactors (CSTR). A CSTR is typically a good conceptual representation of well-mixed fluidized beds.
The reactor contains solid material and gas, the latter of which is represented as a mixture of ideal gases─a valid assumption in this low-pressure system.
There is thermal and chemical equilibrium between gas and solid. Gas-particle heat transfer is extremely fast in fluidized beds, ensuring thermal equilibrium. Experiments have also shown that reaction rates are fast with the chosen sorbent, (20) closely approximating chemical equilibrium.

3.1.1. Chemistry

Chemical adsorption of CO₂ on the amine (Am) group of the sorbent and physical adsorption of H₂O are described as follows

\begin{array}{l} Am + {CO}_{2} (g) \leftrightarrow {AmCO}_{2} Δ H = - 75 kJ / m o l \\ H_{2} O (g) \leftrightarrow H_{2} O (ads) Δ H = - 43 kJ / m o l \end{array}

(1)

The equilibrium sorbent loading of CO₂ (q_CO₂) [mol/kg] is described in the Toth isotherm as follows (24) (the model coefficients for eqs 2 to 5 are shown in Table 1)

q_{C O_{2}} = \frac{n_{s} {bp}_{{CO}_{2}}}{{(1 - {({bp}_{{CO}_{2}})}^{t})}^{1 / t}}

(2)

n_{s} = n_{s, 0} \exp (X (1 - \frac{T}{T_{0}}))

(3)

b = b_{0} \exp (\frac{d H}{R T_{0}} (\frac{T_{0}}{T} - 1))

(4)

t = t_{0} + α (1 - \frac{T_{0}}{T})

(5)

Table 1. Model Coefficients for Use in Equations 2 to 5

n_s,0	X	b₀	dH	t₀	α	T₀
2.146	0.317	38.25	104,581	0.497	1.273	303

For H₂O, a linear fit with the relative humidity (φ) was used. (24)

q_{H_{2} O} = {\begin{array}{l} 5.69 φ + 0.2528 \\ 37.66 φ if φ < 0.0087 \end{array}

(6)

These single-component isotherms can be safely used as no significant multicomponent effects were observed between CO₂ and H₂O for the sorbent used in this study. (24)

3.1.2. Mass and Energy Balances

The following mass balance is solved for gas and solid in each CSTR

\begin{array}{l} \frac{d N}{d t} = F^{in} y^{in} - F y + S_{g}^{T} R \\ \frac{d M}{d t} = G^{in} x^{in} - G x + S_{s}^{T} R \end{array}

(7)

Here, N [kmol] is a vector containing the gas holdup of each gas species; Fⁱⁿ and F [kmol/s] are the gas flow rates into and out of the CSTR; Gⁱⁿ and G [kg/s] are the solids flow rates into and out of the CSTR; y = N/sum(N) [−] is a vector of gas mole fractions (CO₂, H₂O, O₂, and N₂); x = M/sum(M) [−] is a vector of solids mass fractions (Am, AmCO₂, and H₂O(ads) in eq 1); M [kg] is a vector of the mass holdup for each solid species; S is the stoichiometric matrix; and R is a vector of chemical reaction rates. The reaction rates are fast so as to satisfy the chemical equilibria in each CSTR, under the validated assumption that chemical equilibrium will be achieved with the selected sorbent. (20)

A single energy balance is solved for each CSTR, assuming thermal equilibrium between the gas and solid phases

(M^{T} C_{p, m, s} + N^{T} C_{p, g}) \frac{d T}{d t} = F^{in} (C_{p, g}^{T} y^{in}) (T_{g}^{in} - T) + G^{in} (C_{p, m, s}^{T} x^{in}) (T_{s}^{in} - T) - R^{T} Δ H + Q

(8)

Here, C_p,m,s [J/kg·K] and C_p,g [J/kmol·K] are vectors of solids and gas species heat capacities, respectively; T [K] is the reactor temperature; T_gⁱⁿ and T_sⁱⁿ [K] are the inlet temperatures of the gas and solids phases, respectively; ΔH [J/kmol] is a vector of the enthalpies of reaction; and Q [W] is heat added or removed via the heat transfer surfaces. No heat losses to the environment are considered for this low-temperature industrial-scale system. The solids heat capacity was set to 1500 J/kg/K as specified by the supplier.

Heat addition or removal via the heat transfer surfaces is modeled as follows, using an experimentally demonstrated heat transfer coefficient of 400 W/m²/K (20)

Q = UA Δ T

(9)

Here, A [m²] is the total heat transfer surface area, U [W/m²K] is the heat transfer coefficient, and ΔT [K] is the temperature difference between the reactor and the heat transfer fluid. The working fluid temperature is set to a constant value in each reactor, and these temperature assumptions are used in the subsequent process model to calculate the power consumption of the heat pump. The cooling water used at the top of the adsorber (Figure 1) is also assumed to be at a constant temperature (35 °C), even though it would increase by 10 °C between the inlet and the outlet. Hence, the implicit assumption is that the inlet and outlet water temperatures are set below and above the assumed average temperature so as to achieve the total heat transfer rate calculated using the average temperature in eq 9.

Finally, the ideal gas equation of state is used for the gas, as follows

p V_{g} = sum (N) R_{0} T

(10)

Here, p [Pa] is the pressure; V_g [m³] is the gas volume; and R₀ [J/kmol·K] is the universal gas constant. Appropriate pressure levels are set in each CSTR, imposing atmospheric pressure at the top of the adsorber and 0.2 bar at the top of the desorber. In addition, the pressure is increased linearly toward the bottom of the adsorber and the desorber to account for pressure drops of 0.1 and 0.2 bar in these two reactors, respectively.

3.1.3. Solution Method

The system of equations for the network of coupled CSTRs was solved using ode15s, which is a differential-algebraic equation solver in Matlab, employing default settings. The solution was initialized using constant values in all CSTRs derived from the inlet flue gas stream.

3.1.4. CSAR in VTSA and TSA Modes

The CSTR control volumes were linked together as illustrated in Figures 2 or 3, depending on whether the system was operated in VTSA mode (heat and vacuum pumps) or TSA mode (steam).

Figure 2. CSTR control volume network used to simulate the CSAR reactor system in VTSA mode.

Figure 3. CSTR control volume network used to simulate the CSAR reactor system in TSA mode.

Both cases featured a counter-current adsorber with heat extraction and a co-current desorber with heat addition. In VTSA mode, the heat is added and removed primarily by the heat pump (using ammonia as working fluid), although additional heat is removed by cooling water at the top of the adsorber (control volume 5 in Figure 2). Additional heat removal is needed to extract heat added to the system by the hot flue gas and the heat pump (which adds more heat than it removes due to the addition of electrical energy). Using cooling water at a lower temperature than the heat pump working fluid at the top of the adsorber reduces the equilibrium CO₂ partial pressure to maximize CO₂ capture from the flue gas. Heat removal from the cooler (control volume 6 in Figure 2) is also completed by the heat pump. The heat pump working fluid evaporation temperature was set to 55 °C, while the cooling water was set to 35 °C (water enters at 30 °C and exits at 40 °C). The amount of cooling water was automatically adjusted in the simulation to satisfy the overall energy balance.

The VTSA desorber operated at a vacuum of 0.2 bar. Although deeper vacuums could bring further cost reductions, (25) this vacuum level was selected to respect practical limits in large-scale vacuum systems. (19) CO₂ capture of 90% was ensured by automatically adjusting the condensation temperature of the heat pump working fluid, controlling the degree of sorbent regeneration achieved. In this case, a temperature of 81.2 °C was needed, while the average temperature of the sorbent was about 6 °C lower to drive the heat transfer.

To realistically represent the undesired gas mixing in the lock hoppers in VTSA mode, the gas streams were split and mixed as illustrated in Figure 2. In the bottom lock hopper (control volume 12), a certain fraction of the cooled flue gas exiting control volume 1 was split off to flow with the sorbent to the desorber. This gas leakage rate was set as the amount of gas that leaks out when the lock hopper is opened to the side of the desorber, assuming that the lock hopper is charged to a solids volume fraction of 0.5 when open to the adsorber side. In the top lock hopper (control volume 7), the gas that is displaced by the sorbent falling into the lock hopper when charged to a solids volume fraction of 0.5 is assumed to leak to the desorber. Both these effects cause a decrease of the CO₂ purity.

During TSA operating mode in summer, heat is still removed by the heat pump working fluid (specified at 50 °C), but rather than being upgraded to a higher temperature by the heat pump compressor for transfer to the desorber, it is rejected at the same temperature in the air cooler. This avoids the use of the heat pump compressor and limits the size of the air cooler due to the significant temperature difference between the working fluid and the ambient. Water is still used to remove heat from the top of the adsorber at a lower temperature of 40 °C (5 °C higher than in VTSA mode to limit the air cooler size with the higher ambient temperature). A smaller desorber, operating at atmospheric pressure and 106.7 °C, is used with a smaller heat transfer surface area due to the availability of steam at 139 °C from the CHP plant. The heat transfer surface area is automatically adjusted in the model to achieve 90% capture. The heat pump, vacuum pumps, and VTSA desorber are idle during this operating mode.

Gas leakage through the bottom lock hopper (control volume 12 in Figure 3) is approximated by calculating the volume of gas that is dragged with the sorbent flowing to the desorber. At the assumed sorbent volume fraction of 0.5, this means that gas and sorbent volume flows are equal. However, it is assumed that the lock hoppers are still active, only being used to limit gas leakage. When the charged lock hopper is opened to the desorber side, there will not be a sufficiently large pressure difference to suck out a significant amount of gas with the sorbent and the only gas leakage would occur from gas mixing caused by the sorbent falling out of the lock hopper. To account for this effect, the gas volume leakage from the adsorber to the desorber, which reduces CO₂ purity, was specified as only half of the sorbent volume flow. This same mechanism was assumed to take place in the top lock hopper (control volume 7): a gas volume flow equal to half the sorbent flow leaks from the desorber to the cooler where the CO₂ is lost to the atmosphere.

The sorbent circulation rate was optimized manually for VTSA and TSA operating modes, minimizing the heat pump power demand in VTSA mode and the desorber heat transfer surface area requirement in TSA mode. VTSA mode required triple the flowrate of TSA mode (300 relative to 100 kg/s of fully regenerated sorbent) because the sorbent working capacity is limited by the relatively small temperature swing that had to be enforced to maximize heat pump efficiency. In TSA mode, on the other hand, the large temperature swing results in a large sensible heat requirement to heat and cool the sorbent, increasing the importance of capturing more CO₂ during each temperature swing by ensuring a larger sorbent working capacity, which allows for a lower circulation rate.

3.1.5. Model Uncertainties

As mentioned earlier, the CSAR model is based on an experimentally validated model of the SARC concept. (22) The CSAR and SARC reactors are both multistage fluidized beds using the same sorbent that is regenerated by a combined temperature and pressure swing. Thus, the following validated assumptions from the SARC model are directly transferrable to the CSAR model:

The high reactivity of the chosen sorbent makes chemical equilibrium a good assumption.
Horizontal perforated plates can successfully restrict axial mixing and this effect can be represented by modeling the reactor as CSTRs in series.
A good heat transfer coefficient of around 400 W/m²/K can be achieved in the fluidized bed.

However, the conceptual difference between CSAR and SARC introduces three unvalidated assumptions into the model. As outlined below, the associated uncertainties should be relatively small.

The lock hopper system achieves a steady circulation rate. As mentioned earlier, successful circulation between the CSAR reactors remains to be demonstrated. In addition, there will be a transient element to the circulation from the opening and closing of the lock hoppers. However, an industrial system will employ multiple lock hoppers working in a coordinated manner to transfer a near-steady stream of sorbent between the reactors.
Counter-current flow can be achieved in the adsorber while still limiting axial mixing. Unlike the SARC reactor where the fluidized sorbent is kept in a single reactor, the sorbent must slowly descend through the CSAR adsorber. Since the holes in the horizontal perforated plates are large enough to allow particles to pass through (22) and the average sorbent velocity is low (0.02–0.03 m/s), such downward particle transport should happen naturally under continuous sorbent addition at the top and extraction at the bottom.
Successful TSA operation in summer mode. The SARC validation experiments always used a vacuum in desorption, so desorption via pure TSA was not tested. However, the sorbent used in the experiments was originally developed for a pure TSA application, and earlier SARC proof-of-principle experiments showed predictable behavior in pure TSA operation. (26)

Another important uncertainty is related to long-term sorbent stability. Good chemical stability has been demonstrated over 800 cycles in a dual fluidized bed laboratory setup, (27) and a low attrition index of 2.5 was measured in a standardized test, (27) which compares favorably to commercial fluidized bed catalysts. (28) CSAR may further improve sorbent longevity because it operates under gentler fluidization (without cyclones) and lower desorption temperatures than the dual circulating fluidized bed arrangement usually considered for pure temperature swing adsorption applications. Lower desorption temperatures will be beneficial for long-term stability because PEI sorbents exhibit a strong thermal deactivation mechanism, (29) although functionalization with 1,2-epoxybutane significantly increases the feasible operating temperature. (30)

3.2. Process Modeling

The WTE plant flue gas and heat availability were provided by the Twence CHP plant in the Netherlands as summarized in Table 2. CO₂ capture from this flue gas was modeled for the CSAR process and an MEA benchmark as outlined in the two subsections below.

Table 2. Flue Gas Details and Heat Availability from the Simulated CHP Plant

			mol fraction
flue gas flowrate (kg/s)	temperature (°C)	pressure (kPa)	CO₂	H₂O	O₂	N₂	heat available (MW)	steam temperature (°C)
65.7	164.3	101.4	0.095	0.167	0.076	0.662	62.1	139

3.2.1. CSAR Process Model

Two process schemes for capturing CO₂ by CSAR integration to the CHP plant are developed and modeled in Aspen Plus for winter and summer operation (both modes depicted in Figure 4 and Table 4) under the assumptions detailed in Table 3.

Figure 4. Process scheme for winter and summer mode operation of the CSAR process. Continuous lines represent winter mode, and dashed lines represent summer mode.

Table 3. Key Assumptions in the CSAR Process Simulations

parameter	values	units
CO₂ & NH₃ compressor isentropic efficiency	0.85
CO₂ & NH₃ compressor mechanical efficiency	0.95
number of stages in CO₂ liquefaction	3
intercooling temperature	30	°C
number of stages in refrigeration cycle	3
targeted CO₂ liquefaction pressure	33.8	bar
pressure drop in heat exchanger	1% of inlet pressure
winter air temperature	7.5	°C
summer air temperature	15	°C
absorber pressure drop	0.1	bar
flue gas inlet temperature	164.3	°C
capture ratio	90	%
regeneration pressure in winter mode	0.2	bar
regeneration pressure in summer mode	1	bar

In winter mode, the flue gas from the CHP plant (stream 1) is fed to the adsorber via a blower (stream 2) to overcome the pressure drop in the adsorber. The flue gas is contacted in a counter-current mode in the adsorber to capture CO₂ from the flue gas and the CO₂ lean stream (3) is vented to the atmosphere. A combined temperature and vacuum swing is used in the desorber to release the captured CO₂ (stream 4) which is fed to the multistage compressor (stream 5) after being brought to atmospheric pressure by the vacuum pump. The compressed CO₂ stream (stream 6) is dried to prevent ice formation and fed to the cryogenic section to liquify the captured CO₂ (stream 7). The cooling duty required for liquefaction is supplied by a 3-stage refrigeration cycle using NH₃ as a working fluid. Heat is continuously removed from the adsorber and the cooler via another NH₃ heat pump by evaporating the working fluid (stream 14) and added to the desorber by condensing the working fluid (stream 12).

In summer mode, the desorber is operated under TSA mode using the available steam (stream 12-S) from the CHP plant that would otherwise have to be rejected due to a lack of heat demand in summer. The temperature in the adsorber is still controlled by extracting heat by evaporating the heat pump fluid (stream 11-S). In this case, however, the heat from stream 14-S is rejected to air in an additional air cooler to condense the working fluid before it is sent back to the adsorber. As summer mode is operated under TSA mode under atmospheric pressure, captured CO₂ (stream 4-S) is fed directly to the compression section, bypassing the vacuum pump (Table 4).

Table 4. Stream Data for the CSAR Process Simulations According to the Numbering in Figure 2

				(mol fraction)
stream number	pressure (bar)	temperature (°C)	mass flowrate (kg/s)	N₂	CO₂	H₂O	O₂	NH₃
flue gas
1	1.00	164.3	65.72	0.662	0.095	0.167	0.076
2	1.10	177.2	65.72	0.662	0.095	0.167	0.076
winter mode
3	1.00	47.5	50.86	0.854	0.012	0.036	0.098
4	0.20	74.1	14.73	0.011	0.380	0.608	0.002
5	1.01	99.0	9.25	0.026	0.899	0.0721	0.004
6	33.81	31.7	8.97	0.028	0.967	0.002	0.004
7	33.47	–28.0	8.93	0.026	0.970		0.004
8	1.10	–31.0	1.99					1.000
9	1.10	9.2	2.11					1.000
10	11.82	98.9	2.52					1.000
11	23.21	54.8	21.57					1.000
12	42.82	115.0	25.34					1.000
13	42.82	81.1	25.34					1.000
14	23.21	54.8	21.57					1.000
summer mode
3	1.00	49.3	51.87	0.836	0.011	0.061	0.095
4-S	1.00	106.6	13.76	0.004	0.420	0.575	0.001
6	33.81	31.7	8.84	0.009	0.988	0.002	0.001
7	33.47	–28.0	8.84	0.009	0.990		0.001
8	1.10	–31.0	1.99					1.000
9	1.00	9.7	2.12					1.000
10	11.83	98.9	2.52					1.000
11-S	20.41	50.2	29.47					1.000
14-S	20.51	50.2	29.47					1.000

3.2.2. MEA Process Model

One process scheme for capturing CO₂ by MEA integration to the CHP plant is developed and modeled in Aspen Plus. The scheme is shown in Figure 5, while the assumptions are the same as those outlined in Table 3.

