1. Introduction
Fossil fuels have played a significant role in shaping modern civilisation and powering its progress. They are indispensable in meeting the world’s growing energy demands [
1]. It is estimated that they provided over 80% of the total energy supply in 2022 [
2]. In recent decades, the increase in emissions, primarily carbon dioxide (CO
2), along with additional greenhouse gases (GHGs) such as methane (CH
4), nitrous oxide (N
2O), and chlorofluorocarbons (CFCs) has been identified as a leading cause of global warming and climate change. This poses a threat to the sustainability of the ecosystem [
3]. A report by the Joint Research Centre (JRC) states that around 90% of the world’s CO
2 emissions are caused by the combustion of fossil fuels [
4]. Considering the pressing necessity to reduce carbon dioxide emissions and address the environmental consequences of global climate change, policymakers are currently confronted with a dual challenge. In addition to this, they must also consider the potential impact of lower emission targets on the oil market [
5]. The apparent trade-off between economic growth and CO
2 emissions is at the heart of these issues. Improving environmental outcomes can sometimes come at the expense of economic growth [
6]. While fossil fuels play a significant role in global energy generation, renewable energy is essential for decarbonising the economy, addressing climate change, and achieving global carbon neutrality [
7,
8]. As a result, economies have ratified the Paris Climate Agreement and Kyoto Protocol [
6], both of which aim to reduce greenhouse gas emissions [
4].
Carbon capture, utilisation, and storage (CCUS) represents a viable strategy for the decarbonisation of fossil-based power and industrial sectors. It has been identified as the most effective method for reducing CO
2 emissions [
9]. By the year 2050, it is projected that CCUS will contribute 10% to the cumulative global emission reduction [
10], as well as a means of facilitating a long-term transition to a zero-emission future [
9] within this century [
11]. To achieve this, renewable energy solutions also need to be implemented, while also considering energy diversification. To enable that, various studies are conducted on alternative fuels, like biogas, biochar, biodiesel, and hydrogen [
12], and other various biomass-derived synthetic fuels [
13]. Efficient heat production and heat management for heating systems is also of great importance [
14,
15].
Global research has focused on utilising renewable energy sources and improving energy efficiency [
16], hydrogen being of particular interest. Hydrogen is a fuel with a high energy density that is clean and has a calorific value 2.7 times greater than that of fossil fuels, such as natural gas and gasoline. Furthermore, it produces almost zero pollution [
17]. Fuel cells have emerged as an alternative to internal combustion engines in recent years due to their high efficiency, fuel flexibility, and reliable, clean energy [
16]. They are considered an alternative energy source due to their advantages [
18], which include low emissions compared to fossil fuels [
16,
18,
19]. There is a variety of fuel cell types, namely Polymer Electrolyte Membrane Fuel Cells (PEMFCs), Molten Carbonate Fuel Cells (MCFCs), Direct Methanol Fuel Cells (DMFCs), Alkaline Fuel Cells (AFCs), Phosphoric Acid Fuel Cells (PAFCs), and Solid Oxide Fuel Cells (SOFCs) [
20]. They can be classified as either low-temperature or high-temperature fuel cells, with SOFCs belonging to the latter [
21,
22].
SOFCs are one of the most promising power generation technologies for high energy conversion efficiency, while also being strongly adaptive to various carbon-containing fuels, which provides the potential for integration with biomass gasification [
23], and further improves the adaptability of SOFCs in multi-generation systems [
20]. They utilise hydrogen or hydrogen carriers such as biogas, natural gas, e-fuels or e-fuel, and ammonia [
24,
25,
26,
27] as a fuel. Among the zero-carbon fuels, ammonia is also considered a potential SOFC fuel. It has the potential of being produced through green routes, i.e., from hydrogen via electrolysis using electricity from renewable sources [
24]. Other advantages, besides fuel flexibility, include the low greenhouse gas emissions, no moving parts, and good part-load performance [
28]. While SOFCs come with a variety of advantages, the disadvantages should also be considered. A high operating start-up temperature and chemical and mechanical problems need to be taken into consideration when designing SOFCs [
29]. To achieve a commercial breakthrough, it is also necessary to address the challenge of their durability and stability [
30].
Another problem that SOFCs tackle is the balancing of high energy demand in times of power shortages. This trend is seen in recent years, due to the rapid adoption of wind and solar power generation capacities, causing unpredictable supply and demand [
31]. This trend is set to continue and even accelerate in line with climate change objectives, when more renewables are adopted [
32]. Even if solar energy is considered as an effective solution for transition to renewable energy, due to its carbon-neutral characteristics, the operational down-time between power generation constraints large-scale application. To overcome these challenges and to ensure the sustainability of future energy systems, energy storage and production technologies are needed to balance the supply and demand [
23]. Because of renewable energy adoption, conventional coal and nuclear power plants are harder to adapt to sudden supply and demand changes. Considering the mentioned problems, fuel cells play a crucial role in supplying energy during times of peak energy demands.
SOFCs can reach total electric efficiencies up to 45–60% [
19,
33,
34,
35,
36], while high-efficiency SOFC hybrid systems can be even higher [
20,
37,
38,
39]. The overall heat and electric efficiency of those combined heat and power (CHP) systems can reach 90–95% [
18,
28,
40]. These high efficiencies are due to the high operating temperature of the SOFC, which allows for the recovery of exhaust heat using various technologies. A study using a double-effect absorption refrigeration cycle and multi-effect distillation with thermal vapor compression unit technologies to recover exhaust heat from the SOFC-GT system was carried out and found the electrical efficiencies can be raised up to 65.77% [
39]. In a former study, the overall efficiency of a fuel cell system was successfully raised by pairing it with a high-temperature heat pump, where the exhaust heat was used as a preheating method of water [
41]. Recent studies also tried different alternatives to couple a SOFC with a classic or organic Rankine cycle [
42,
43,
44,
45]. The Rankine cycle (RC) is an important technical method for recovering waste heat and improving energy efficiency [
46].
The objective of this study is to simulate a SOFC-RC-CCUS hybrid system that utilises biogas whose flowrate is approximated from the operating data of a real biogas plant. For this purpose, computer simulations using Aspen Plus V12.1 software were conducted. The system aims to assess the feasibility of fully utilising generated waste heat of high SOFC operating temperatures, enabling utilisation of hot exhaust gases for additional power production [
35] in a modified RC, while also fully integrating the process. After heat utilisation, vacuum swing adsorption is used to capture CO
2 from exhaust gases, which is then compressed, liquefied, and stored, while the generated heat from this process is used to generate sanitary hot water. Carbon capture contributes to sustainability of the system, which also comes directly from the choice of sustainable biogas as a fuel [
47]. The fuel has an advantage over the fossil fuel-powered SOFCs. Although fossil fuels have a negative impact on the environment due to their carbon emissions, their use in SOFCs can reduce emissions [
41], as fuel cells are more efficient in producing electricity compared to conventional power generation methods [
35]. SOFCs produce less SO
x and CO
2 emissions compared to traditional combustion methods, while SOFC plants have higher efficiency and lower emissions compared to other fossil-fuelled energy systems [
19].
The use of biogas as an alternative has great advantages, since coupling with CC means that the process could even be considered carbon negative, since CO
2 would not be released into the atmosphere. A disadvantage of biogas, however, is that it has a lower methane content than natural gas, while also impurities, mainly H
2S, should be considered, since the process in this case requires additional purification before fuel can enter the system. H
2S should not be present in the system, since it is corrosive, poisons reformer catalysts, and is not tolerable by SOFCs [
47].
A system’s operation is reliant upon energy demand and is cycled upon that demand. In real-time operation, the system would operate at full capacity at peaks of power demand, while the output of the system would drop at times of low energy demand. Captured CO2 would be stored for potential later use, to produce synthetic fuels, like synthetic natural gas, when excess electricity would be available. The process, with a combination of synthetic fuel production, would in this way contribute to balancing the periods of low and high energy demand. Due to cycling, the system is considered as more reliable in comparison to conventional energy generation methods, like nuclear and thermal powerplants, and even when comparing the system to solar and wind power, since the former systems cannot effectively respond to variable energy supply and demand. Wind and solar can generate power only when their respective natural resources are available, while nuclear and thermal power plants can adjust their power output, but rapid changes are not desired.
The significance, contribution, and novelty of the system comes from the next key aspects of the process:
The process can operate at times when variable renewable solutions like solar cannot provide enough constant energy supply. In this way, the process provides a solution to balance out the peaks of high energy demand and increases energy reliability.