Figure 5. MEA capture plant process scheme.

The chemical absorption of CO₂ of the MEA-based capture plant is an electrolyte process, so a suitable thermodynamic model is required to describe the process. A thermodynamic model available in Aspen Plus was used; it is based on the ELECNRTL property model and allows rate-based calculation.

The flue gas from the CHP plant is fed at the bottom of the contact cooler column in which an air-cooled water flux is distributed at the top of the column to achieve a final temperature of the flue gas of about 40 °C. This decreases the volumetric flow rate of the gas and brings the temperature to the proper one to be processed in the absorber that it is reached via a blower to overcome the pressure drops. The flue gas is treated in a counter-current mode in the absorber, which is 8.2 m in diameter with a packing height of 18 m, to capture CO₂ by a downward-flowing lean CO₂-loaded solvent. Here occurs the exothermic chemical absorption of CO₂. The solvent at the bottom of the absorber is a CO₂-rich stream pumped to a recuperative heat exchanger, increasing the temperature before reaching the desorber. The solvent regeneration occurs by reversing the chemical reaction using heat added via steam condensation in the reboiler, with the heat input being adjusted to achieve a 90% capture ratio. From the bottom of the desorber, the hot CO₂-lean stream is sent to the recuperative heat exchanger. The CO₂ exits from the top of the desorber and is cooled in a condenser that eliminates most of the H₂O. Subsequently, the CO₂ is liquified using the same process as in CSAR. The summary of stream data is provided in Table 5.

Table 5. Stream Data for the MEA Capture Plant Simulations According to the Numbering in Figure 5

				(mol fraction)
stream number	pressure (bar)	temperature (°C)	mass flowrate (kg/s)	N₂	CO₂	H₂O	O₂	MEA
flue gas
1	1.00	164.3	65.72	0.662	0.095	0.167	0.076
2	0.96	40.0	61.66	0.733	0.105	0.078	0.084
3	1.10	50.1	61.66	0.733	0.105	0.078	0.084
4	1.01	52.5	54.12	0.780	0.010	0.121	0.089
5	1.05	53.8	288.79		0.054	0.882		0.113
6	1.83	115.6	279.89		0.037	0.885		0.113
7	1.50	39.7	281.25		0.036	0.887		0.112
8	1.50	39.8	8.96		0.950	0.050
9	33.47	–28.0	8.70		1.000

The MEA process is investigated in conventional mode where it operates throughout the year and in a flexible mode where it operates only in summer when heat is available for free. Unlike CSAR that can continue operations during winter on electrical energy, such idling during winter months will increase the levelized capital cost in exchange for avoiding the cost of consuming the heat product of the plant.

3.3. Economic Assessment

The economic assessment was completed using the open Standardized Economic Assessment (SEA) tool, (31) with the full economic assessment spreadsheets available online^a and as Supporting Material. Details can be found in the SEA User Guide. (32)

The SEA tool is a bottom-up economic assessment framework where capital costs are assessed in detail, largely using correlations from Turton et al. (33) A correlation from Woods (34) was used for the vacuum pump. The resulting costs were then added up to yield the bare erected cost of the plant and increased using various factors to the total overnight cost as outlined in Table 6. All costs are adjusted for currency, year, and location.

Table 6. Conversion of Total Installed Costs of All Major Equipment to Total Capital Requirement for Constructing the Plant

bare erected cost (BEC)	sum of all installed equipment costs
Process contingency (PSC)	20% of BEC for CO₂ capture units, 0% otherwise
Engineering procurement and construction (EPC)	8% of BEC
Project contingency (PTC)	15% of (BEC + PSC + EPC)
Total plant costs (TPC)	BEC + PS + EPC + PTC
Owner’s cost (OC)	15% of TPC
Total overnight costs (TOC)	TPC + OC

All relevant operating costs are added and a cash flow analysis is completed to find the levelized cost of liquified CO₂, i.e., the CO₂ value needed to reach a net present value of zero at the chosen discount rate, plant lifetime, and construction period. In other words, the liquid CO₂ stream is treated as a revenue source that recuperates the expense of building and operating the CO₂ capture and liquefaction facilities (assuming that the plant will receive payments for capturing biogenic CO₂ for negative emissions). No CO₂ transport and storage costs are included as this will be highly case-dependent for such small facilities. For example, the real-world plant simulated in this work plans to sell CO₂ to nearby greenhouses at a profit. The main economic assumptions are detailed in Table 7.

Table 7. Key Assumptions in the Economic Assessment

currency, year, location	Euros (€), 2020, North Europe
discount rate	8%
economic lifetime	25 years
construction period	2 years
first year and general capacity factor	65% and 90%
fixed operating costs	4.5% of TOC per year
base case electricity and heat costs	60 and 30 €/MWh
sorbent cost	15 €/kg
solvent cost	2 €/kg

Fixed operating costs account both for routine maintenance and insurance. For the flexible CSAR and MEA plants, it was assumed that this cost is only 3% of TOC per year for all of the plant components that are only used for half the year. It can be reasonably assumed that these components will require considerably less maintenance than components that are used throughout the year.

Electricity and heat costs are highly case-dependent and are therefore varied in a sensitivity analysis presented in Section 4.

4. Results and Discussion

Click to copy section linkSection link copied!

Results are presented and discussed in three sections: (1) technical results, (2) economic results, and (3) mapping the competitiveness of the three investigated plant configurations across different electricity and heat prices.

4.1. Technical Results

Table 8 shows the technical performance of the three plants. The blower consumption in the CSAR plants is considerably higher than in MEA due to the conservatively high pressure drop assumed. Experimental tests have shown rapid CO₂ adsorption (20) that should allow for an attractively short and/or dilute adsorber, but the counter-current fluidized bed operation of CSAR may require a taller bed with a large pressure drop. Experimental demonstration is required before more optimistic assumptions can be considered.

Table 8. Electricity Consumption from the Three Different Plants during Summer and Winter (kW)

	CSAR		Flex CSAR		MEA
Item	winter	summer	winter	summer	winter	summer
blowers	1007.6	1007.6	1007.6	1007.6	682.0	682.0
heat pump	2772.9	2772.9	2772.9	0.0	0.0	0.0
vacuum pumps	1400.4	1400.4	1400.4	0.0	0.0	0.0
CO₂ liquefaction	3620.8	3620.8	3620.8	3565.1	2954.9	2954.9
air coolers	257.1	556.1	257.1	782.8	591.1	1094.8
MEA pumps	0	0	0	0	402.5	402.5
water pumps	4.5	4.5	4.5	4.5	73.0	71.1
total	9063.3	9362.4	9063.3	5360.0	4703.5	5205.3

Aside from CO₂ liquefaction, the heat and vacuum pump used to regenerate the sorbent represents the main power consumption in the CSAR concept, whereas the MEA concept requires 33 MW of heat (more than half of the CHP plant’s heat output) to regenerate the solvent. Due to the efficiency of the heat pump, the electrical energy required for sorbent regeneration in CSAR is almost 8 times lower than the thermal energy needed in MEA. Even though electricity is more valuable than district heat, this large difference in energy consumption promises a considerable economic benefit from CSAR. Coincidentally, Flex CSAR also uses 33 MW of heat for sorbent regeneration in summer, but this heat is assumed to be available at no cost. The sorbent used in CSAR has a lower regeneration enthalpy than MEA, but a large amount of water is also adsorbed from the flue gas and CSAR does not use any heat integration between the warm sorbent from the desorber and cold sorbent from the adsorber, bringing the total heat duty to a similar level as MEA.

CO₂ liquefaction costs are higher for CSAR than MEA due to the lower CO₂ purity (∼97% relative to 100% for MEA) and the slightly pressurized state (1.5 bar in this case) at which the MEA process produces CO₂. Flex CSAR achieves 99% purity in summer mode due to avoiding the gas leakage associated with pressure changes in the lock hoppers during conventional CSAR operating mode.

The greatest difference between winter and summer power consumption is related to air coolers. During summer, much greater cooler fan consumption is required due to the higher ambient temperature assumed (15 °C in summer vs 7.5 °C in winter). The MEA process needs to reject the most heat, resulting in the largest air cooler fan power consumption.

Water pump power consumption is higher for MEA due to greater heat rejection requirements. During summer operation, Flex CSAR reduces water consumption because heat is rejected directly from the ammonia circuit in the adsorber and the cooler.

4.2. Economic Results

The comparison between CSAR and the MEA benchmark is shown in Figure 6. The full details behind this figure can be viewed online^b or in the Supporting Material in the open access economic assessments completed with the SEA tool.

Figure 6. Breakdown of liquified CO₂ costs for the different technologies assuming electricity and heat prices of 60 and 30 €/MWh, respectively.

The figure differentiates cases with and without large amounts of heat that cannot be sold in the summer. Such free heat is positive for processes relying on a temperature swing such as MEA and the flexible CSAR configuration. Figure 6 shows that the MEA process returns only slightly higher costs for capturing and liquifying CO₂ than the CSAR configurations when it can operate on free heat 50% of the time. However, when no free heat is available, it becomes 40% more expensive than CSAR due to the large cost of heat for regenerating the solvent.

The flexible CSAR configuration returns the lowest cost when free heat is available. Due to the assumption that fixed O&M is reduced by a third on the equipment that is only used for half the year; the sum of capital and fixed O&M costs is similar between the CSAR and Flex CSAR configurations. Thus, the reduced electricity consumption by the Flex CSAR configuration during summer months when it runs on free heat significantly reduces overall costs. If O&M costs are not reduced on equipment used only half the year, liquified CO₂ costs increase by 1.7 €/ton.

Operating the MEA benchmark in a flexible mode where it is idled during winter months does not appear to be profitable if free heat is available only 50% of the year. The reduced capital utilization causes the levelized capital costs to double and the fixed O&M cost to increase by a third. These increases exceed the benefits of avoiding the consumption of heat valued at 30 €/MWh.

The MEA process returns lower capital costs than the CSAR options. Figure 7 illustrates that this is mainly due to the avoidance of the additional turbomachinery involved in the heat and vacuum pumps (included in the “Other equipment” category). The CSAR plants also involve significantly higher heat rejection costs, mainly due to the added costs involved in cooling the vacuum pressure stream exiting the desorber. Furthermore, the higher CO₂ purity and pressure delivered by MEA also reduce CO₂ liquefaction compressor costs relative to CSAR. On the other hand, CSAR brings large savings on vessels and heat integration, despite its larger desorber. The three main reasons for the substantially lower cost of CSAR in this category are: (1) CSAR uses carbon steel equipment, whereas MEA uses stainless steel clad vessels and stainless steel heat exchangers to resist corrosion from the MEA solvent, (2) CSAR avoids the recuperator which imposes a substantial cost in the MEA plant due to the large MEA flowrate and the narrow temperature approach in this heat exchanger, and (3) CSAR processes the hot flue gas directly, whereas MEA employs an additional direct contact cooler to cool the flue gas. Finally, the flexible CSAR configuration faces higher capital costs due to the need for the extra desorber and air cooler.

Figure 7. Capital cost breakdown of the three plants. “Other equipment” comprises blowers and flue gas coolers for MEA, while the heat and vacuum pump costs dominate this category for the CSAR plants.

Significant uncertainty exists regarding the costs of the large-scale heat and vacuum pumps employed in the CSAR concept. Figure 8 explores this uncertainty, revealing that changes to the costs of these units have a moderate but significant effect on the liquified CO₂ cost from the CSAR plant. Even so, large cost escalations (well beyond 50%) will be required to drive the cost of CSAR above that of MEA, even in the case where free heat is available for half the year.

Figure 8. Effect of CSAR heat and vacuum pump costs on its competitiveness against the MEA benchmark. The heat pump includes the heat pump compressor, the NH₃ drum, and the heat exchanger surfaces inside the reactors.

4.3. Sensitivity to Electricity and Heat Prices

The value of the heat and electricity sold by a CHP plant can vary strongly from case to case. For example, when the CHP plant competes with natural gas heating, a good benchmark could be natural gas prices (with an appropriate addition for CO₂ emissions). Comparative costs between the distribution networks of hot water and natural gas represent another important factor. When the CHP plant competes with electric heating, heat may have a similar value to electricity. For systems where electric load peaks in the heating season, CHP can bring large added benefits by reducing the costly electricity distribution capacity required. Heat pumps complicate this comparison further by trading lower electricity consumption for higher capital costs.

CO₂ capture retrofits that consume some of the plant’s electricity or heat production introduce additional complexity in this valuation exercise. For example, when a CHP plant installs CO₂ capture that consumes more than half the heat output during the heating season, most existing heat customers need to transition to a different solution (or additional CHP capacity needs to be built). Such a transition may involve substantial additional capital expenses and an under-utilization of the existing hot water distribution system, leading to a high cost of the heat consumed by the CO₂ capture plant.

For these reasons, the 30 €/MWh heat price assumed in the previous section may be conservatively low. It represents natural gas at a price of 5.5 €/GJ and a CO₂ price of 50 €/ton and ignores the capital cost implications discussed in the previous paragraph. As shown in Figure 9 (left), higher heat prices strongly increase the cost of the MEA benchmark, whereas CSAR is unaffected. Such cases where the loss of heat supply capacity is very costly present a strong business case for electrically powered CO₂ capture technologies like CSAR.

Figure 9. Effect of heat and electricity prices on the liquified CO₂ costs resulting from the CSAR and MEA plants considered in this study. 50 and 0% in the legend refer to the fraction of free heat available during the year.

Elevated electricity prices affect CSAR more than MEA, but the difference is relatively small, given that MEA also consumes a substantial amount of electricity for running blowers, pumps, air coolers, and CO₂ liquefaction compressors (Table 8). Higher electricity prices are possible when electricity from the CHP plant is used in a decentralized manner, avoiding some electricity transmission and distribution capacity from the centralized grid.

The regions where CSAR and MEA are the preferred solutions are indicated by the solid lines in Figure 10. The availability of free heat benefits the MEA benchmark, even when the flexible CSAR configuration is employed. This is shown by MEA being competitive at higher heat prices with 50% free heat than when no free heat is available. In general, MEA needs unrealistically low heat prices to be the preferred solution, especially when no free heat is available.

Figure 10. Combinations of electricity and heat prices where MEA (solid line) and CSAR are the preferred options with and without the availability of free heat during summer months. Approximated performance of an advanced PZ/AMP solvent (dashed line) is also included as a stricter benchmark.

A more advanced piperazine amino-methyl-propanol (PZ/AMP) solvent achieving 25% lower energy demand and 5% lower capital costs than MEA (35) is also included in Figure 10 (dashed lines) as a more competitive benchmark. In this case, CSAR requires considerably higher heat prices to outcompete the solvent technology. When no free heat is available, CSAR will remain the preferred solution in most cases as the heat price required by PZ/AMP to compete remains unrealistically low. However, when 50% free heat is available, PZ/AMP presents a more attractive solution that may outcompete CSAR in some cases. For example, Figure 10 (right) shows that CSAR and PZ/AMP present equivalent economic performance with the base case heat (30 €/MWh) and electricity (60 €/MWh) prices assumed in this study.

5. Conclusions

Click to copy section linkSection link copied!

Combined heat and power (CHP) plants often use difficult-to-combust fuels like waste and low-grade biomass because they can afford to use simple and inefficient power cycles. This raises the possibility of achieving negative CO₂ emissions via CO₂ capture and utilization or storage (CCUS). When heat is the primary valuable product produced by the plant, conventional CO₂ capture processes consuming a large quantity of heat become less attractive unless a productive use can be found for the large amount of very-low-grade heat (typically below 50 °C) rejected from the CO₂ capture facility. Thus, processes capturing CO₂ using electrical power only may be better candidates for enabling CCUS from CHP plants.

The present study investigated the prospects of the novel continuous swing adsorption reactor (CSAR) that captures CO₂ using combined vacuum and temperature swing adsorption (VTSA) driven by heat and vacuum pumps. CSAR consumes only electrical power and could also be configured to run on heat from the plant when excess heat is available for free, especially during summer months. The CSAR concept running on electricity throughout the year, a flexible CSAR configuration that switches to running on free heat during the summer, and a conventional monoethanolamine (MEA) benchmark were compared in a techno-economic analysis to map out the prospects of CSAR.

Without the availability of free heat during the summer, CSAR is clearly the superior solution, as MEA consumes most of the plant’s heat output for CO₂ capture. To compete with CSAR, MEA would need unrealistically low heat prices of 9–15 €/MWh when electricity costs 50–100 €/MWh, although an advanced PZ/AMP solvent benchmark increases this range to 16–27 €/MWh. If free summer heat is available, MEA becomes considerably more attractive, doubling breakeven heat prices in an example where free heat is available for half the year. However, the flexible CSAR configuration also improves the competitiveness of CSAR in this scenario, lowering MEA breakeven heat prices to 13–20 €/MWh (27–41 €/MWh against the PZ/AMP benchmark) with electricity prices of 50–100 €/MWh.