A common practice of biogas plants is to provide heat and power [
31]. The adoption of the system would help to raise the power output of the biogas plants, since biogas is commonly burned on site through various types of engines, gas, and steam turbines [
47], which have lower efficiencies. Replacing those would increase the efficiency of existing biogas power plants.
Biogas plants are commonly placed in more rural areas, which usually do not have, or have a smaller, industry sector. The adoption of process would bring additional job opportunities and provide hot sanitary water to smaller local districts.
There is a potential to couple the process with synthetic fuel production in periods of low energy demand, e.g., synthetic natural gas, which could be used as a green alternative for local fuel demand, contributing to sustainable energy solutions.
An improved and modified version of a classic RC is adopted in a current study, increasing the efficiency of the RC, due to steam reheating between a high- and low-pressure turbine.
The process is fully integrated, making it self-sufficient and decreasing the reliability on outside heat sources, where heat losses can occur between transferring the heat to the specific process units. This also increases the efficiency and lowers the environmental impact and operating costs.
As the last step of the process, CC was considered, making the current proposed process carbon negative.
The proposed system uses biogas as a green alternative to fossil fuels.
It should be noted that the combination of a SOFC and RC is not a new concept, as previously mentioned, but at the time of writing, the authors are not aware of any studies or research papers that have simulated the process using a such-modified version of RC, while also fever studies exist on similar biogas fed hybrid systems. The authors also are not aware of studies that integrate biogas-fed SOFC, modified RC, post-RC carbon capture, liquefaction, and storage/usage in such way, while providing extensive study of the proposed system. Novelty and innovation also come from a utilisation of waste heat in the CCUS section, while the process offers a great alternative of completely utilising hot exhaust gases provided by the SOFC.
2. Materials and Methods
Aspen Plus is the market leader in process simulators with over 40 years of experience and information. It is used by many of the world’s largest chemical companies because of its flexibility and wide range of applications. Built-in process modelling, cost estimation, energy management, safety analysis, and process improvement with built-in artificial intelligence are just some of the features of the software [
48].
Figure 1 presents the simplified flowchart of the proposed process, while
Figure 2 shows a detailed flowsheet of the simulated process.
The process is consisting of four main components: steam reforming, SOFC, integrated modified Rankine cycle, and CO2 separation and liquefaction. The former includes the pre-treatment and steam reforming.
The aim of the system is to achieve higher efficiencies than conventional systems, while using a green fuel as an alternative to fossil fuel-driven SOFCs. In the proposed system, biogas is first reformed and then fed to the SOFC, which was chosen as the main power generation method because SOFCs offer higher electrical efficiency compared to other conventional power generation methods. This is possible because electricity is generated directly from the electrochemical reaction. The process is thus not limited by the Carnot cycle, compared to traditional thermal power plants [
35]. SOFCs are flexible in the fuels they can use, and can be considered sustainable when operating on biofuels [
33]. For the current study, biogas, a sustainable fuel, was chosen, contributing to the sustainability of the SOFC and the whole system.
Since the fuel in SOFCs is not fully utilised, it is partially recycled, while the remaining fuel is burned. Part of the resulting hot flue gases is used to supply heat to the system, which eliminates the need for hot utilities in continuous operation, thus eliminating operating costs and reducing the system’s dependence on external sources, increasing reliability. Since SOFC provides hot flue gases, due to a high operating temperature, there is a possibility to utilise this remaining heat. The remaining hot flue gases are therefore sent to a modified RC, which uses the heat from the gases to generate additional power, increasing overall and electrical efficiencies. Cooled flue gases are then sent to the CCUS section where CO2 is captured, compressed, and liquefied. The electrical efficiency is slightly reduced in this section due to the compression, but the overall efficiency is increased due to the useful heat generated by the compression. Carbon capture is also preferred because it prevents the release of CO2 into the atmosphere, thus contributing to the sustainability of the system.
At the beginning of the process, biogas inflow is introduced, with properties and composition based on a real-life example, and is presented in
Section 2.1. The biogas then passes through a separator (VLS-1), which separates condensed water (WS-1) from the vapour phase. The fuel stream FS-1 is then fed into a compressor (C-1), where the discharge pressure is set to the operating pressure of 1.2 bar [
49], and the appropriate isentropic and mechanical efficiencies are set based on existing compressors on the market. In the process, heat losses and pressure drops were neglected. The pressurised vapour then passes into a stream mixer (E-1), combining with the recycled depleted fuel (A-EXH-11) from the SOFC. The outlet mixer flow (FS-4) is then fed into a plug–flow reactor (R-1) where the steam-reforming process occurs. Since reforming is endothermic, additional heat is supplied with SOFC hot flue gases (FG-12). The flowrate is adjusted with the splitter (SS-3) to set the desired outlet temperature of stream FS-5, representing reformed SOFC fuel. In the reformer, reactions with appropriate kinetics are defined and are discussed later in
Section 2.2. The resulting hydrogen rich stream (FS-5) is supplied into the SOFC anode, while the cathode is supplied with pre-heated air that is first compressed in C-2 to a pressure of 1.2 bar. Preheating occurs in a heat exchanger (AS-HE-1), where heat is supplied with a stream of flue gases FG-15. The amount of air needed is calculated using air utilisation (
Ua) and fuel utilisation (
Uf) values which are used to model the SOFC. The values were selected from a range of plausible options: the
Uf values in the literature vary from 0.68 to 0.95 [
20,
40,
50,
51], while the values of
Ua are commonly around 0.20 [
51,
52,
53,
54]. Since there is no direct way to simulate a fuel cell in Aspen Plus, SOFC was replicated with the available process units. The anode is represented with SOFC-A, and cathode is represented with SOFC-C and AS-HE-2. The modelling is discussed in more detail later in
Section 2.3.
The fuel cell anode exhaust gases are represented by stream A-EXH-1, and the depleted air from the SOFC is stream C-EXH-2. The splitter SS-1 is used to separate the anode exhaust into stream A-EXH-11, which is recycled into E-1, while the rest (stream A-EXH-21) is fed into combustor (R-2). This split ratio between streams is set in a way to achieve the specified steam-to-carbon ratio (
S/
C) in a reformer [
55]. The combustor is simulated with an RSTOIC unit (R-2) and is explained in
Section 2.3.
Hot flue gases (FG-1) of combustor outlets are split into two streams, FG-11 and FG-21, where the FG-11 stream is used to supply the heat demand of the reformer R-1 and air preheater AS-HE-1. To ensure the adequate preheating of air, a design specification that varies the split fraction of FG-11 in SS-2 until the temperature of stream FG-16 is 10 °C higher than the temperature of stream AS-2 is set. To supply heat to the reformer, a design specification of splitter SS-3 is set in a way that the specified temperature at the reformer outlet is achieved by varying the split fraction of stream FG-12.
The remaining flue gases (stream FG-21) are led through a modified RC, which is used to utilise the remaining heat for power production. A modified version of the classic Rankine cycle is used to achieve a higher efficiency. Flue gases (FG-21 through FG-25) pass through a series of heat exchangers in a counter-current flow with water/steam. In the first heat exchanger (RC-HPHW), pressurised water (HPW-2) is first heated to its boiling point. The exiting stream HPW-3 is then led through the boiler (RC-HPSG), used to generate saturated high-pressure steam (HPS-1), which is further superheated in RC-SHPSG. The stream SHPS-1 is then passed through high-pressure turbine RC-HPT. The exiting low-pressure steam (LPS-1) is reheated in RC-LPSR to generate superheated low-pressure steam (SLPS-1), then passed through low-pressure turbine RC-LPT. Saturated steam in a vacuum (VPS-1) is then condensed and pressurised in RC-COND and RC-P-1, respectively. To achieve condensation, river water (CW-1) at 9 °C is pumped into the condenser with a pump (RC-P-2), which raises its pressure to 5 bar. In accordance with the law, the outlet water temperature (CW-3) is heated by a temperature difference of 3 °C in comparison to CW-1. This is achieved with a design specification that varies the flowrate of stream CW-1. The pressurised water (HPW-1) then re-enters the RC, which is also represented in
Figure 3 in a form of temperature–entropy diagram.
To achieve proper heat utilisation in the RC, the design specification varies the flowrate of HPW-2 to achieve a 10 °C temperature difference between streams FG-25 and HPW-2. If the error for hot and cold stream temperature crossover was present, the temperature difference was gradually raised by 5 °C, until the crossover was resolved.