In most cases, CHP plants would sell heat for substantially higher prices than those needed for a competitive MEA process (mentioned above), although advanced solvents offer stronger competition, especially when a significant amount of free heat is available. When considering retrofits to existing plants, the costs of solvent-based solutions would be even higher because of the capital cost implications of supplying existing heat customers with an alternative heat supply when most of the CHP plant’s heat is consumed for CO₂ capture. For these reasons, the CSAR concept appears to be a highly promising technology for application to CHP plants, and investments in dedicated experimental demonstration of the concept can be recommended.

Supporting Information

Click to copy section linkSection link copied!

The Supporting Information is available free of charge at https://pubs.acs.org/doi/10.1021/acs.energyfuels.3c00885.

Full economic assessment of the CSAR cases and the MEA benchmark (ZIP)

ef3c00885_si_001.zip (2.15 MB)

Terms & Conditions

Most electronic Supporting Information files are available without a subscription to ACS Web Editions. Such files may be downloaded by article for research use (if there is a public use license linked to the relevant article, that license may permit other uses). Permission may be obtained from ACS for other uses through requests via the RightsLink permission system: http://pubs.acs.org/page/copyright/permissions.html.

Author Information

Click to copy section linkSection link copied!

Corresponding Author
- Abdelghafour Zaabout - Process Technology Department, SINTEF Industry, Trondheim 7034, Norway; ACER CoE Center, University Mohammed 6 Polytechnic, Ben Guerir 43150, Morocco; https://orcid.org/0000-0002-7468-8050; Email: [email protected]
Authors
- Schalk Cloete - Process Technology Department, SINTEF Industry, Trondheim 7034, Norway
- Chaitanya Dhoke - Process Technology Department, SINTEF Industry, Trondheim 7034, Norway; https://orcid.org/0000-0001-5580-1962
- Davide Bonalumi - Department of Energy, Politecnico di Milano, Milano 20156, Italy; https://orcid.org/0000-0002-4116-0532
- John Morud - Process Technology Department, SINTEF Industry, Trondheim 7034, Norway
- Antonio Giuffrida - Department of Energy, Politecnico di Milano, Milano 20156, Italy
- Matteo Carmelo Romano - Department of Energy, Politecnico di Milano, Milano 20156, Italy
Notes
The authors declare no competing financial interest.

Acknowledgments

Click to copy section linkSection link copied!

This study was partly funded under the Climit-Demo project “Verification and demonstration of an advanced adsorption reactor for cost-effective CO₂ capture” with grant number 621172. The internal financial support from SINTEF for preparing the draft is also acknowledged. The authors also acknowledge all valuable information provided by Henk Fikkert about Twence Waste-to-Energy plant in the Netherlands.

List of Acronyms

Click to copy section linkSection link copied!

BECCS	bioenergy CO₂ capture and storage
CCS	CO₂ capture and storage
CHP	combined heat and power
CSAR	continuous swing adsorption reactor
CSTR	continuous stirred tank reactor
MEA	monoethanolamine
O&M	operating and maintenance
SARC	swing adsorption reactor cluster
SEA	standardized economic assessment
TOC	total overnight cost
TSA	temperature swing adsorption
VPSA	vacuum pressure swing adsorption
WTE	waste-to-energy

Additional Notes

Click to copy section linkSection link copied!

^a https://bit.ly/3yYVSZ5

^b https://bit.ly/3yYVSZ5

References

Click to copy section linkSection link copied!

This article references 35 other publications.