The exhausted flue gases (FG-25) and (FG-16) enter the carbon capture part of the process, where the condensed water (WS-2) is first removed in separator VLS-2. For the carbon capture process, the vacuum swing adsorption was assumed. The process was not simulated since it requires dynamic simulations and is based on a great amount of experimental data. Instead, it was modelled with a simple separator unit (VSA), where the CO2 was separated from the flue gases FG-3. The remaining gases, N2, H2O, and O2, are represented with a stream WS-3. For this purpose, the split fraction of CO2, N2, O2, and H2O to stream CC-1 were specified to the values of 0.98, 0.0001, 0.0001, and 0.0001, respectively, assuming 98% of CO2 would be captured, along with smaller amounts of other gasses (1%).
To store captured CO
2, multistage compression was added, with an additional liquefication. CO
2 is compressed in the compressors connected in series (C-3, C-4, C-5, C-6) to a pressure of 69 bar then liquefied by cooling the stream CC-9 to 18 °C [
56]. The liquefication is achieved with a simple ammonia (R717) refrigeration cycle, where the compression heat pump was set up in a way, that it could produce water at 60 °C.
To utilise the heat produced from the process of captured CO2 compression and liquefaction, the production of hot water for domestic use in a nearby district was assumed. The streams SHW-C-1 through SHW-C-4 are used to cool hot CO2 after each compression stage, while the heat from the refrigeration cycle is used to heat up stream SHW-C-5. The heated streams (SHW-H-1 through SHW-H-5) are then combined in the mixer SM-3.
The temperature of the hot water was assumed to be 60 °C, according to fourth generation district heating systems [
57]. To supply the water, an additional pump DH-P was placed on a flowsheet, which raises the pressure to 6 bar (stream SHW-1) [
58]. For the inlet temperature of the water, a value of 30 °C was taken from research of Lund et al. The value represents an approximated average return temperature of the domestic hot water tanks in their study [
59]. The same temperature difference of 10 °C was set between hot and cold streams in heat exchangers RC-HPWH, and CC-HE-1 through CC-HE-6.
The following limitations and assumptions were considered in the construction and modelling of the process.
A range of operating parameters was chosen by the review of literature data.
The process is a conceptual design, and therefore not optimised.
A workaround to simulate SOFC was made in Aspen Plus.
Heat and pressure losses were neglected.
The process was simulated in a steady-state and continuous mode.
2.1. Biogas Flowrate
The total biogas flowrate of the biogas plant was taken to be the same as in the previous study conducted by Rola et al. [
31]. It was assumed that impurities are removed before the power plant, and so the biogas at the inlet consists of only CH
4, CO
2, and H
2O, with molar flows of 16.67 kmol/h, 8.97 kmol/h, and 1.35 kmol/h, respectively. The temperature of the inlet was assumed to be 35 °C, while the pressure was set to 1 atm. Since the SOFC would be operated at times of high electricity demand, the SOFC capacity must be higher than the biogas production rate. For this purpose, a capacity of 3 days’ worth of biogas production was assumed, and so all the molar flowrates were multiplied by a factor of 3, while each simulation was set to run under this same biogas feed flowrate, 80.97 kmol/h.
2.2. Reactor and Reaction Kinetics
Prior to SOFC, carbon fuel is first reformed with water steam. Reforming is primarily described with three reactions, namely steam methane reforming (SMR), water–gas shift (WGS), and direct steam methane reforming (DSMR) reaction, represented with Equations (1)–(3), respectively [
53]. Only these reactions were considered in the reactor model, while the coking was explored outside of the Aspen Plus environment.
To model the reforming of biogas, the Langmuir–Hinshelwood–Hougen–Watson (LHHW) mathematical model developed by Xu and Froment [
60] was used. Even though the model was developed in 1989, it still stands as one of the most widely used mathematical models to describe kinetics over nickel–alumina catalysts. The proof of this is that many of the papers compare, cite, and even use the same kinetics to model SR even in recent years [
53,
61,
62,
63,
64,
65]. The model is described by the following Equations (4)–(6), representing the kinetics of SMR, WGS, and DSMR reactions, respectively.
In the model, the rate of corresponding reaction is represented by
r,
p is partial pressure of the respective component (methane (CH
4), water (H
2O), hydrogen (H
2), carbon monoxide (CO) or carbon dioxide (CO
2)),
k is the rate constant of the corresponding reaction, following the Arrhenius equation,
K is the adsorption constant of the denoted component, following Van’t Hoff’s equation, and
Keq is the equilibrium constant of the respective reaction. The parameters for rate, adsorption, and equilibria constants are represented in
Table 1.
The model was used in a plug–flow reactor (PFR), modelled in a co-current flow with reactants and combustion products of R-2, where the combustion flue gases supply the heat to the PFR. In a reactor, a constant overall heat transfer coefficient of 20 W/(m
2K) was assumed from a study [
66]. The density of the catalyst and porosity were set to 2179 kg/m
3 and 0.39, respectively, according to [
53]. The reactor’s length, number of tubes, and their diameter were set to be 10 m, 500, and 0.1 m, respectively. The dimensions were chosen arbitrarily, so that the reaction mixture reaches equilibrium at a specified temperature of the SOFC anode inlet. For simplicity reasons, this temperature is denoted as reformer operating temperature. The temperature is reached with a design specification that varies the split fraction of stream FG-12 in a stream splitter SS-2.
An additional calculator was set to provide a specified steam-to-carbon ratio (
S/
C) at the reformer inlet, calculated with Equation (7), from respective molar flowrates of the molecules. The
S/
C ratio was then achieved by adjusting the split fraction of stream A-EXH-11 in stream splitter SS-1.
2.3. SOFC and Combustion
Since Aspen Plus does not have readily available models to simulate fuel cells, a workaround was made. The anode (SOFC-A) and cathode (SOFC-C with AS-HE-2) were modelled separately as an equilibrium reactor and component splitter with heat exchanger, respectively. The splitter serves to reproduce the oxygen consumption/reduction in the fuel cell. The oxygen ion is the charge carrier in the SOFC. It is transported through the electrolyte to the anode side where it reacts with H
2 to produce electrons. This transfer cannot be simulated in Aspen Plus, so the overall reaction of the cell half reactions was used [
52], in accordance with Equation (8).
To simulate fuel consumption in SOFC, the anode was modelled as an equilibrium reactor, where the SMR, WGS (Equations (1) and (2)), and overall electrochemical reaction of the SOFC, described by Equation (8) [
40], were defined. Additionally, the exhaust temperature of stream A-EXH-1 was defined in SOFC-A, to simulate the heat up of the anode fuel stream inside the SOFC stack.
To model the oxygen consumption, and therefore fuel consumption in SOFC, a component splitter was used as a cathode, where the split fraction of oxygen to the stream SOFC-M was taken as the air utilisation of the SOFC [
52]. To ensure that specific fuel utilisation of SOFC is achieved, Equation (9) was derived and set in a calculator block. The block calculates the required air flowrate (
) from the specified
Uf, defined by Equation (10), where
and
are consumed fuel in SOFC and fresh fuel at the SOFC inlet, respectively, in a form of equivalent hydrogen flowrate [
54], which is calculated from the molar flowrates of CH
4, H
2, and CO (
,
, and
), according to Equation (11) [
52]. The numbers 0.79 and 0.21 represent the mole fractions of nitrogen and oxygen in air, respectively.
To calculate the power of the SOFC, another calculator block was set up. The power output in the SOFC (PSOFC) can be calculated by multiplying the voltage (VSOFC) and current (ISOFC), according to Equation (12).
The reversible voltage (
VSOFC, rev) was calculated from Equation (13) [
40], where ∆
G° is standard Gibbs free energy of electrochemical reaction (Equation (8));
F is the Faraday constant, with a value of 96,485 As/mol;
Tavg is the average temperature between the SOFC inlet and outlet;
p is pressure;
p0 reference pressure of 1 atm; and
xavg represents the average mole fraction between the inlet and outlet of the SOFC for the corresponding molecule (H
2, O
2, or H
2O) [
49].
The current was calculated by Equation (14). Substituting Equations (13) and (14) into Equation (12) gives Equation (15), which represents the reversible power of the cell (
PSOFC, rev) [
67]. To account for voltage losses in a fuel cell, the reversible power was multiplied by a factor of 0.65, which was held constant through the simulations.
The calculated power was set to be written on the heat stream SOFC-P in the heat splitter HS. This stream represents the power output of the SOFC, while the heat flow Q-3 was adjusted to a low value of 1 kW through a design specification that varies the air utilisation or split fraction in cathode SOFC-C. This simulates the removal of generated heat through heating up the depleted air (C-EXH-1) in the SOFC, represented by the heater AS-HE-2, where the temperature is specified to be the same as the defined temperature of block SOFC-A.