1
UNFCCC. Historic Paris Agreement on Climate Change 2015. Available from: https://unfccc.int/process-and-meetings/the-paris-agreement/the-paris-agreement.
Google Scholar
There is no corresponding record for this reference.
2
IPCC. Fifth Assessment Report: Mitigation of Climate Change, Intergovernmental Panel on Climate Change, 2014.
Google Scholar
There is no corresponding record for this reference.
3
IEA. CUS in clean energy transitions, in Energy Technology Perspectives, Special report on carbon capture utilization and storage; International Energy Agency, 2020.
Google Scholar
There is no corresponding record for this reference.
4
IPCC. Global Warming of 1.5 °C, Intergovernmental Panel on Climate Change, 2018.
Google Scholar
There is no corresponding record for this reference.
5
Gapminder. Global income mountains 2022. Available from: https://www.gapminder.org/fw/income-mountains/.
Google Scholar
There is no corresponding record for this reference.
6
Fajardy, M.; Dowell, N. M. Can BECCS deliver sustainable and resource efficient negative emissions?. Energy Environ. Sci. 2017, 10, 1389– 1426, DOI: 10.1039/c7ee00465f
Google Scholar
6
Can BECCS deliver sustainable and resource efficient negative emissions?
Fajardy, Mathilde; Mac Dowell, Niall
Energy & Environmental Science (2017), 10 (6), 1389-1426CODEN: EESNBY; ISSN:1754-5706. (Royal Society of Chemistry)
A review. Neg. emissions technologies (NETs) in general and bioenergy with CO2 capture and storage (BECCS) in particular are commonly regarded as vital yet controversial to meeting our climate goals. In this contribution we present a whole-systems anal. of the BECCS value chain assocd. with cultivation, harvesting, transport and conversion in dedicated biomass power stations in conjunction with CCS, of a range of biomass resources - both dedicated energy crops (miscanthus, switchgrass, short rotation coppice willow), and agricultural residues (wheat straw). We explicitly consider the implications of sourcing the biomass from different regions, climates and land types. The water, carbon and energy footprints of each value chain were calcd., and their impact on the overall system water, carbon and power efficiencies was evaluated. An extensive literature review was performed and a statistical anal. of the available data is presented. In order to describe the dynamic greenhouse gas balance of such a system, a yearly accounting of the emissions was performed over the lifetime of a BECCS facility, and the carbon "break-even time" and lifetime net CO2 removal from the atm. were detd. The effects of direct and indirect land use change were included, and were found to be a key determinant of the viability of a BECCS project. Overall we conclude that, depending on the conditions of its deployment, BECCS could lead to both carbon pos. and neg. results. The total quantity of CO2 removed from the atm. over the project lifetime and the carbon break-even time were obsd. to be highly case specific. This has profound implications for the policy frameworks required to incentivize and regulate the widespread deployment of BECCS technol. The results of a sensitivity anal. on the model combined with the investigation of alternate supply chain scenarios elucidated key levers to improve the sustainability of BECCS: (1) measuring and limiting the impacts of direct and indirect land use change, (2) using carbon neutral power and org. fertilizer, (3) minimizing biomass transport, and prioritizing sea over road transport, (4) maximizing the use of carbon neg. fuels, and (5) exploiting alternative biomass processing options, e.g., natural drying or torrefaction. A key conclusion is that, regardless of the biomass and region studied, the sustainability of BECCS relies heavily on intelligent management of the supply chain.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC2sXls1ygt7c%253D&md5=d133376dc81665c9ff3b601213cfb1be
7
Dong, J.; Tang, Y.; Nzihou, A. Comparison of waste-to-energy technologies of gasification and incineration using life cycle assessment: Case studies in Finland, France and China. J. Cleaner Prod. 2018, 203, 287– 300, DOI: 10.1016/j.jclepro.2018.08.139
Google Scholar
7
Comparison of waste-to-energy technologies of gasification and incineration using life cycle assessment: Case studies in Finland, France and China
Dong, Jun; Tang, Yuanjun; Nzihou, Ange; Chi, Yong; Weiss-Hortala, Elsa; Ni, Mingjiang; Zhou, Zhaozhi
Journal of Cleaner Production (2018), 203 (), 287-300CODEN: JCROE8; ISSN:0959-6526. (Elsevier Ltd.)
Waste-to-Energy (WtE) has gradually constituted one of the most important options to achieve energy recovery from municipal solid waste (MSW). However, the environmental sustainability of a specific WtE system varies with used technologies and geog. differences. As a result, three representative WtE systems are compared using life cycle assessment (LCA): a gasification-based WtE plant in Finland, mech.-grate incineration in France, and circulating fluidized bed incineration in China. Results show that the overall environmental performance of the gasification system is better than incineration. The use of gasification technol., attributed to an intermediate syngas purifn. step, can provide benefits of both reducing the stack emissions and increasing the energy efficiency. Regional waste management, esp. related to MSW caloric value and emission regulation, are detg. factors for a preferable performance of the incineration in France over that in China. Sensitivity and uncertainty analyses further address key variations such as choice of MSW compn., basis of displaced electricity, energy recovery mode, and application of "best-available technol." dedicated to incineration. It is found that the most sensitive parameters influencing the LCA results are: electricity recovery, CO2 emission, and NOx emission. In the future, use of the source-sepd. high caloric waste combined with a more stringent emission std. can efficiently improve MSW incineration in China. Bottom ash recycling for metals and materials is highly applicable regarding incineration in France. This presented study can overall contribute to the development of specific WtE technol. and local waste management plan for decision-makers.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC1cXhs1eisb%252FE&md5=f26549ba0d23017e2d7a70a7f9265831
8
Roussanaly, S.; Ouassou, J. A.; Anantharaman, R. Impact of Uncertainties on the Design and Cost of CCS From a Waste-to-Energy Plant. Front. Energy Res. 2020, 8, 17 DOI: 10.3389/fenrg.2020.00017
Google Scholar
There is no corresponding record for this reference.
9
Chandel, M. K.; Kwok, G.; Jackson, R. B. The potential of waste-to-energy in reducing GHG emissions. Carbon Manage. 2012, 3, 133– 144, DOI: 10.4155/cmt.12.11
Google Scholar
9
The potential of waste-to-energy in reducing GHG emissions
Chandel, Munish K.; Kwok, Gabriel; Jackson, Robert B.; Pratson, Lincoln F.
Carbon Management (2012), 3 (2), 133-144CODEN: CMAAC8; ISSN:1758-3004. (Future Science Ltd.)
The combustion of municipal solid waste (MSW) to generate heat or electricity (waste-to-energy [WTE]) could reduce net GHG emissions in the USA compared with combusting methane from landfills. Moreover, neg. CO2 emissions could be achieved with CCS because 66% of the carbon in MSW is typically biogenic. For the five largest landfill sites in each state, we est. that at least 58 and 11 sites have enough MSW to fuel WTE plants of >50 MWe and >100 MWe, resp. Furthermore, half of these sites lie within 20 km of potential underground saline and other CO2 storage reservoirs. We est. that the levelized electricity cost for WTE without CO2 capture is US94/MWh and is $285/MWh with amine-based post-combustion capture technol. The cost of CO2 capture is $58/Mg CO2, resulting in a cost for carbon neg. emissions of $93/Mg CO2; substantially lower than for some geoengineering methods, including capturing CO2 from air.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC38XkvVOiu70%253D&md5=ed5a0a68ea245e2a02b26d51300b2015
10
Mondino, G.; Grande, C. A.; Blom, R. Evaluation of MBTSA technology for CO2 capture from waste-to-energy plants. Int. J. Greenhouse Gas Control 2022, 118, 103685 DOI: 10.1016/j.ijggc.2022.103685
Google Scholar
10
Evaluation of MBTSA technology for CO2 capture from waste-to-energy plants
Mondino, Giorgia; Grande, Carlos A.; Blom, Richard; Nord, Lars O.
International Journal of Greenhouse Gas Control (2022), 118 (), 103685CODEN: IJGGBW; ISSN:1750-5836. (Elsevier B.V.)
Moving bed temp. swing adsorption (MBTSA) is a promising technol. for CO2 capture from flue gases. In a MBTSA unit, a selective adsorbent material is circulated between a low-temp. stage where it removes CO2 from the flue gas and a higher-temp. zone where it desorbs CO2 at higher purity. The main benefits of MBTSA are low pressure drops in the adsorption zone and the possibility to heat the adsorbent faster than std. adsorption technologies. This work evaluated via process simulations the use of the MBTSA technol. for CO2 capture from an industrial-scale waste-to-energy plant. To assess the technol. with realistic parameters, we measured heat transfer coeffs. in the heating section of a new MBTSA demonstrator unit using activated carbon spheres. The heating device was produced by 3D printing, and has rectangular channels on the gas-solid side rotated at 45° to facilitate solid flow. The heat transfer coeffs. increased with the flow rate of activated carbon particles, and the highest value of 120 W/m2K was measured for a sorbent mass flux of 3.5 kg/m2s. This information was used as input for the process simulations, and allowed a tailored and realistic design of an MBTSA unit capturing more than 90% of the exhaust CO2 with a purity above 95%. The rather high sp. heat duty of the process (5.7 MJ/kg CO2) can be attributed to the low adsorption capacity of the activated carbon. In this respect, significant improvements can be expected by employing adsorbents with higher adsorption capacity and selectivity, such as zeolites or metal-org. frameworks.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB38Xhslanur3I&md5=e34674261425f0f82f2f42d3095cc667
11
Haaf, M.; Anantharaman, R.; Roussanaly, S. CO2 capture from waste-to-energy plants: Techno-economic assessment of novel integration concepts of calcium looping technology. Resour., Conserv. Recycl. 2020, 162, 104973 DOI: 10.1016/j.resconrec.2020.104973
Google Scholar
There is no corresponding record for this reference.
12
Durán, I.; Rubiera, F.; Pevida, C. Vacuum swing CO2 adsorption cycles in Waste-to-Energy plants. Chem. Eng. J. 2020, 382, 122841 DOI: 10.1016/j.cej.2019.122841
Google Scholar
12
Vacuum swing CO2 adsorption cycles in Waste-to-Energy plants
Duran, Ines; Rubiera, Fernando; Pevida, Covadonga
Chemical Engineering Journal (Amsterdam, Netherlands) (2020), 382 (), 122841CODEN: CMEJAJ; ISSN:1385-8947. (Elsevier B.V.)
For the first time, the performance of vacuum swing adsorption-based processes for CO2 capture at waste-to-energy facilities was examd. CO2 capture and storage is gaining increasing attention in this sector. An anal. of simple cycle configurations for this application provided a ref. scenario to examine the potentiality of adsorption technol. This work maximized CO2 sepn. from solid waste incineration facility flue gas. Three vacuum swing adsorption and one vacuum/temp. swing adsorption configurations were assessed in a fixed-bed lab. app.; the effect of cycle design, no. of columns, and operational conditions were analyzed. The adsorbent was pine sawdust-based activated C, a forestry byproduct with great availability. A math. model developed in Aspen Adsorption complemented the exptl. study which validated the model. Addnl. simulations were performed to further evaluate the effect of different vacuum swing adsorption configurations had on product purity and recovery. With relatively simple configurations, consisting of a 4-bed max., CO2 recovery >95% was achieved and CO2 purity increased from 8 to ∼35-40%.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC1MXhvFCkt7vP&md5=8dd312ea63c913b6a00df55446665545
13
Tsupari, E.; Arponen, T.; Hankalin, V. Feasibility comparison of bioenergy and CO2 capture and storage in a large combined heat, power and cooling system. Energy 2017, 139, 1040– 1051, DOI: 10.1016/j.energy.2017.08.022
Google Scholar
13
Feasibility comparison of bioenergy and CO2 capture and storage in a large combined heat, power and cooling system
Tsupari, Eemeli; Arponen, Timo; Hankalin, Ville; Karki, Janne; Kouri, Sampo
Energy (Oxford, United Kingdom) (2017), 139 (), 1040-1051CODEN: ENEYDS; ISSN:0360-5442. (Elsevier Ltd.)
Heating and cooling is responsible for almost 50% of the final energy demand in Europe. One of the most developed combined heat, power and cooling (CHPC) systems in the world exists in Helsinki, Finland, operated by Helen Ltd. As one option for significant redns. in direct CO2 emissions from Helen's fleet, this paper presents case studies for different options regarding a multifuel CHP plant planned for Helsinki. The studied cases include coal firing, co-firing high proportion of forest residues with coal, applying post-combustion CCS for coal firing, and combination of CCS and biomass co-firing. The cases are compared in different market situations in terms of the operation and profitability of the plant portfolio. The results highlight the sensitivities of economic feasibility on different market prices. With the default values assumed, the co-firing case is about as profitable as coal firing solely at present price of CO2 allowances. If CO2 price increases, co-firing becomes the most feasible option until the combination of co-firing and CCS becomes the most feasible option if the price of CO2 allowance is high. However, this would require recognising bio-CCS, and the "neg." CO2 emissions it generates, in the regulations of EU Emissions Trading System.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC2sXhtlyisrrM&md5=ae8bbf60e544470842ac88faa6c0b64f
14
Gładysz, P.; Sowiżdżał, A.; Miecznik, M. Techno-Economic Assessment of a Combined Heat and Power Plant Integrated with Carbon Dioxide Removal Technology: A Case Study for Central Poland. Energies 2020, 13, 2841 DOI: 10.3390/en13112841
Google Scholar
14
Techno-economic assessment of a combined heat and power plant integrated with carbon dioxide removal technology: a case study for central Poland
Gladysz, Pawel; Sowizdzal, Anna; Miecznik, Maciej; Hacaga, Maciej; Pajak, Leszek
Energies (Basel, Switzerland) (2020), 13 (11), 2841CODEN: ENERGA; ISSN:1996-1073. (MDPI AG)
The objective of this study is to assess the techno-economic potential of the proposed novel energy system, which allows for neg. emissions of carbon dioxide (CO2). The analyzed system comprises four main subsystems: a biomass-fired combined heat and power plant integrated with a CO2 capture and compression unit, a CO2 transport pipeline, a CO2-enhanced geothermal system, and a supercrit. CO2 Brayton power cycle. For the purpose of the comprehensive techno-economic assessment, the results for the ref. biomass-fired combined heat and power plant without CO2 capture are also presented. Based on the proposed framework for energy and economic assessment, the energy efficiencies, the specific primary energy consumption of CO2 avoidance, the cost of CO2 avoidance, and neg. CO2 emissions are evaluated based on the results of process simulations. In addn., an overview of the relevant elements of the whole system is provided, taking into account technol. progress and technol. readiness levels. The specific primary energy consumption per unit of CO2 avoided in the analyzed system is equal to 2.17 MJLHV/kg CO2 for biomass only (and 6.22 MJLHV/kg CO2 when geothermal energy is included) and 3.41 MJLHV/kg CO2 excluding the CO2 utilization in the enhanced geothermal system. Regarding the economic performance of the analyzed system, the levelized cost of electricity and heat are almost two times higher than those of the ref. system (239.0 to 127.5 EUR/MWh and 9.4 to 5.0 EUR/GJ), which leads to neg. values of the Net Present Value in all analyzed scenarios. The CO2 avoided cost and CO2 neg. cost in the business as usual economic scenario are equal to 63.0 and 48.2 EUR/t CO2, resp., and drop to 27.3 and 20 EUR/t CO2 in the technol. development scenario. The anal. proves the economic feasibility of the proposed CO2 utilization and storage option in the enhanced geothermal system integrated with the sCO2 cycle when the cost of CO2 transport and storage is above 10 EUR/t CO2 (at a transport distance of 50 km). The technol. readiness level of the proposed technol. was assessed as TRL4 (technol. development), mainly due to the early stage of the CO2-enhanced geothermal systems development.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3cXhvFynsbvJ&md5=70b276072b1e38e702c888539531b693
15
Khorshidi, Z.; Ho, M. T.; Wiley, D. E. Techno-economic evaluation of using biomass-fired auxiliary units for supplying energy requirements of CO2 capture in coal-fired power plants. Int. J. Greenhouse Gas Control 2015, 32, 24– 36, DOI: 10.1016/j.ijggc.2014.10.017
Google Scholar
15
Techno-economic evaluation of using biomass-fired auxiliary units for supplying energy requirements of CO2 capture in coal-fired power plants
Khorshidi, Zakieh; Ho, Minh T.; Wiley, Dianne E.
International Journal of Greenhouse Gas Control (2015), 32 (), 24-36CODEN: IJGGBW; ISSN:1750-5836. (Elsevier B. V.)
Parasitically providing the energy required for CO2 capture from retrofitted coal power plants can lead to a significant loss in output of electricity. In this study, different configurations of auxiliary units are investigated to partially or totally meet the energy requirements for MEA post-combustion capture in a 500 MW sub-crit. coal-fired plant. The auxiliary unit is either a boiler, providing only the heat required for solvent regeneration in the capture process or a combined heat and power (CHP) unit, providing both heat and electricity. Using biomass in auxiliary units, the grid loss is reduced without increasing fossil fuel consumption. The results show that using a biomass CHP unit is more favorable than using a biomass boiler both in terms of CO2 emission redns. and power plant economic viability. By using an auxiliary biomass CHP unit, both the emission intensity and the cost of electricity would be marginally lower than for a coal plant with capture. Further emission redns. occur if CO2 is captured both from the coal plant and the auxiliary biomass CHP, resulting in neg. emissions. However, high incentive schemes (a carbon price higher than 55 $/t CO2 or a combination of lower carbon price and renewable energy certificates) or a low biomass price (lower than 1 $/GJ) are required to make CO2 capture from both the coal plant and the auxiliary biomass CHP unit economically attractive. All cost comparisons are for CO2 capture only and CO2 transport and storage are not included in this study.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC2cXhvVygsbbK&md5=2dba2f56d941f1ba62df6722ad554459
16
Kuramochi, T.; Faaij, A.; Ramírez, A. Prospects for cost-effective post-combustion CO2 capture from industrial CHPs. Int. J. Greenhouse Gas Control 2010, 4, 511– 524, DOI: 10.1016/j.ijggc.2009.12.008
Google Scholar
16
Prospects for cost-effective post-combustion CO2 capture from industrial CHPs
Kuramochi, Takeshi; Faaij, Andre; Ramirez, Andrea; Turkenburg, Wim
International Journal of Greenhouse Gas Control (2010), 4 (3), 511-524CODEN: IJGGBW; ISSN:1750-5836. (Elsevier Ltd.)
Industrial Combined Heat and Power plants (CHPs) are often operated at partial load conditions. If CO2 is captured from a CHP, addnl. energy requirements can be fully or partly met by increasing the load. Load increase improves plant efficiency and, consequently, part of the addnl. energy consumption would be offset. If this advantage is large enough, industrial CHPs may become an attractive option for CO2 capture and storage CCS. We therefore investigated the techno-economic performance of post-combustion CO2 capture from small-to-medium-scale (50-200 MWe max. elec. capacity) industrial Natural Gas Combined Cycle- (NGCC-) CHPs in comparison with large-scale (400 MWe) NGCCs in the short term (2010) and the mid-term future (2020-2025). The analyzed system encompasses NGCC, CO2 capture, compression, and branch CO2 pipeline. The tech. results showed that CO2 capture energy requirement for industrial NGCC-CHPs is significantly lower than that for 400 MWe NGCCs: up to 16% in the short term and up to 12% in the midterm future. The economic results showed that at low heat-to-power ratio operations, CO2 capture from industrial NGCC-CHPs at 100 MWe in the short term (41-44 euro/tCO2 avoided) and 200 MWe in the midterm future (33-36 euro/tCO2 avoided) may compete with 400 MWe NGCCs (46-50 euro/tCO2 avoided short term, 30-35 euro/tCO2 avoided mid-term).
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC3cXnsF2gu7k%253D&md5=fec70bc0c757250ae11a89bc8b8d8fcf
17
Magnanelli, E.; Mosby, J.; Becidan, M. Scenarios for carbon capture integration in a waste-to-energy plant. Energy 2021, 227, 120407 DOI: 10.1016/j.energy.2021.120407
Google Scholar
17
Scenarios for carbon capture integration in a waste-to-energy plant
Magnanelli, Elisa; Mosby, Jostein; Becidan, Michael
Energy (Oxford, United Kingdom) (2021), 227 (), 120407CODEN: ENEYDS; ISSN:0360-5442. (Elsevier Ltd.)
In this work, the performance of an amine-based post-combustion carbon capture system using MEA (monoethanolamine) integrated to a Waste-to-Energy (WtE) plant is studied. WtE plants are affected by fluctuations at different time-scales, due to changes in waste properties as well as variations in district heat demand. A dynamic model of the combined plant is used to study the effect of flue gas fluctuations on capture plant operation, and the effect of integrating the capture plant into the WtE plant. When the two plants are considered sep., the heat requirement of the capture plant corresponds to 27% of the nominal thermal capacity of the WtE plant. When integrating the two plants, steam extn. from the boiler drum to provide the heat necessary to the capture plant reduces the power and district heat prodn. of the WtE plant by 30% and 6% resp., while extn. from the turbine causes a redn. of 8% and 12%. By modifying the condensers' temp., it is possible to maintain 96% of the original district heat prodn. By performing carbon capture only when excess heat is available, it is possible to capture 47% of the CO2 emitted by the WtE plant, while reducing the power prodn. by only 5%.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3MXoslKhs7Y%253D&md5=017f149b89c8ac482df1bbd83bfb5d0a
18
Luberti, M.; Oreggioni, G. D.; Ahn, H. Design of a rapid vacuum pressure swing adsorption (RVPSA) process for post-combustion CO2 capture from a biomass-fuelled CHP plant. J. Environ. Chem. Eng. 2017, 5, 3973– 3982, DOI: 10.1016/j.jece.2017.07.029
Google Scholar
18
Design of a rapid vacuum pressure swing adsorption (RVPSA) process for post-combustion CO2 capture from a biomass-fuelled CHP plant
Luberti, Mauro; Oreggioni, Gabriel David; Ahn, Hyungwoong
Journal of Environmental Chemical Engineering (2017), 5 (4), 3973-3982CODEN: JECEBG; ISSN:2213-3437. (Elsevier Ltd.)
It was aimed to design a novel RVPSA (Rapid Vacuum Pressure Swing Adsorption) unit for CO2 concn. and recovery in order to achieve the aggressive CO2 capture target, i.e. 95+% CO2 purity and 90+% CO2 recovery at the same time, applied to an existing 10 MWth biomass-fuelled CHP plant. Biomass-fuelled CHP plants are deemed carbon-neutral on the grounds of the net CO2 addn. to the atm. as a result of its operation being practically zero, ignoring the CO2 emissions involved in the ancillary processes, such as soil enhancement, biomass transport and processing, etc. Furthermore, integrating the biomass-fuelled CHP plant with carbon capture, transport and storage enables carbon-neg. energy generation, as its net effect is to recover some CO2 in the air and then store it underground through this plant operation. By the way, a RVPSA process features more efficient utilization of the adsorbents in the column, leading to much higher bed productivity than a conventional adsorption process. Such a high bed productivity makes it easier to scale up this adsorption process for its application to industrial post-combustion capture. A two-stage, two-bed RVPSA unit was designed and simulated to capture CO2 from the biomass-fuelled CHP plant flue gas contg. 13.3% CO2 mole fraction. Effects of operating conditions such as the Purge-to-Feed ratio (P/F) and desorption pressure on the specific power consumption were investigated in detail. It was found that the integrated two-stage RVPSA unit was capable of achieving the following overall performances: CO2 recovery of 90.9%, CO2 purity of 95.0%, bed productivity of 21.2 molCO2/kg/h and power consumption of 822.9 kJ/kgCO2. The productivity of the RVPSA unit designed in this study was 20-30 times higher than those of the conventional CO2 capture VPSA processes.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC2sXhtlShu7%252FJ&md5=2696330c89269ac6138af38a1b717548