The value of heat stream Q-1 is subtracted from the heat generated by reactions taking place in the SOFC, and the only value that is close to the calculated power of the SOFC remains in stream Q-2. In this way, energy balance of the fuel cell is established. The decision to set the value of the heat stream Q-3 to 1 kW, rather than 0 kW, can be attributed to convergence reasons. To help with the convergence of the design specification, a looser solution interval between 0.9 kW and 1.1 kW was also specified.
The remaining fuel, which is not recycled with generated water in the SOFC, was combusted in block R-2. The combustion was modelled as a stoichiometric reactor, where oxidation reactions of H
2, CO, and CH
4 were specified, according to Equations (8), (16), and (17), respectively [
68,
69].
It was assumed that the remaining fuel would be completely oxidised, and the combustor was set to be adiabatic. In this way, the flue gases are heated up by the generated heat in combustion.
2.4. Base Case Simulation
In all simulations, the temperature of the stream AS-3 was set to be the same as the reformer-specified operating temperature (temperature of stream FS-5). The temperature of the SOFC operation was set in block SOFC-A, and the depleted air heater AS-HE-2 was set to heat up the air to that same temperature. Like stream AS-3, stream C-EXH-2 was therefore set up to be the same as the temperature of stream A-EXH-1.
First, the base case of the process was run, where the reformer operating temperature was set to 650 °C, and the SOFC exhaust temperature was set to 850 °C. For simplicity, this specified outlet temperature is denoted as the operating temperature of the SOFC.
In this simulation, the S/C of 2.5 was specified in the calculator that varies the split fraction of stream A-EXH-11 in SS-1, and the fuel utilisation was specified to the value of 0.70 in a calculator that calculates the air flowrate AS-1.
After a successful run, the temperature, pressure, vapour fraction, flowrate, and composition of each stream, and heat and work duty of process units were recorded. Additionally, results from relevant design specifications and calculators, like SOFC power, air utilisation, and S/C ratio were taken from the run. After the run S/C, SOFC power, fuel utilisation, and temperature difference in relevant heat exchangers was checked manually, through calculation in excel to make sure that calculators and design specifications were properly converged, and no error was made.
System performance indicators, like the SOFC’s electrical efficiency, system’s overall efficiency, and system’s electrical efficiency were calculated. For the reformer, calculation of total methane conversion was carried out, while the danger of catalyst coking due to Boudouard reaction (Equation (18)) [
23] was investigated. Since the idea of the process is to also provide heat in a form of domestic hot water, while utilising the residual heat of captured carbon compression, the number of consumer households was estimated.
2.5. Sensitivity Analysis
After the base case, the simulation was carried out at different operating parameters. In the first sensitivity analysis, the effect of the reformer operating temperature at different SOFC operating temperatures was investigated, as shown in
Table 2. For the analysis, the
S/
C ratio and fuel utilisation were kept constant at 2.5 and 0.70, respectively.
In the second analysis, the effect of fuel utilisation was investigated, at various SOFCs. Fuel utilisation was varied between 0.60 and 0.90 with a step of 0.10. The investigated SOFC/reformer operating temperatures were 750 °C/550 °C, 800 °C/600 °C, 850 °C/650 °C, 900 °C/700 °C, and 950 °C/750 °C. The S/C ratio was kept constant at 2.5.
The third analysis was conducted while varying the S/C ratio between 1.5 and 3.5 with a step of 0.5, for the selected SOFC/reformer temperatures of 750 °C/550 °C, 850 °C/650 °C, and 950 °C/750 °C, to cover the SOFC and reformer operating temperature range. In this analysis, the fuel utilisation was constant, with a value of 0.70.
Like in the case of base case simulation, various parameters were calculated in excel to confirm successful runs, and selected efficiencies, coking potential, and air utilisation were presented. The number of consumer households was not presented in the analysis, since the biogas flowrate, and therefore the number, stayed the same.
2.6. Results Analysis
2.6.1. Performance Indicators
To assess the system and SOFC performance, three efficiencies were calculated with Equations (19) [
70], (20) [
40], and (21) [
70], representing SOFC electrical (
ηSOFC), system electrical (
ηel), and system overall efficiency (
ηoverall), respectively.
where
PSOFC represents the power output of SOFC,
molar flowrate of biogas,
LHVbiogas lower heating value of biogas,
Win total inputted work in the system,
Wout is generated work, and
useful output heat from the system. The latter is calculated as a sum of exchanged heat in heat exchangers CC-HE-1 through CC-HE-4, and CC-HE-6, used to produce domestic hot water.