19
Webley, P. A. Adsorption technology for CO2 separation and capture: a perspective. Adsorption 2014, 20, 225– 231, DOI: 10.1007/s10450-014-9603-2
Google Scholar
19
Adsorption technology for CO2 separation and capture: a perspective
Webley, Paul A.
Adsorption (2014), 20 (2-3), 225-231CODEN: ADSOFO; ISSN:0929-5607. (Springer)
A review. The capture of CO2 from process and flue gas streams and subsequent sequestration was first proposed as a greenhouse gas mitigation option in the 1990s. This proposal spawned a series of lab. and field tests in CO2 capture which has now grown into a major world-wide research effort encompassing a myriad of capture technologies and ingenious flow sheets integrating power prodn. and carbon capture. Simultaneously, the explosive growth in materials science in the last two decades has produced a wealth of new materials and knowledge providing us with new avenues to explore to fine tune CO2 adsorption and selectivity. Lab. and field studies over the last decade have explored the synergy of process and materials to produce numerous CO2 capture technologies and materials based on cyclic adsorption processes. In this brief perspective, we look at some of these developments and comment on the application and limitations of adsorption process to CO2 capture. We identify major engineering obstacles to overcome as well as potential breakthroughs necessary to achieve commercialization of adsorption processes for CO2 capture. Our perspective is primarily restricted to post-combustion flue gas capture and CO2 capture from natural gas.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC2cXhs1Siu7o%253D&md5=5204244844661294757bca77df701b60
20
Dhoke, C.; Zaabout, A.; Cloete, S. Demonstration of the Novel Swing Adsorption Reactor Cluster Concept in a Multistage Fluidized Bed with Heat-Transfer Surfaces for Postcombustion CO2 Capture. Ind. Eng. Chem. Res. 2020, 59, 22281– 22291, DOI: 10.1021/acs.iecr.0c05951
Google Scholar
20
Demonstration of the Novel Swing Adsorption Reactor Cluster Concept in a Multistage Fluidized Bed with Heat-Transfer Surfaces for Postcombustion CO2 Capture
Dhoke, Chaitanya; Zaabout, Abdelghafour; Cloete, Schalk; Seo, Hwimin; Park, Yong-ki; Demoulin, Leyne; Amini, Shahriar
Industrial & Engineering Chemistry Research (2020), 59 (51), 22281-22291CODEN: IECRED; ISSN:0888-5885. (American Chemical Society)
This paper reports the exptl. demonstration of the novel swing adsorption reactor cluster (SARC) concept in a multistage fluidized bed reactor with inbuilt heat-transfer surfaces for postcombustion CO2 capture at a capacity up to 24 kg-CO2/day. SARC employs combined temp. and vacuum swings (VTSA), driven by heat and vacuum pumps, to regenerate the solid sorbent after CO2 capture. The lab.-scale reactor utilized a vacuum pump and a heating oil loop (emulating the heat pump) to demonstrate 90% CO2 capture from an N2/CO2 mixt. approximating a coal power plant flue gas fed at 200 NL/min. In addn., dedicated expts. demonstrated three important features required for the success of the SARC concept: (1) the polyethyleneimine sorbent employed imposes no kinetic limitations in CO2 adsorption (referred to as carbonation) and only minor nonidealities in regeneration, (2) a high heat-transfer coeff. in the range of 307-489 W/M2 K is achieved on the heat transfer surfaces inside the reactor, and (3) perforated plate separators inserted along the height of the reactor can achieve the plug-flow characteristics required for high CO2 capture efficiency. Finally, sensitivity anal. revealed the expected improvements in CO2 capture efficiency with increased pressure and temp. swings and shorter carbonation times, demonstrating predictable behavior of the SARC reactor. This study provides a sound basis for further scale-up of the SARC concept.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3cXisFyrtLjE&md5=be7e9feed53f2c4a396cd2d5f4c4a810
21
Zaabout, A.; Romano, M. C.; Cloete, S. Thermodynamic assessment of the swing adsorption reactor cluster (SARC) concept for post-combustion CO2 capture. Int. J. Greenhouse Gas Control 2017, 60, 74– 92, DOI: 10.1016/j.ijggc.2017.03.001
Google Scholar
21
Thermodynamic assessment of the swing adsorption reactor cluster (SARC) concept for post-combustion CO2 capture
Zaabout, Abdelghafour; Romano, Matteo C.; Cloete, Schalk; Giuffrida, Antonio; Morud, John; Chiesa, Paolo; Amini, Shahriar
International Journal of Greenhouse Gas Control (2017), 60 (), 74-92CODEN: IJGGBW; ISSN:1750-5836. (Elsevier B.V.)
This paper presents the novel swing adsorption reactor cluster (SARC) for post combustion CO2 capture. The SARC concept consists of a cluster of bubbling/turbulent multistage fluidized bed reactors which dynamically cycle a solid sorbent between carbonation and regeneration. A synergistic combination of vacuum swing through a vacuum pump and temp. swing through a heat pump is employed to ensure high process efficiency. The base case SARC configuration imposed an energy penalty of 9.64%-points on a conventional coal-fired power plant, which is in line with advanced amine-based absorption processes. Sensitivity analyses showed that significant potential for further improvements (∼1.5%-points) exist through mechanisms such as an increase in the no. of reactor stages, further redns. in regeneration pressure and optimization of the cycle length. Addnl. efficiency improvements can also be traded for increased reactor footprint. However, future sorbent material selection studies esp. for this novel process hold the largest potential for further efficiency improvements. The SARC concept is well suited to retrofitting purposes due to limited integration with the steam cycle, and the simple standalone reactor design will simplify future scale-up efforts. The concept is therefore recommended for further study.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC2sXlslantbw%253D&md5=7c3148fcb96d81401a34f7f1f2315eac
22
Dhoke, C.; Cloete, S.; Amini, S. Study of the Cost Reductions Achievable from the Novel SARC CO2 Capture Concept Using a Validated Reactor Model. Ind. Eng. Chem. Res. 2021, 60, 12390– 12402, DOI: 10.1021/acs.iecr.1c00357
Google Scholar
22
Study of the Cost Reductions Achievable from the Novel SARC CO2 Capture Concept Using a Validated Reactor Model
Dhoke, Chaitanya; Cloete, Schalk; Amini, Shahriar; Zaabout, Abdelghafour
Industrial & Engineering Chemistry Research (2021), 60 (33), 12390-12402CODEN: IECRED; ISSN:0888-5885. (American Chemical Society)
New process concepts, such as the swing adsorption reactor cluster (SARC) CO2 capture process, are often techno-economically investigated using idealized modeling assumptions. This study quantifies the impact of this practice by updating a previous economic assessment with results from an improved reactor model validated against recently completed SARC lab-scale demonstration expts. The exptl. comparison showed that the assumption of chem. equil. was valid, that the previously employed heat transfer coeff. was conservatively low, and that the required redn. of axial mixing could be easily achieved using simple perforated plates in the reactor. However, the assumption of insignificant effects of the hydrostatic pressure gradient needed to be revised. In the economic assessment, the neg. effect of the hydrostatic pressure gradient was almost canceled out by deploying the exptl. obsd. heat transfer coeffs., resulting in a small net increase in CO2 avoidance costs of 2.8-4.8% relative to the unvalidated model. Further redns. in axial mixing via more perforated plates only brought minor benefits, but a shorter reactor enabled by the fast exptl. obsd. adsorption kinetics had a larger pos. effect: halving the reactor height reduced CO2 avoidance costs by 13.3%. A new heat integration scheme feeding vacuum pressure steam raised from several low-grade heat sources to the SARC desorption step resulted in similar gains. When all improvements were combined, the optimal CO2 avoidance cost was 23.7% below the best result from prior works. The main uncertainty that needs to be overcome to realize the great economic potential of the SARC concept is long-term sorbent stability: mech. stability must be improved substantially and long-term chem. stability under real flue gas conditions must be demonstrated.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3MXhslersL%252FJ&md5=4e507d9451b94ceb7a074caa43a3e93b
23
Zerobin, F.; Pröll, T. Concentrated Carbon Dioxide (CO2) from Diluted Sources through Continuous Temperature Swing Adsorption (TSA). Ind. Eng. Chem. Res. 2020, 59, 9207– 9214, DOI: 10.1021/acs.iecr.9b06177
Google Scholar
23
Concentrated Carbon Dioxide (CO2) from Diluted Sources through Continuous Temperature Swing Adsorption (TSA)
Zerobin, Florian; Proell, Tobias
Industrial & Engineering Chemistry Research (2020), 59 (19), 9207-9214CODEN: IECRED; ISSN:0888-5885. (American Chemical Society)
CO2 capture and storage and most CO2 capture and utilization routes require concd. CO2 streams for efficient compression, pipeline transport, injection, or chem. syntheses. The achieved quality of the CO2-rich product stream greatly affects the CO2 capture energy effort, resulting in widely scattered figures for CO2 capture in the literature. This wok specifically addressed the provision of concd. CO2 (>99 vol. percent) from dil. sources. A continuously operated temp.-swing adsorption process (TSA) was selected to illustrate tech. challenges. A detailed steady-state process model was used for a thermodn. evaluation (previously developed for the com. available solid sorbent, Lewatit VP OC 1065). Three typical inlet CO2 concns. corresponding to atm. air (0.04 vol. percentdb), gas turbine combined cycle exhaust gas (4 vol. percentdb), and solid fuel combustion exhaust gas (10 vol. percentdb) were assessed. Each case was optimized in terms of stage configuration, sorbent circulation rate, and stripping steam rate. For direct air capture with a 50% rate, two stages were used in the adsorber and 10 stages were used in the desorber; for the capture from exhaust gas mixts., a 90% capture rate and a 4 x 4 stage configuration were used. Specific total energy demand for capture and concn. was 10 times higher for direct ambient air capture (25.76 MJ/kgCO2 heat @ 120° + 8.26 MJ/kgCO2 power) vs. combustion exhaust gas capture with 4 vol. percentdb (3.64 MJ/kgCO2 heat @ 120° + 0.09 MJ/kgCO2 power) and 10 vol. ercentdb (3.21 MJ/kgCO2 heat @ 120° + 0.04 MJ/kgCO2 power). A simple exergy anal. showed ∼3 times higher irreversibility for direct air capture vs. capture from the two more concd. source streams.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3cXmvFGgsL4%253D&md5=c91a17908cfd1f9dee2c8480e6a7329a
24
Dhoke, C.; Cloete, S.; Krishnamurthy, S. Sorbents screening for post-combustion CO2 capture via combined temperature and pressure swing adsorption. Chem. Eng. J. 2020, 380, 122201 DOI: 10.1016/j.cej.2019.122201
Google Scholar
24
Sorbents screening for post-combustion CO2 capture via combined temperature and pressure swing adsorption
Dhoke, Chaitanya; Cloete, Schalk; Krishnamurthy, Shreenath; Seo, Hwimin; Luz, Ignacio; Soukri, Mustapha; Park, Yong-ki; Blom, Richard; Amini, Shahriar; Zaabout, Abdelghafour
Chemical Engineering Journal (Amsterdam, Netherlands) (2020), 380 (), 122201CODEN: CMEJAJ; ISSN:1385-8947. (Elsevier B.V.)
Adsorption-based post-combustion CO2 capture is enjoying significant research attention due to its potential for significant redns. in energy penalty, cost and environmental impact. Recent sorbent development work has focussed on polyethyleneimine (PEI) and dry sorbents that exhibit attractively low regeneration energy requirements. The main objective of this study is to identify best suitable sorbent for the recently published swing adsorption reactor cluster (SARC) concept. The screening results of four sorbents indicated two PEI sorbents to be good candidates for SARC application: a PEI sorbent functionalized with 1,2-epoxybutane supported on silica (referred to as EB-PEI in the rest of the document) and a PEI sorbent supported on mesoporous silica contg. confined metal org. framework nanocrystals (referred to as PEI-MOF in the rest of the document). High resoln. single-component isotherms revealed substantial differences in adsorption capacity and optimal operating temps. for the two PEI sorbents, and CO2 and H2O isotherm models were derived from this data. Subsequently, breakthrough expts. and lab-scale reactor tests showed that co-feeding of CO2 and H2O had no significant effect, allowing the single-component isotherm models to be safely used in large-scale reactor simulations. Such a reactor model was then employed to illustrate the effect of the sorbent adsorption characteristics on the efficiency of the novel swing adsorption reactor cluster, which combines pressure and temp. swings. The EB-PEI and PEI-MOF sorbents were compared to a previously published PEI sorbent with distinctly different adsorption behavior and recommendations for future sorbent development work were made.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC1MXhs1Gksb%252FK&md5=4516fc8993e10177d8a7fc179f0637a8
25
Cloete, S.; Giuffrida, A.; Romano, M. C. Economic assessment of the swing adsorption reactor cluster for CO2 capture from cement production. J. Cleaner Prod. 2020, 275, 123024 DOI: 10.1016/j.jclepro.2020.123024
Google Scholar
25
Economic assessment of the swing adsorption reactor cluster for CO2 capture from cement production
Cloete, Schalk; Giuffrida, Antonio; Romano, Matteo C.; Zaabout, Abdelghafour
Journal of Cleaner Production (2020), 275 (), 123024CODEN: JCROE8; ISSN:0959-6526. (Elsevier Ltd.)
Cement prodn. is responsible for about 8% of global CO2 emissions. Most of these emissions originate from the process itself and thus cannot be avoided via clean energy, leaving CO2 capture as the only viable soln. This study investigates the prospects of decarbonizing the cement industry via the swing adsorption reactor cluster (SARC) - a new post-combustion CO2 capture technol. that requires no integration with the host process, consumes only elec. energy and shows a competitive energy penalty. SARC operates by synergistically combining a temp. swing using a heat pump and a vacuum swing using a vacuum pump. In the present study, the SARC concept is evaluated economically and compared to several benchmarks. SARC achieves CO2 avoidance costs of euro52/ton in the base case, which is higher than oxyfuel combustion, similar to calcium looping and lower than four other technol. options. SARC can approach the cost of oxyfuel combustion with more optimistic assumptions regarding economies of scale, particularly for the vacuum pump. The local electricity mix is another important factor because SARC, as an electricity consumer, becomes more attractive when the price and CO2 intensity of electricity is low. Furthermore, the simplicity of retrofitting existing cement plants with the SARC process becomes increasingly valuable when rapid CO2 emissions redns. are targeted. SARC is therefore well positioned for a global decarbonization effort aiming to limit global warming well below 2°C.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3cXhsVymsr7E&md5=296afa8b615b97789aeae98c5ed22623
26
Dhoke, C.; Zaabout, A.; Cloete, S. The swing adsorption reactor cluster (SARC) for post combustion CO2 capture: Experimental proof-of-principle. Chem. Eng. J. 2018, 377, 120145 DOI: 10.1016/j.cej.2018.10.082
Google Scholar
There is no corresponding record for this reference.
27
Kim, K.; Seo, H.; Kim, D. J. Experimental evaluation of CO2 capture with an amine impregnated sorbent in dual circulating fluidized bed process. Int. J. Greenhouse Gas Control 2020, 101, 103141 DOI: 10.1016/j.ijggc.2020.103141
Google Scholar
27
Experimental evaluation of CO2 capture with an amine impregnated sorbent in dual circulating fluidized bed process
Kim, Kiwoong; Seo, Hwimin; Kim, Dae Jin; Lee, Chungwoo; Min, Da Young; Kim, Hye Mi; Park, Yong-Ki
International Journal of Greenhouse Gas Control (2020), 101 (), 103141CODEN: IJGGBW; ISSN:1750-5836. (Elsevier B.V.)
Carbon Capture and Sequestration (CCS) technol. to slow global warming is a challenge to be solved worldwide. In this study, a dual circulating fluidized bed process using a solid-sorbent was developed for the post-combustion CO2 capture process from a pulverized coal power plant. This solid-sorbent-based CO2 capture process consists of absorber, regenerator, and standpipes in between them. An amine-functionalized silica was utilized as a solid-sorbent, and a bench-scale facility capable of treating flue gas of 20 Nm3/h was constructed for the performance verification. As a result, when the sorbent to CO2 ratio was 24.6 wt/wt%, a CO2 capture efficiency of 80% or more was obtained, and the max. CO2 working capacity was 4.5 wt%. A long-term stability was verified in the bench-scale facility and, as a result, the sorption capacity decreased by 5% for about 800 cycles. In addn., a solid-solid indirect heat exchanger was applied at the upper part of the absorber to partially recover solid sensible energy to reduce the regeneration energy. The sorbent loading inside the tube affects the heat transfer efficiency, and the heat transfer coeff. ranges from 8 to 10.5 W/m2-K.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3cXhslKqurbL&md5=489bf61c7f34e75eebe6b66eaddae0b9
28
Kukade, S.; Kumar, P.; Rao, P. V. Comparative study of attrition measurements of commercial FCC catalysts by ASTM fluidized bed and jet cup test methods. Powder Technol. 2016, 301, 472– 477, DOI: 10.1016/j.powtec.2016.06.040
Google Scholar
28
Comparative study of attrition measurements of commercial FCC catalysts by ASTM fluidized bed and jet cup test methods
Kukade, Somanath; Kumar, Pramod; Rao, Peddy V. C.; Choudary, Nettem V.
Powder Technology (2016), 301 (), 472-477CODEN: POTEBX; ISSN:0032-5910. (Elsevier B.V.)
Catalyst loss due to fines generation by attrition is a major problem in refinery fluid catalytic cracking (FCC) units as it impacts inventory loss. Attrition resistance of catalyst is one of the crit. parameter in catalyst selection for a FCC unit. ASTM D5757 fluidized bed attrition test is the most commonly used attrition resistance test method to rank FCC catalysts and additives. In the present study, catalyst attrition tests were performed for FCC catalysts using an ASTM fluidized bed, cylindrical jet cup and conical jet cup. Performance ranking shows that attrition index obtained by these tests vary, but the order of ranking remains unchanged for ASTM fluidized bed and conical jet cup test methods as compared to cylindrical jet cup test. The investigation conducted here shows that morphol. of attrited fresh FCC catalyst using conical jet cup was found to be similar to plant equil. catalyst and also takes less attrition time relative to ASTM fluidized bed.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC28XhtV2nsL3I&md5=12e02c0a4470c49ca1ea8ad72f1ebffe
29
Si, W.; Yang, B.; Yu, Q. Deactivation Kinetics of Polyethylenimine-based Adsorbents Used for the Capture of Low Concentration CO(2). ACS Omega 2019, 4, 11237– 11244, DOI: 10.1021/acsomega.9b00792
Google Scholar
29
Deactivation Kinetics of Polyethylenimine-based Adsorbents Used for the Capture of Low Concentration CO2
Si, Wenting; Yang, Bin; Yu, Qingni; Lei, Lecheng; Zhu, Jingke
ACS Omega (2019), 4 (6), 11237-11244CODEN: ACSODF; ISSN:2470-1343. (American Chemical Society)
CO2 emission is generally regarded as the major contributor to global climate change and polyethylenimine (PEI)-based CO2 adsorbents are promising material for the capture of low concn. CO2. The paper deals with the deactivation kinetics of PEI-based CO2 adsorbents used for the capture of low concn. CO2. EA and TG analyses demonstrated that thermal degrdn. and O2-induced deactivation of the adsorbents occurred simultaneously under air-exposure condition. It was found by N2-exposure expts. at the temp. of 50-80° that the thermal degrdn. of PEI-based adsorbents followed 1st-order reaction model with an activation energy of 80.98 kJ/mol and a pre-exponential factor of 6.055×108 (h-1). Parallel reaction model was employed to distinguish the O2-induced deactivation from the thermal degrdn. of the adsorbents through air-exposure expts. within 50-80°. The O2-induced deactivation exhibited a 2nd-order reaction with an activation energy of 74.47 kJ/mol and a pre-exponential factor of 6.321×106 (%-1•h-1). The results of simulating the overall deactivation of the adsorbent by the parallel-reaction kinetic model were well consistent with those of the expts., proving the parallel reaction model was feasible for the description of the deactivation of PEI-based adsorbents.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC1MXht1Kis7%252FO&md5=310f2a8bc0b4eb5b249b2266782eb4d9
30
Choi, W.; Min, K.; Kim, C. Epoxide-functionalization of polyethyleneimine for synthesis of stable carbon dioxide adsorbent in temperature swing adsorption. Nat. Commun. 2016, 7, 12640 DOI: 10.1038/ncomms12640
Google Scholar
30
Epoxide-functionalization of polyethyleneimine for synthesis of stable carbon dioxide adsorbent in temperature swing adsorption
Choi, Woosung; Min, Kyungmin; Kim, Chaehoon; Ko, Young Soo; Jeon, Jae Wan; Seo, Hwimin; Park, Yong-Ki; Choi, Minkee
Nature Communications (2016), 7 (), 12640CODEN: NCAOBW; ISSN:2041-1723. (Nature Publishing Group)
Amine-contg. adsorbents have been extensively investigated for post-combustion carbon dioxide capture due to their ability to chemisorb low-concn. carbon dioxide from a wet flue gas. However, earlier studies have focused primarily on the carbon dioxide uptake of adsorbents, and have not demonstrated effective adsorbent regeneration and long-term stability under such conditions. Here, we report the versatile and scalable synthesis of a functionalized-polyethyleneimine (PEI)/silica adsorbent which simultaneously exhibits a large working capacity (2.2 mmol g-1) and long-term stability in a practical temp. swing adsorption process (regeneration under 100% carbon dioxide at 120°C), enabling the sepn. of concd. carbon dioxide. We demonstrate that the functionalization of PEI with 1,2-epoxybutane reduces the heat of adsorption and facilitates carbon dioxide desorption (>99%) during regeneration compared with unmodified PEI (76%). Moreover, the functionalization significantly improves long-term adsorbent stability over repeated temp. swing adsorption cycles due to the suppression of urea formation and oxidative amine degrdn.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC28XhsVKjsbbM&md5=5cd8e3feea15ffa16785240f59e28bfb
31
del Pozo, C. A.; Cloete, S.; Álvaro, Á. J. Standard Economic Assessment (SEA) Tool. https://bit.ly/3IXPWC8, 2021.
Google Scholar
There is no corresponding record for this reference.
32
del Pozo, C. A.; Cloete, S.; Álvaro, Á. J. SEA Tool User Guide. https://bit.ly/3jq9Bkf, 2021.
Google Scholar
There is no corresponding record for this reference.
33
Turton, R.; Bailie, R. C.; Whiting, W. B. Analysis, Synthesis and Design of Chemical Processes: Appendix A; Pearson Education, 2008.
Google Scholar
There is no corresponding record for this reference.
34
Woods, D. R. Rules of Thumb in Engineering Practice; Wiley-YCH, 2007; p 383.
Google Scholar
There is no corresponding record for this reference.
35
Feron, P. H. M.; Cousins, A.; Jiang, K. An update of the benchmark post-combustion CO2-capture technology. Fuel 2020, 273, 117776 DOI: 10.1016/j.fuel.2020.117776
Google Scholar
35
An update of the benchmark post-combustion CO2-capture technology
Feron, Paul H. M.; Cousins, Ashleigh; Jiang, Kaiqi; Zhai, Rongrong; Garcia, Monica
Fuel (2020), 273 (), 117776CODEN: FUELAC; ISSN:0016-2361. (Elsevier Ltd.)
A review. This study provides a description of a new benchmark post-combustion CO2 capture (PCC) technol. reflecting the publicly reported performances by various technol. suppliers. To achieve this several amines and amine formulations have been considered using a process model developed in ProTreat. A 40 wt% formulation of PZ (piperazine)/AMP (amino-methyl-propanol) in a 1:2 M ratio was selected as the most representative of the current state of the art. A PCC process configuration with absorber intercooling and rich split flow was selected to reflect the fact that the technol. suppliers use a variety of process designs to optimize the process performance. The techno-economic performances were further detailed for the PCC process integrated with an ultra-supercrit. coal fired power station and a natural gas fired combined-cycle. The techno-economic evaluation of the PCC process indicated that the costs of capture with respect to 30 wt% MEA for the coal-fired power station were reduced by 22% and for the natural gas fired combined-cycle by 15%.
>> More from SciFinder ^®
https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3cXmvFWks7k%253D&md5=6213020e357cb99a39a58e21cdac0726

Cited By

Click to copy section linkSection link copied!

This article has not yet been cited by other publications.

Download PDF

Get e-Alerts

Energy & Fuels

Cite this: Energy Fuels 2023, 37, 16, 12030–12044

Click to copy citationCitation copied!

https://doi.org/10.1021/acs.energyfuels.3c00885

Published August 7, 2023

CC-BY 4.0 .

Article Views

Altmetric

Citations

Learn about these metrics

Article Views are the COUNTER-compliant sum of full text article downloads since November 2008 (both PDF and HTML) across all institutions and individuals. These metrics are regularly updated to reflect usage leading up to the last few days.

Citations are the number of other articles citing this article, calculated by Crossref and updated daily. Find more information about Crossref citation counts.

The Altmetric Attention Score is a quantitative measure of the attention that a research article has received online. Clicking on the donut icon will load a page at altmetric.com with additional details about the score and the social media presence for the given article. Find more information on the Altmetric Attention Score and how the score is calculated.

Abstract
High Resolution Image
Download MS PowerPoint Slide
Figure 1
Figure 1. Illustration of the CSAR working principle.
High Resolution Image
Download MS PowerPoint Slide
Figure 2
Figure 2. CSTR control volume network used to simulate the CSAR reactor system in VTSA mode.
High Resolution Image
Download MS PowerPoint Slide
Figure 3
Figure 3. CSTR control volume network used to simulate the CSAR reactor system in TSA mode.
High Resolution Image
Download MS PowerPoint Slide
Figure 4
Figure 4. Process scheme for winter and summer mode operation of the CSAR process. Continuous lines represent winter mode, and dashed lines represent summer mode.
High Resolution Image
Download MS PowerPoint Slide
Figure 5
Figure 5. MEA capture plant process scheme.
High Resolution Image
Download MS PowerPoint Slide
Figure 6
Figure 6. Breakdown of liquified CO₂ costs for the different technologies assuming electricity and heat prices of 60 and 30 €/MWh, respectively.
High Resolution Image
Download MS PowerPoint Slide
Figure 7
Figure 7. Capital cost breakdown of the three plants. “Other equipment” comprises blowers and flue gas coolers for MEA, while the heat and vacuum pump costs dominate this category for the CSAR plants.
High Resolution Image
Download MS PowerPoint Slide
Figure 8
Figure 8. Effect of CSAR heat and vacuum pump costs on its competitiveness against the MEA benchmark. The heat pump includes the heat pump compressor, the NH₃ drum, and the heat exchanger surfaces inside the reactors.
High Resolution Image
Download MS PowerPoint Slide
Figure 9
Figure 9. Effect of heat and electricity prices on the liquified CO₂ costs resulting from the CSAR and MEA plants considered in this study. 50 and 0% in the legend refer to the fraction of free heat available during the year.
High Resolution Image
Download MS PowerPoint Slide
Figure 10
Figure 10. Combinations of electricity and heat prices where MEA (solid line) and CSAR are the preferred options with and without the availability of free heat during summer months. Approximated performance of an advanced PZ/AMP solvent (dashed line) is also included as a stricter benchmark.
High Resolution Image
Download MS PowerPoint Slide
References
This article references 35 other publications.
1. 1
  UNFCCC. Historic Paris Agreement on Climate Change 2015. Available from: https://unfccc.int/process-and-meetings/the-paris-agreement/the-paris-agreement.
  There is no corresponding record for this reference.
2. 2
  IPCC. Fifth Assessment Report: Mitigation of Climate Change, Intergovernmental Panel on Climate Change, 2014.
  There is no corresponding record for this reference.
3. 3
  IEA. CUS in clean energy transitions, in Energy Technology Perspectives, Special report on carbon capture utilization and storage; International Energy Agency, 2020.
  There is no corresponding record for this reference.
4. 4
  IPCC. Global Warming of 1.5 °C, Intergovernmental Panel on Climate Change, 2018.
  There is no corresponding record for this reference.
5. 5
  Gapminder. Global income mountains 2022. Available from: https://www.gapminder.org/fw/income-mountains/.
  There is no corresponding record for this reference.
6. 6
  Fajardy, M.; Dowell, N. M. Can BECCS deliver sustainable and resource efficient negative emissions?. Energy Environ. Sci. 2017, 10, 1389– 1426, DOI: 10.1039/c7ee00465f
  6
  Can BECCS deliver sustainable and resource efficient negative emissions?
  Fajardy, Mathilde; Mac Dowell, Niall
  Energy & Environmental Science (2017), 10 (6), 1389-1426CODEN: EESNBY; ISSN:1754-5706. (Royal Society of Chemistry)
  A review. Neg. emissions technologies (NETs) in general and bioenergy with CO2 capture and storage (BECCS) in particular are commonly regarded as vital yet controversial to meeting our climate goals. In this contribution we present a whole-systems anal. of the BECCS value chain assocd. with cultivation, harvesting, transport and conversion in dedicated biomass power stations in conjunction with CCS, of a range of biomass resources - both dedicated energy crops (miscanthus, switchgrass, short rotation coppice willow), and agricultural residues (wheat straw). We explicitly consider the implications of sourcing the biomass from different regions, climates and land types. The water, carbon and energy footprints of each value chain were calcd., and their impact on the overall system water, carbon and power efficiencies was evaluated. An extensive literature review was performed and a statistical anal. of the available data is presented. In order to describe the dynamic greenhouse gas balance of such a system, a yearly accounting of the emissions was performed over the lifetime of a BECCS facility, and the carbon "break-even time" and lifetime net CO2 removal from the atm. were detd. The effects of direct and indirect land use change were included, and were found to be a key determinant of the viability of a BECCS project. Overall we conclude that, depending on the conditions of its deployment, BECCS could lead to both carbon pos. and neg. results. The total quantity of CO2 removed from the atm. over the project lifetime and the carbon break-even time were obsd. to be highly case specific. This has profound implications for the policy frameworks required to incentivize and regulate the widespread deployment of BECCS technol. The results of a sensitivity anal. on the model combined with the investigation of alternate supply chain scenarios elucidated key levers to improve the sustainability of BECCS: (1) measuring and limiting the impacts of direct and indirect land use change, (2) using carbon neutral power and org. fertilizer, (3) minimizing biomass transport, and prioritizing sea over road transport, (4) maximizing the use of carbon neg. fuels, and (5) exploiting alternative biomass processing options, e.g., natural drying or torrefaction. A key conclusion is that, regardless of the biomass and region studied, the sustainability of BECCS relies heavily on intelligent management of the supply chain.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC2sXls1ygt7c%253D&md5=d133376dc81665c9ff3b601213cfb1be
7. 7
  Dong, J.; Tang, Y.; Nzihou, A. Comparison of waste-to-energy technologies of gasification and incineration using life cycle assessment: Case studies in Finland, France and China. J. Cleaner Prod. 2018, 203, 287– 300, DOI: 10.1016/j.jclepro.2018.08.139
  7
  Comparison of waste-to-energy technologies of gasification and incineration using life cycle assessment: Case studies in Finland, France and China
  Dong, Jun; Tang, Yuanjun; Nzihou, Ange; Chi, Yong; Weiss-Hortala, Elsa; Ni, Mingjiang; Zhou, Zhaozhi
  Journal of Cleaner Production (2018), 203 (), 287-300CODEN: JCROE8; ISSN:0959-6526. (Elsevier Ltd.)
  Waste-to-Energy (WtE) has gradually constituted one of the most important options to achieve energy recovery from municipal solid waste (MSW). However, the environmental sustainability of a specific WtE system varies with used technologies and geog. differences. As a result, three representative WtE systems are compared using life cycle assessment (LCA): a gasification-based WtE plant in Finland, mech.-grate incineration in France, and circulating fluidized bed incineration in China. Results show that the overall environmental performance of the gasification system is better than incineration. The use of gasification technol., attributed to an intermediate syngas purifn. step, can provide benefits of both reducing the stack emissions and increasing the energy efficiency. Regional waste management, esp. related to MSW caloric value and emission regulation, are detg. factors for a preferable performance of the incineration in France over that in China. Sensitivity and uncertainty analyses further address key variations such as choice of MSW compn., basis of displaced electricity, energy recovery mode, and application of "best-available technol." dedicated to incineration. It is found that the most sensitive parameters influencing the LCA results are: electricity recovery, CO2 emission, and NOx emission. In the future, use of the source-sepd. high caloric waste combined with a more stringent emission std. can efficiently improve MSW incineration in China. Bottom ash recycling for metals and materials is highly applicable regarding incineration in France. This presented study can overall contribute to the development of specific WtE technol. and local waste management plan for decision-makers.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC1cXhs1eisb%252FE&md5=f26549ba0d23017e2d7a70a7f9265831
8. 8
  Roussanaly, S.; Ouassou, J. A.; Anantharaman, R. Impact of Uncertainties on the Design and Cost of CCS From a Waste-to-Energy Plant. Front. Energy Res. 2020, 8, 17 DOI: 10.3389/fenrg.2020.00017
  There is no corresponding record for this reference.
9. 9
  Chandel, M. K.; Kwok, G.; Jackson, R. B. The potential of waste-to-energy in reducing GHG emissions. Carbon Manage. 2012, 3, 133– 144, DOI: 10.4155/cmt.12.11
  9
  The potential of waste-to-energy in reducing GHG emissions
  Chandel, Munish K.; Kwok, Gabriel; Jackson, Robert B.; Pratson, Lincoln F.
  Carbon Management (2012), 3 (2), 133-144CODEN: CMAAC8; ISSN:1758-3004. (Future Science Ltd.)
  The combustion of municipal solid waste (MSW) to generate heat or electricity (waste-to-energy [WTE]) could reduce net GHG emissions in the USA compared with combusting methane from landfills. Moreover, neg. CO2 emissions could be achieved with CCS because 66% of the carbon in MSW is typically biogenic. For the five largest landfill sites in each state, we est. that at least 58 and 11 sites have enough MSW to fuel WTE plants of >50 MWe and >100 MWe, resp. Furthermore, half of these sites lie within 20 km of potential underground saline and other CO2 storage reservoirs. We est. that the levelized electricity cost for WTE without CO2 capture is US94/MWh and is $285/MWh with amine-based post-combustion capture technol. The cost of CO2 capture is $58/Mg CO2, resulting in a cost for carbon neg. emissions of $93/Mg CO2; substantially lower than for some geoengineering methods, including capturing CO2 from air.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC38XkvVOiu70%253D&md5=ed5a0a68ea245e2a02b26d51300b2015
10. 10
  Mondino, G.; Grande, C. A.; Blom, R. Evaluation of MBTSA technology for CO2 capture from waste-to-energy plants. Int. J. Greenhouse Gas Control 2022, 118, 103685 DOI: 10.1016/j.ijggc.2022.103685
  10
  Evaluation of MBTSA technology for CO2 capture from waste-to-energy plants
  Mondino, Giorgia; Grande, Carlos A.; Blom, Richard; Nord, Lars O.
  International Journal of Greenhouse Gas Control (2022), 118 (), 103685CODEN: IJGGBW; ISSN:1750-5836. (Elsevier B.V.)
  Moving bed temp. swing adsorption (MBTSA) is a promising technol. for CO2 capture from flue gases. In a MBTSA unit, a selective adsorbent material is circulated between a low-temp. stage where it removes CO2 from the flue gas and a higher-temp. zone where it desorbs CO2 at higher purity. The main benefits of MBTSA are low pressure drops in the adsorption zone and the possibility to heat the adsorbent faster than std. adsorption technologies. This work evaluated via process simulations the use of the MBTSA technol. for CO2 capture from an industrial-scale waste-to-energy plant. To assess the technol. with realistic parameters, we measured heat transfer coeffs. in the heating section of a new MBTSA demonstrator unit using activated carbon spheres. The heating device was produced by 3D printing, and has rectangular channels on the gas-solid side rotated at 45° to facilitate solid flow. The heat transfer coeffs. increased with the flow rate of activated carbon particles, and the highest value of 120 W/m2K was measured for a sorbent mass flux of 3.5 kg/m2s. This information was used as input for the process simulations, and allowed a tailored and realistic design of an MBTSA unit capturing more than 90% of the exhaust CO2 with a purity above 95%. The rather high sp. heat duty of the process (5.7 MJ/kg CO2) can be attributed to the low adsorption capacity of the activated carbon. In this respect, significant improvements can be expected by employing adsorbents with higher adsorption capacity and selectivity, such as zeolites or metal-org. frameworks.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB38Xhslanur3I&md5=e34674261425f0f82f2f42d3095cc667
11. 11
  Haaf, M.; Anantharaman, R.; Roussanaly, S. CO2 capture from waste-to-energy plants: Techno-economic assessment of novel integration concepts of calcium looping technology. Resour., Conserv. Recycl. 2020, 162, 104973 DOI: 10.1016/j.resconrec.2020.104973
  There is no corresponding record for this reference.
12. 12
  Durán, I.; Rubiera, F.; Pevida, C. Vacuum swing CO2 adsorption cycles in Waste-to-Energy plants. Chem. Eng. J. 2020, 382, 122841 DOI: 10.1016/j.cej.2019.122841
  12
  Vacuum swing CO2 adsorption cycles in Waste-to-Energy plants
  Duran, Ines; Rubiera, Fernando; Pevida, Covadonga
  Chemical Engineering Journal (Amsterdam, Netherlands) (2020), 382 (), 122841CODEN: CMEJAJ; ISSN:1385-8947. (Elsevier B.V.)
  For the first time, the performance of vacuum swing adsorption-based processes for CO2 capture at waste-to-energy facilities was examd. CO2 capture and storage is gaining increasing attention in this sector. An anal. of simple cycle configurations for this application provided a ref. scenario to examine the potentiality of adsorption technol. This work maximized CO2 sepn. from solid waste incineration facility flue gas. Three vacuum swing adsorption and one vacuum/temp. swing adsorption configurations were assessed in a fixed-bed lab. app.; the effect of cycle design, no. of columns, and operational conditions were analyzed. The adsorbent was pine sawdust-based activated C, a forestry byproduct with great availability. A math. model developed in Aspen Adsorption complemented the exptl. study which validated the model. Addnl. simulations were performed to further evaluate the effect of different vacuum swing adsorption configurations had on product purity and recovery. With relatively simple configurations, consisting of a 4-bed max., CO2 recovery >95% was achieved and CO2 purity increased from 8 to ∼35-40%.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC1MXhvFCkt7vP&md5=8dd312ea63c913b6a00df55446665545
13. 13
  Tsupari, E.; Arponen, T.; Hankalin, V. Feasibility comparison of bioenergy and CO2 capture and storage in a large combined heat, power and cooling system. Energy 2017, 139, 1040– 1051, DOI: 10.1016/j.energy.2017.08.022
  13
  Feasibility comparison of bioenergy and CO2 capture and storage in a large combined heat, power and cooling system
  Tsupari, Eemeli; Arponen, Timo; Hankalin, Ville; Karki, Janne; Kouri, Sampo
  Energy (Oxford, United Kingdom) (2017), 139 (), 1040-1051CODEN: ENEYDS; ISSN:0360-5442. (Elsevier Ltd.)
  Heating and cooling is responsible for almost 50% of the final energy demand in Europe. One of the most developed combined heat, power and cooling (CHPC) systems in the world exists in Helsinki, Finland, operated by Helen Ltd. As one option for significant redns. in direct CO2 emissions from Helen's fleet, this paper presents case studies for different options regarding a multifuel CHP plant planned for Helsinki. The studied cases include coal firing, co-firing high proportion of forest residues with coal, applying post-combustion CCS for coal firing, and combination of CCS and biomass co-firing. The cases are compared in different market situations in terms of the operation and profitability of the plant portfolio. The results highlight the sensitivities of economic feasibility on different market prices. With the default values assumed, the co-firing case is about as profitable as coal firing solely at present price of CO2 allowances. If CO2 price increases, co-firing becomes the most feasible option until the combination of co-firing and CCS becomes the most feasible option if the price of CO2 allowance is high. However, this would require recognising bio-CCS, and the "neg." CO2 emissions it generates, in the regulations of EU Emissions Trading System.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC2sXhtlyisrrM&md5=ae8bbf60e544470842ac88faa6c0b64f
14. 14
  Gładysz, P.; Sowiżdżał, A.; Miecznik, M. Techno-Economic Assessment of a Combined Heat and Power Plant Integrated with Carbon Dioxide Removal Technology: A Case Study for Central Poland. Energies 2020, 13, 2841 DOI: 10.3390/en13112841
  14
  Techno-economic assessment of a combined heat and power plant integrated with carbon dioxide removal technology: a case study for central Poland
  Gladysz, Pawel; Sowizdzal, Anna; Miecznik, Maciej; Hacaga, Maciej; Pajak, Leszek
  Energies (Basel, Switzerland) (2020), 13 (11), 2841CODEN: ENERGA; ISSN:1996-1073. (MDPI AG)
  The objective of this study is to assess the techno-economic potential of the proposed novel energy system, which allows for neg. emissions of carbon dioxide (CO2). The analyzed system comprises four main subsystems: a biomass-fired combined heat and power plant integrated with a CO2 capture and compression unit, a CO2 transport pipeline, a CO2-enhanced geothermal system, and a supercrit. CO2 Brayton power cycle. For the purpose of the comprehensive techno-economic assessment, the results for the ref. biomass-fired combined heat and power plant without CO2 capture are also presented. Based on the proposed framework for energy and economic assessment, the energy efficiencies, the specific primary energy consumption of CO2 avoidance, the cost of CO2 avoidance, and neg. CO2 emissions are evaluated based on the results of process simulations. In addn., an overview of the relevant elements of the whole system is provided, taking into account technol. progress and technol. readiness levels. The specific primary energy consumption per unit of CO2 avoided in the analyzed system is equal to 2.17 MJLHV/kg CO2 for biomass only (and 6.22 MJLHV/kg CO2 when geothermal energy is included) and 3.41 MJLHV/kg CO2 excluding the CO2 utilization in the enhanced geothermal system. Regarding the economic performance of the analyzed system, the levelized cost of electricity and heat are almost two times higher than those of the ref. system (239.0 to 127.5 EUR/MWh and 9.4 to 5.0 EUR/GJ), which leads to neg. values of the Net Present Value in all analyzed scenarios. The CO2 avoided cost and CO2 neg. cost in the business as usual economic scenario are equal to 63.0 and 48.2 EUR/t CO2, resp., and drop to 27.3 and 20 EUR/t CO2 in the technol. development scenario. The anal. proves the economic feasibility of the proposed CO2 utilization and storage option in the enhanced geothermal system integrated with the sCO2 cycle when the cost of CO2 transport and storage is above 10 EUR/t CO2 (at a transport distance of 50 km). The technol. readiness level of the proposed technol. was assessed as TRL4 (technol. development), mainly due to the early stage of the CO2-enhanced geothermal systems development.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3cXhvFynsbvJ&md5=70b276072b1e38e702c888539531b693
15. 15
  Khorshidi, Z.; Ho, M. T.; Wiley, D. E. Techno-economic evaluation of using biomass-fired auxiliary units for supplying energy requirements of CO2 capture in coal-fired power plants. Int. J. Greenhouse Gas Control 2015, 32, 24– 36, DOI: 10.1016/j.ijggc.2014.10.017
  15
  Techno-economic evaluation of using biomass-fired auxiliary units for supplying energy requirements of CO2 capture in coal-fired power plants
  Khorshidi, Zakieh; Ho, Minh T.; Wiley, Dianne E.
  International Journal of Greenhouse Gas Control (2015), 32 (), 24-36CODEN: IJGGBW; ISSN:1750-5836. (Elsevier B. V.)
  Parasitically providing the energy required for CO2 capture from retrofitted coal power plants can lead to a significant loss in output of electricity. In this study, different configurations of auxiliary units are investigated to partially or totally meet the energy requirements for MEA post-combustion capture in a 500 MW sub-crit. coal-fired plant. The auxiliary unit is either a boiler, providing only the heat required for solvent regeneration in the capture process or a combined heat and power (CHP) unit, providing both heat and electricity. Using biomass in auxiliary units, the grid loss is reduced without increasing fossil fuel consumption. The results show that using a biomass CHP unit is more favorable than using a biomass boiler both in terms of CO2 emission redns. and power plant economic viability. By using an auxiliary biomass CHP unit, both the emission intensity and the cost of electricity would be marginally lower than for a coal plant with capture. Further emission redns. occur if CO2 is captured both from the coal plant and the auxiliary biomass CHP, resulting in neg. emissions. However, high incentive schemes (a carbon price higher than 55 $/t CO2 or a combination of lower carbon price and renewable energy certificates) or a low biomass price (lower than 1 $/GJ) are required to make CO2 capture from both the coal plant and the auxiliary biomass CHP unit economically attractive. All cost comparisons are for CO2 capture only and CO2 transport and storage are not included in this study.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC2cXhvVygsbbK&md5=2dba2f56d941f1ba62df6722ad554459
16. 16
  Kuramochi, T.; Faaij, A.; Ramírez, A. Prospects for cost-effective post-combustion CO2 capture from industrial CHPs. Int. J. Greenhouse Gas Control 2010, 4, 511– 524, DOI: 10.1016/j.ijggc.2009.12.008
  16
  Prospects for cost-effective post-combustion CO2 capture from industrial CHPs
  Kuramochi, Takeshi; Faaij, Andre; Ramirez, Andrea; Turkenburg, Wim
  International Journal of Greenhouse Gas Control (2010), 4 (3), 511-524CODEN: IJGGBW; ISSN:1750-5836. (Elsevier Ltd.)
  Industrial Combined Heat and Power plants (CHPs) are often operated at partial load conditions. If CO2 is captured from a CHP, addnl. energy requirements can be fully or partly met by increasing the load. Load increase improves plant efficiency and, consequently, part of the addnl. energy consumption would be offset. If this advantage is large enough, industrial CHPs may become an attractive option for CO2 capture and storage CCS. We therefore investigated the techno-economic performance of post-combustion CO2 capture from small-to-medium-scale (50-200 MWe max. elec. capacity) industrial Natural Gas Combined Cycle- (NGCC-) CHPs in comparison with large-scale (400 MWe) NGCCs in the short term (2010) and the mid-term future (2020-2025). The analyzed system encompasses NGCC, CO2 capture, compression, and branch CO2 pipeline. The tech. results showed that CO2 capture energy requirement for industrial NGCC-CHPs is significantly lower than that for 400 MWe NGCCs: up to 16% in the short term and up to 12% in the midterm future. The economic results showed that at low heat-to-power ratio operations, CO2 capture from industrial NGCC-CHPs at 100 MWe in the short term (41-44 euro/tCO2 avoided) and 200 MWe in the midterm future (33-36 euro/tCO2 avoided) may compete with 400 MWe NGCCs (46-50 euro/tCO2 avoided short term, 30-35 euro/tCO2 avoided mid-term).
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC3cXnsF2gu7k%253D&md5=fec70bc0c757250ae11a89bc8b8d8fcf
17. 17
  Magnanelli, E.; Mosby, J.; Becidan, M. Scenarios for carbon capture integration in a waste-to-energy plant. Energy 2021, 227, 120407 DOI: 10.1016/j.energy.2021.120407
  17
  Scenarios for carbon capture integration in a waste-to-energy plant
  Magnanelli, Elisa; Mosby, Jostein; Becidan, Michael
  Energy (Oxford, United Kingdom) (2021), 227 (), 120407CODEN: ENEYDS; ISSN:0360-5442. (Elsevier Ltd.)
  In this work, the performance of an amine-based post-combustion carbon capture system using MEA (monoethanolamine) integrated to a Waste-to-Energy (WtE) plant is studied. WtE plants are affected by fluctuations at different time-scales, due to changes in waste properties as well as variations in district heat demand. A dynamic model of the combined plant is used to study the effect of flue gas fluctuations on capture plant operation, and the effect of integrating the capture plant into the WtE plant. When the two plants are considered sep., the heat requirement of the capture plant corresponds to 27% of the nominal thermal capacity of the WtE plant. When integrating the two plants, steam extn. from the boiler drum to provide the heat necessary to the capture plant reduces the power and district heat prodn. of the WtE plant by 30% and 6% resp., while extn. from the turbine causes a redn. of 8% and 12%. By modifying the condensers' temp., it is possible to maintain 96% of the original district heat prodn. By performing carbon capture only when excess heat is available, it is possible to capture 47% of the CO2 emitted by the WtE plant, while reducing the power prodn. by only 5%.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3MXoslKhs7Y%253D&md5=017f149b89c8ac482df1bbd83bfb5d0a
18. 18
  Luberti, M.; Oreggioni, G. D.; Ahn, H. Design of a rapid vacuum pressure swing adsorption (RVPSA) process for post-combustion CO2 capture from a biomass-fuelled CHP plant. J. Environ. Chem. Eng. 2017, 5, 3973– 3982, DOI: 10.1016/j.jece.2017.07.029
  18
  Design of a rapid vacuum pressure swing adsorption (RVPSA) process for post-combustion CO2 capture from a biomass-fuelled CHP plant
  Luberti, Mauro; Oreggioni, Gabriel David; Ahn, Hyungwoong
  Journal of Environmental Chemical Engineering (2017), 5 (4), 3973-3982CODEN: JECEBG; ISSN:2213-3437. (Elsevier Ltd.)
  It was aimed to design a novel RVPSA (Rapid Vacuum Pressure Swing Adsorption) unit for CO2 concn. and recovery in order to achieve the aggressive CO2 capture target, i.e. 95+% CO2 purity and 90+% CO2 recovery at the same time, applied to an existing 10 MWth biomass-fuelled CHP plant. Biomass-fuelled CHP plants are deemed carbon-neutral on the grounds of the net CO2 addn. to the atm. as a result of its operation being practically zero, ignoring the CO2 emissions involved in the ancillary processes, such as soil enhancement, biomass transport and processing, etc. Furthermore, integrating the biomass-fuelled CHP plant with carbon capture, transport and storage enables carbon-neg. energy generation, as its net effect is to recover some CO2 in the air and then store it underground through this plant operation. By the way, a RVPSA process features more efficient utilization of the adsorbents in the column, leading to much higher bed productivity than a conventional adsorption process. Such a high bed productivity makes it easier to scale up this adsorption process for its application to industrial post-combustion capture. A two-stage, two-bed RVPSA unit was designed and simulated to capture CO2 from the biomass-fuelled CHP plant flue gas contg. 13.3% CO2 mole fraction. Effects of operating conditions such as the Purge-to-Feed ratio (P/F) and desorption pressure on the specific power consumption were investigated in detail. It was found that the integrated two-stage RVPSA unit was capable of achieving the following overall performances: CO2 recovery of 90.9%, CO2 purity of 95.0%, bed productivity of 21.2 molCO2/kg/h and power consumption of 822.9 kJ/kgCO2. The productivity of the RVPSA unit designed in this study was 20-30 times higher than those of the conventional CO2 capture VPSA processes.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC2sXhtlShu7%252FJ&md5=2696330c89269ac6138af38a1b717548
19. 19
  Webley, P. A. Adsorption technology for CO2 separation and capture: a perspective. Adsorption 2014, 20, 225– 231, DOI: 10.1007/s10450-014-9603-2
  19
  Adsorption technology for CO2 separation and capture: a perspective
  Webley, Paul A.
  Adsorption (2014), 20 (2-3), 225-231CODEN: ADSOFO; ISSN:0929-5607. (Springer)
  A review. The capture of CO2 from process and flue gas streams and subsequent sequestration was first proposed as a greenhouse gas mitigation option in the 1990s. This proposal spawned a series of lab. and field tests in CO2 capture which has now grown into a major world-wide research effort encompassing a myriad of capture technologies and ingenious flow sheets integrating power prodn. and carbon capture. Simultaneously, the explosive growth in materials science in the last two decades has produced a wealth of new materials and knowledge providing us with new avenues to explore to fine tune CO2 adsorption and selectivity. Lab. and field studies over the last decade have explored the synergy of process and materials to produce numerous CO2 capture technologies and materials based on cyclic adsorption processes. In this brief perspective, we look at some of these developments and comment on the application and limitations of adsorption process to CO2 capture. We identify major engineering obstacles to overcome as well as potential breakthroughs necessary to achieve commercialization of adsorption processes for CO2 capture. Our perspective is primarily restricted to post-combustion flue gas capture and CO2 capture from natural gas.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC2cXhs1Siu7o%253D&md5=5204244844661294757bca77df701b60
20. 20
  Dhoke, C.; Zaabout, A.; Cloete, S. Demonstration of the Novel Swing Adsorption Reactor Cluster Concept in a Multistage Fluidized Bed with Heat-Transfer Surfaces for Postcombustion CO2 Capture. Ind. Eng. Chem. Res. 2020, 59, 22281– 22291, DOI: 10.1021/acs.iecr.0c05951
  20
  Demonstration of the Novel Swing Adsorption Reactor Cluster Concept in a Multistage Fluidized Bed with Heat-Transfer Surfaces for Postcombustion CO2 Capture
  Dhoke, Chaitanya; Zaabout, Abdelghafour; Cloete, Schalk; Seo, Hwimin; Park, Yong-ki; Demoulin, Leyne; Amini, Shahriar
  Industrial & Engineering Chemistry Research (2020), 59 (51), 22281-22291CODEN: IECRED; ISSN:0888-5885. (American Chemical Society)
  This paper reports the exptl. demonstration of the novel swing adsorption reactor cluster (SARC) concept in a multistage fluidized bed reactor with inbuilt heat-transfer surfaces for postcombustion CO2 capture at a capacity up to 24 kg-CO2/day. SARC employs combined temp. and vacuum swings (VTSA), driven by heat and vacuum pumps, to regenerate the solid sorbent after CO2 capture. The lab.-scale reactor utilized a vacuum pump and a heating oil loop (emulating the heat pump) to demonstrate 90% CO2 capture from an N2/CO2 mixt. approximating a coal power plant flue gas fed at 200 NL/min. In addn., dedicated expts. demonstrated three important features required for the success of the SARC concept: (1) the polyethyleneimine sorbent employed imposes no kinetic limitations in CO2 adsorption (referred to as carbonation) and only minor nonidealities in regeneration, (2) a high heat-transfer coeff. in the range of 307-489 W/M2 K is achieved on the heat transfer surfaces inside the reactor, and (3) perforated plate separators inserted along the height of the reactor can achieve the plug-flow characteristics required for high CO2 capture efficiency. Finally, sensitivity anal. revealed the expected improvements in CO2 capture efficiency with increased pressure and temp. swings and shorter carbonation times, demonstrating predictable behavior of the SARC reactor. This study provides a sound basis for further scale-up of the SARC concept.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3cXisFyrtLjE&md5=be7e9feed53f2c4a396cd2d5f4c4a810
21. 21
  Zaabout, A.; Romano, M. C.; Cloete, S. Thermodynamic assessment of the swing adsorption reactor cluster (SARC) concept for post-combustion CO2 capture. Int. J. Greenhouse Gas Control 2017, 60, 74– 92, DOI: 10.1016/j.ijggc.2017.03.001
  21
  Thermodynamic assessment of the swing adsorption reactor cluster (SARC) concept for post-combustion CO2 capture
  Zaabout, Abdelghafour; Romano, Matteo C.; Cloete, Schalk; Giuffrida, Antonio; Morud, John; Chiesa, Paolo; Amini, Shahriar
  International Journal of Greenhouse Gas Control (2017), 60 (), 74-92CODEN: IJGGBW; ISSN:1750-5836. (Elsevier B.V.)
  This paper presents the novel swing adsorption reactor cluster (SARC) for post combustion CO2 capture. The SARC concept consists of a cluster of bubbling/turbulent multistage fluidized bed reactors which dynamically cycle a solid sorbent between carbonation and regeneration. A synergistic combination of vacuum swing through a vacuum pump and temp. swing through a heat pump is employed to ensure high process efficiency. The base case SARC configuration imposed an energy penalty of 9.64%-points on a conventional coal-fired power plant, which is in line with advanced amine-based absorption processes. Sensitivity analyses showed that significant potential for further improvements (∼1.5%-points) exist through mechanisms such as an increase in the no. of reactor stages, further redns. in regeneration pressure and optimization of the cycle length. Addnl. efficiency improvements can also be traded for increased reactor footprint. However, future sorbent material selection studies esp. for this novel process hold the largest potential for further efficiency improvements. The SARC concept is well suited to retrofitting purposes due to limited integration with the steam cycle, and the simple standalone reactor design will simplify future scale-up efforts. The concept is therefore recommended for further study.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC2sXlslantbw%253D&md5=7c3148fcb96d81401a34f7f1f2315eac
22. 22
  Dhoke, C.; Cloete, S.; Amini, S. Study of the Cost Reductions Achievable from the Novel SARC CO2 Capture Concept Using a Validated Reactor Model. Ind. Eng. Chem. Res. 2021, 60, 12390– 12402, DOI: 10.1021/acs.iecr.1c00357
  22
  Study of the Cost Reductions Achievable from the Novel SARC CO2 Capture Concept Using a Validated Reactor Model
  Dhoke, Chaitanya; Cloete, Schalk; Amini, Shahriar; Zaabout, Abdelghafour
  Industrial & Engineering Chemistry Research (2021), 60 (33), 12390-12402CODEN: IECRED; ISSN:0888-5885. (American Chemical Society)
  New process concepts, such as the swing adsorption reactor cluster (SARC) CO2 capture process, are often techno-economically investigated using idealized modeling assumptions. This study quantifies the impact of this practice by updating a previous economic assessment with results from an improved reactor model validated against recently completed SARC lab-scale demonstration expts. The exptl. comparison showed that the assumption of chem. equil. was valid, that the previously employed heat transfer coeff. was conservatively low, and that the required redn. of axial mixing could be easily achieved using simple perforated plates in the reactor. However, the assumption of insignificant effects of the hydrostatic pressure gradient needed to be revised. In the economic assessment, the neg. effect of the hydrostatic pressure gradient was almost canceled out by deploying the exptl. obsd. heat transfer coeffs., resulting in a small net increase in CO2 avoidance costs of 2.8-4.8% relative to the unvalidated model. Further redns. in axial mixing via more perforated plates only brought minor benefits, but a shorter reactor enabled by the fast exptl. obsd. adsorption kinetics had a larger pos. effect: halving the reactor height reduced CO2 avoidance costs by 13.3%. A new heat integration scheme feeding vacuum pressure steam raised from several low-grade heat sources to the SARC desorption step resulted in similar gains. When all improvements were combined, the optimal CO2 avoidance cost was 23.7% below the best result from prior works. The main uncertainty that needs to be overcome to realize the great economic potential of the SARC concept is long-term sorbent stability: mech. stability must be improved substantially and long-term chem. stability under real flue gas conditions must be demonstrated.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3MXhslersL%252FJ&md5=4e507d9451b94ceb7a074caa43a3e93b
23. 23
  Zerobin, F.; Pröll, T. Concentrated Carbon Dioxide (CO2) from Diluted Sources through Continuous Temperature Swing Adsorption (TSA). Ind. Eng. Chem. Res. 2020, 59, 9207– 9214, DOI: 10.1021/acs.iecr.9b06177
  23
  Concentrated Carbon Dioxide (CO2) from Diluted Sources through Continuous Temperature Swing Adsorption (TSA)
  Zerobin, Florian; Proell, Tobias
  Industrial & Engineering Chemistry Research (2020), 59 (19), 9207-9214CODEN: IECRED; ISSN:0888-5885. (American Chemical Society)
  CO2 capture and storage and most CO2 capture and utilization routes require concd. CO2 streams for efficient compression, pipeline transport, injection, or chem. syntheses. The achieved quality of the CO2-rich product stream greatly affects the CO2 capture energy effort, resulting in widely scattered figures for CO2 capture in the literature. This wok specifically addressed the provision of concd. CO2 (>99 vol. percent) from dil. sources. A continuously operated temp.-swing adsorption process (TSA) was selected to illustrate tech. challenges. A detailed steady-state process model was used for a thermodn. evaluation (previously developed for the com. available solid sorbent, Lewatit VP OC 1065). Three typical inlet CO2 concns. corresponding to atm. air (0.04 vol. percentdb), gas turbine combined cycle exhaust gas (4 vol. percentdb), and solid fuel combustion exhaust gas (10 vol. percentdb) were assessed. Each case was optimized in terms of stage configuration, sorbent circulation rate, and stripping steam rate. For direct air capture with a 50% rate, two stages were used in the adsorber and 10 stages were used in the desorber; for the capture from exhaust gas mixts., a 90% capture rate and a 4 x 4 stage configuration were used. Specific total energy demand for capture and concn. was 10 times higher for direct ambient air capture (25.76 MJ/kgCO2 heat @ 120° + 8.26 MJ/kgCO2 power) vs. combustion exhaust gas capture with 4 vol. percentdb (3.64 MJ/kgCO2 heat @ 120° + 0.09 MJ/kgCO2 power) and 10 vol. ercentdb (3.21 MJ/kgCO2 heat @ 120° + 0.04 MJ/kgCO2 power). A simple exergy anal. showed ∼3 times higher irreversibility for direct air capture vs. capture from the two more concd. source streams.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3cXmvFGgsL4%253D&md5=c91a17908cfd1f9dee2c8480e6a7329a
24. 24
  Dhoke, C.; Cloete, S.; Krishnamurthy, S. Sorbents screening for post-combustion CO2 capture via combined temperature and pressure swing adsorption. Chem. Eng. J. 2020, 380, 122201 DOI: 10.1016/j.cej.2019.122201
  24
  Sorbents screening for post-combustion CO2 capture via combined temperature and pressure swing adsorption
  Dhoke, Chaitanya; Cloete, Schalk; Krishnamurthy, Shreenath; Seo, Hwimin; Luz, Ignacio; Soukri, Mustapha; Park, Yong-ki; Blom, Richard; Amini, Shahriar; Zaabout, Abdelghafour
  Chemical Engineering Journal (Amsterdam, Netherlands) (2020), 380 (), 122201CODEN: CMEJAJ; ISSN:1385-8947. (Elsevier B.V.)
  Adsorption-based post-combustion CO2 capture is enjoying significant research attention due to its potential for significant redns. in energy penalty, cost and environmental impact. Recent sorbent development work has focussed on polyethyleneimine (PEI) and dry sorbents that exhibit attractively low regeneration energy requirements. The main objective of this study is to identify best suitable sorbent for the recently published swing adsorption reactor cluster (SARC) concept. The screening results of four sorbents indicated two PEI sorbents to be good candidates for SARC application: a PEI sorbent functionalized with 1,2-epoxybutane supported on silica (referred to as EB-PEI in the rest of the document) and a PEI sorbent supported on mesoporous silica contg. confined metal org. framework nanocrystals (referred to as PEI-MOF in the rest of the document). High resoln. single-component isotherms revealed substantial differences in adsorption capacity and optimal operating temps. for the two PEI sorbents, and CO2 and H2O isotherm models were derived from this data. Subsequently, breakthrough expts. and lab-scale reactor tests showed that co-feeding of CO2 and H2O had no significant effect, allowing the single-component isotherm models to be safely used in large-scale reactor simulations. Such a reactor model was then employed to illustrate the effect of the sorbent adsorption characteristics on the efficiency of the novel swing adsorption reactor cluster, which combines pressure and temp. swings. The EB-PEI and PEI-MOF sorbents were compared to a previously published PEI sorbent with distinctly different adsorption behavior and recommendations for future sorbent development work were made.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC1MXhs1Gksb%252FK&md5=4516fc8993e10177d8a7fc179f0637a8
25. 25
  Cloete, S.; Giuffrida, A.; Romano, M. C. Economic assessment of the swing adsorption reactor cluster for CO2 capture from cement production. J. Cleaner Prod. 2020, 275, 123024 DOI: 10.1016/j.jclepro.2020.123024
  25
  Economic assessment of the swing adsorption reactor cluster for CO2 capture from cement production
  Cloete, Schalk; Giuffrida, Antonio; Romano, Matteo C.; Zaabout, Abdelghafour
  Journal of Cleaner Production (2020), 275 (), 123024CODEN: JCROE8; ISSN:0959-6526. (Elsevier Ltd.)
  Cement prodn. is responsible for about 8% of global CO2 emissions. Most of these emissions originate from the process itself and thus cannot be avoided via clean energy, leaving CO2 capture as the only viable soln. This study investigates the prospects of decarbonizing the cement industry via the swing adsorption reactor cluster (SARC) - a new post-combustion CO2 capture technol. that requires no integration with the host process, consumes only elec. energy and shows a competitive energy penalty. SARC operates by synergistically combining a temp. swing using a heat pump and a vacuum swing using a vacuum pump. In the present study, the SARC concept is evaluated economically and compared to several benchmarks. SARC achieves CO2 avoidance costs of euro52/ton in the base case, which is higher than oxyfuel combustion, similar to calcium looping and lower than four other technol. options. SARC can approach the cost of oxyfuel combustion with more optimistic assumptions regarding economies of scale, particularly for the vacuum pump. The local electricity mix is another important factor because SARC, as an electricity consumer, becomes more attractive when the price and CO2 intensity of electricity is low. Furthermore, the simplicity of retrofitting existing cement plants with the SARC process becomes increasingly valuable when rapid CO2 emissions redns. are targeted. SARC is therefore well positioned for a global decarbonization effort aiming to limit global warming well below 2°C.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3cXhsVymsr7E&md5=296afa8b615b97789aeae98c5ed22623
26. 26
  Dhoke, C.; Zaabout, A.; Cloete, S. The swing adsorption reactor cluster (SARC) for post combustion CO2 capture: Experimental proof-of-principle. Chem. Eng. J. 2018, 377, 120145 DOI: 10.1016/j.cej.2018.10.082
  There is no corresponding record for this reference.
27. 27
  Kim, K.; Seo, H.; Kim, D. J. Experimental evaluation of CO2 capture with an amine impregnated sorbent in dual circulating fluidized bed process. Int. J. Greenhouse Gas Control 2020, 101, 103141 DOI: 10.1016/j.ijggc.2020.103141
  27
  Experimental evaluation of CO2 capture with an amine impregnated sorbent in dual circulating fluidized bed process
  Kim, Kiwoong; Seo, Hwimin; Kim, Dae Jin; Lee, Chungwoo; Min, Da Young; Kim, Hye Mi; Park, Yong-Ki
  International Journal of Greenhouse Gas Control (2020), 101 (), 103141CODEN: IJGGBW; ISSN:1750-5836. (Elsevier B.V.)
  Carbon Capture and Sequestration (CCS) technol. to slow global warming is a challenge to be solved worldwide. In this study, a dual circulating fluidized bed process using a solid-sorbent was developed for the post-combustion CO2 capture process from a pulverized coal power plant. This solid-sorbent-based CO2 capture process consists of absorber, regenerator, and standpipes in between them. An amine-functionalized silica was utilized as a solid-sorbent, and a bench-scale facility capable of treating flue gas of 20 Nm3/h was constructed for the performance verification. As a result, when the sorbent to CO2 ratio was 24.6 wt/wt%, a CO2 capture efficiency of 80% or more was obtained, and the max. CO2 working capacity was 4.5 wt%. A long-term stability was verified in the bench-scale facility and, as a result, the sorption capacity decreased by 5% for about 800 cycles. In addn., a solid-solid indirect heat exchanger was applied at the upper part of the absorber to partially recover solid sensible energy to reduce the regeneration energy. The sorbent loading inside the tube affects the heat transfer efficiency, and the heat transfer coeff. ranges from 8 to 10.5 W/m2-K.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3cXhslKqurbL&md5=489bf61c7f34e75eebe6b66eaddae0b9
28. 28
  Kukade, S.; Kumar, P.; Rao, P. V. Comparative study of attrition measurements of commercial FCC catalysts by ASTM fluidized bed and jet cup test methods. Powder Technol. 2016, 301, 472– 477, DOI: 10.1016/j.powtec.2016.06.040
  28
  Comparative study of attrition measurements of commercial FCC catalysts by ASTM fluidized bed and jet cup test methods
  Kukade, Somanath; Kumar, Pramod; Rao, Peddy V. C.; Choudary, Nettem V.
  Powder Technology (2016), 301 (), 472-477CODEN: POTEBX; ISSN:0032-5910. (Elsevier B.V.)
  Catalyst loss due to fines generation by attrition is a major problem in refinery fluid catalytic cracking (FCC) units as it impacts inventory loss. Attrition resistance of catalyst is one of the crit. parameter in catalyst selection for a FCC unit. ASTM D5757 fluidized bed attrition test is the most commonly used attrition resistance test method to rank FCC catalysts and additives. In the present study, catalyst attrition tests were performed for FCC catalysts using an ASTM fluidized bed, cylindrical jet cup and conical jet cup. Performance ranking shows that attrition index obtained by these tests vary, but the order of ranking remains unchanged for ASTM fluidized bed and conical jet cup test methods as compared to cylindrical jet cup test. The investigation conducted here shows that morphol. of attrited fresh FCC catalyst using conical jet cup was found to be similar to plant equil. catalyst and also takes less attrition time relative to ASTM fluidized bed.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC28XhtV2nsL3I&md5=12e02c0a4470c49ca1ea8ad72f1ebffe
29. 29
  Si, W.; Yang, B.; Yu, Q. Deactivation Kinetics of Polyethylenimine-based Adsorbents Used for the Capture of Low Concentration CO(2). ACS Omega 2019, 4, 11237– 11244, DOI: 10.1021/acsomega.9b00792
  29
  Deactivation Kinetics of Polyethylenimine-based Adsorbents Used for the Capture of Low Concentration CO2
  Si, Wenting; Yang, Bin; Yu, Qingni; Lei, Lecheng; Zhu, Jingke
  ACS Omega (2019), 4 (6), 11237-11244CODEN: ACSODF; ISSN:2470-1343. (American Chemical Society)
  CO2 emission is generally regarded as the major contributor to global climate change and polyethylenimine (PEI)-based CO2 adsorbents are promising material for the capture of low concn. CO2. The paper deals with the deactivation kinetics of PEI-based CO2 adsorbents used for the capture of low concn. CO2. EA and TG analyses demonstrated that thermal degrdn. and O2-induced deactivation of the adsorbents occurred simultaneously under air-exposure condition. It was found by N2-exposure expts. at the temp. of 50-80° that the thermal degrdn. of PEI-based adsorbents followed 1st-order reaction model with an activation energy of 80.98 kJ/mol and a pre-exponential factor of 6.055×108 (h-1). Parallel reaction model was employed to distinguish the O2-induced deactivation from the thermal degrdn. of the adsorbents through air-exposure expts. within 50-80°. The O2-induced deactivation exhibited a 2nd-order reaction with an activation energy of 74.47 kJ/mol and a pre-exponential factor of 6.321×106 (%-1•h-1). The results of simulating the overall deactivation of the adsorbent by the parallel-reaction kinetic model were well consistent with those of the expts., proving the parallel reaction model was feasible for the description of the deactivation of PEI-based adsorbents.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC1MXht1Kis7%252FO&md5=310f2a8bc0b4eb5b249b2266782eb4d9
30. 30
  Choi, W.; Min, K.; Kim, C. Epoxide-functionalization of polyethyleneimine for synthesis of stable carbon dioxide adsorbent in temperature swing adsorption. Nat. Commun. 2016, 7, 12640 DOI: 10.1038/ncomms12640
  30
  Epoxide-functionalization of polyethyleneimine for synthesis of stable carbon dioxide adsorbent in temperature swing adsorption
  Choi, Woosung; Min, Kyungmin; Kim, Chaehoon; Ko, Young Soo; Jeon, Jae Wan; Seo, Hwimin; Park, Yong-Ki; Choi, Minkee
  Nature Communications (2016), 7 (), 12640CODEN: NCAOBW; ISSN:2041-1723. (Nature Publishing Group)
  Amine-contg. adsorbents have been extensively investigated for post-combustion carbon dioxide capture due to their ability to chemisorb low-concn. carbon dioxide from a wet flue gas. However, earlier studies have focused primarily on the carbon dioxide uptake of adsorbents, and have not demonstrated effective adsorbent regeneration and long-term stability under such conditions. Here, we report the versatile and scalable synthesis of a functionalized-polyethyleneimine (PEI)/silica adsorbent which simultaneously exhibits a large working capacity (2.2 mmol g-1) and long-term stability in a practical temp. swing adsorption process (regeneration under 100% carbon dioxide at 120°C), enabling the sepn. of concd. carbon dioxide. We demonstrate that the functionalization of PEI with 1,2-epoxybutane reduces the heat of adsorption and facilitates carbon dioxide desorption (>99%) during regeneration compared with unmodified PEI (76%). Moreover, the functionalization significantly improves long-term adsorbent stability over repeated temp. swing adsorption cycles due to the suppression of urea formation and oxidative amine degrdn.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BC28XhsVKjsbbM&md5=5cd8e3feea15ffa16785240f59e28bfb
31. 31
  del Pozo, C. A.; Cloete, S.; Álvaro, Á. J. Standard Economic Assessment (SEA) Tool. https://bit.ly/3IXPWC8, 2021.
  There is no corresponding record for this reference.
32. 32
  del Pozo, C. A.; Cloete, S.; Álvaro, Á. J. SEA Tool User Guide. https://bit.ly/3jq9Bkf, 2021.
  There is no corresponding record for this reference.
33. 33
  Turton, R.; Bailie, R. C.; Whiting, W. B. Analysis, Synthesis and Design of Chemical Processes: Appendix A; Pearson Education, 2008.
  There is no corresponding record for this reference.
34. 34
  Woods, D. R. Rules of Thumb in Engineering Practice; Wiley-YCH, 2007; p 383.
  There is no corresponding record for this reference.
35. 35
  Feron, P. H. M.; Cousins, A.; Jiang, K. An update of the benchmark post-combustion CO2-capture technology. Fuel 2020, 273, 117776 DOI: 10.1016/j.fuel.2020.117776
  35
  An update of the benchmark post-combustion CO2-capture technology
  Feron, Paul H. M.; Cousins, Ashleigh; Jiang, Kaiqi; Zhai, Rongrong; Garcia, Monica
  Fuel (2020), 273 (), 117776CODEN: FUELAC; ISSN:0016-2361. (Elsevier Ltd.)
  A review. This study provides a description of a new benchmark post-combustion CO2 capture (PCC) technol. reflecting the publicly reported performances by various technol. suppliers. To achieve this several amines and amine formulations have been considered using a process model developed in ProTreat. A 40 wt% formulation of PZ (piperazine)/AMP (amino-methyl-propanol) in a 1:2 M ratio was selected as the most representative of the current state of the art. A PCC process configuration with absorber intercooling and rich split flow was selected to reflect the fact that the technol. suppliers use a variety of process designs to optimize the process performance. The techno-economic performances were further detailed for the PCC process integrated with an ultra-supercrit. coal fired power station and a natural gas fired combined-cycle. The techno-economic evaluation of the PCC process indicated that the costs of capture with respect to 30 wt% MEA for the coal-fired power station were reduced by 22% and for the natural gas fired combined-cycle by 15%.
  >> More from SciFinder ^®
  https://chemport.cas.org/services/resolver?origin=ACS&resolution=options&coi=1%3ACAS%3A528%3ADC%252BB3cXmvFWks7k%253D&md5=6213020e357cb99a39a58e21cdac0726
Supporting Information
Supporting Information
The Supporting Information is available free of charge at https://pubs.acs.org/doi/10.1021/acs.energyfuels.3c00885.
- Full economic assessment of the CSAR cases and the MEA benchmark (ZIP)
- ef3c00885_si_001.zip (2.15 MB)
Terms & Conditions

Most electronic Supporting Information files are available without a subscription to ACS Web Editions. Such files may be downloaded by article for research use (if there is a public use license linked to the relevant article, that license may permit other uses). Permission may be obtained from ACS for other uses through requests via the RightsLink permission system: http://pubs.acs.org/page/copyright/permissions.html.

Prospects of the Novel CSAR Concept for Fully Electric or Flexible Electric–Thermal Hybrid CO2 Capture from CHP PlantsClick to copy article linkArticle link copied!

Energy & Fuels

License Summary*

Abstract

License Summary*

License Summary*

License Summary*

1. Introduction

2. Continuous Swing Adsorption Reactor (CSAR)

Figure 1

3. Methodology

3.1. CSAR Reactor Modeling

3.1.1. Chemistry

3.1.2. Mass and Energy Balances

3.1.3. Solution Method

3.1.4. CSAR in VTSA and TSA Modes

Figure 2

Figure 3

3.1.5. Model Uncertainties

3.2. Process Modeling

3.2.1. CSAR Process Model

Figure 4

3.2.2. MEA Process Model

Figure 5

3.3. Economic Assessment

4. Results and Discussion

4.1. Technical Results

4.2. Economic Results

Figure 6

Figure 7

Figure 8

4.3. Sensitivity to Electricity and Heat Prices

Figure 9

Figure 10

5. Conclusions

Supporting Information

Terms & Conditions

Author Information

Acknowledgments

List of Acronyms

Additional Notes

References

Cited By

Energy & Fuels

License Summary*

Article Views

Altmetric

Citations

Recommended Articles

Abstract

Figure 1

Figure 2

Figure 3

Figure 4

Figure 5

Figure 6

Figure 7

Figure 8

Figure 9

Figure 10

References

Supporting Information

Supporting Information

Terms & Conditions

Prospects of the Novel CSAR Concept for Fully Electric or Flexible Electric–Thermal Hybrid CO₂ Capture from CHP Plants
Click to copy article linkArticle link copied!