Wout is calculated as a sum of the produced power of SOFC and turbines RC-HPT and RC-LPT, while Win is a sum of the required work to run the compressors, C-1 through C-7, and pumps, RC-P-1, RC-P-2, and DH-P.
2.6.2. Coking Potential and Methane Conversion
Since it is known that the Ni catalysts, used in SOFCs and reforming reactors, are susceptible to coking (Equation (18)) [
33], its danger was explored in a way of calculating the equilibrium constant of coking reaction (
Kp) and comparing it to the reaction quotient (
Qp) of the reformer outlet composition. The equilibrium constant and reaction quotient were calculated from Equations (22) and (23) [
71], respectively, where
xj is the mole fraction of the respective molecule,
p absolute pressure, and
p0 reference pressure of 1 atm.
To obtain the Gibbs free energy (∆
Gr) of coking reaction, Gibbs free energies of the species
j (∆
Gj) were first calculated from the corresponding enthalpies (∆
Hj) and entropies (∆
Sj), by Equation (24) [
72]. Those were calculated by the Shomate equation and parameters, which are available online for each species: CO [
73], CO
2 [
74], and C [
75]. The ∆
Gr was then calculated from Equation (25) [
72].
To assess the danger of coking, the ratio
Kp/
Qp was calculated. If the ratio is higher than 1 (
Kp >
Qp), it is considered that the equilibrium is shifted towards products [
71], and therefore carbon formation, while the values below 1 (
Kp <
Qp) indicate that the equilibrium is shifted towards reactants [
71], and coking would therefore not be present.
The conversion of methane (
) in reformer was calculated from Equation (26), where
and
are molar flowrates at the inlet and outlet of the reactor, respectively.
2.6.3. Hot Sanitary Water
It was assumed that an average household has an area of 234 m
2, with energy consumption of 160 kWh/(m
2a), of which 14.8% is used for the production of domestic hot water. Assuming a half-year SOFC operation and considering that the simulated process operates at a full capacity of 3 days’ worth of stored biogas 1 day, the number of possible consumer households (
N) was then approximated by Equation (27).
4. Conclusions
This study introduces a novel fully integrated SOFC-RC system with CCUS. The base case simulation at SOFC/reformer operating temperatures of 850 °C/650 °C and operating parameters S/C = 2.5, Uf = 0.70 Ua = 0.1806 provided an overall efficiency of 71.64%, with a 67.70% electrical efficiency and a refrigerant COP of 3.55. The latter is quite low compared to other SOFC systems, the reason being that this scheme is completely integrated. The advantage of the proposed system is that no outside sources of heat and electricity are needed and it is a net zero-emission process when it operates continuously.
A sensitivity analysis was performed, where a temperature range from 750 to 950 °C for the SOFC revealed that operating at the high temperature and low reactor temperatures was adequate for higher efficiencies, reaching up to 73.24% overall and 69.23% electrical efficiency at an operating temperature of 950 °C/650 °C. The main findings of the sensitivity analysis were that the efficiencies decrease along with air utilisation when raising the reformer operating temperature, due to increasing heat demand. Operating at an SOFC temperature of 950 °C, a 4.36% decrease in overall efficiency and a 15.34% decrease in air utilisation were noted when the reformer temperature was raised from 650 °C to 800 °C. However, the temperature has a positive effect on coking since higher temperatures decrease the Kp/Qp ratio. Increasing the reformer temperature at high operating temperatures shows a bigger drop off in efficiency than lower operating temperatures but pose a more suitable operating condition to avoid coking.
An unexpected observation could be attributed to the S/C ratio, which increased the system efficiencies in a more complex way. An increase of 1.91% in overall and electrical efficiency was found, when increasing the S/C ratio from 1.5 to 3.5 at operating temperatures of 850 °C/650 °C. It enhanced the conversion of methane to hydrogen, which was thought to increase the efficiency of the SOFC. Raising the operating temperatures unexpectedly lowered the efficiencies, which is likely due to the WGS reaction.
To achieve better performance, the importance of a fuel utilisation factor was studied within the sensitivity analysis. The simulations found that increasing it directly benefits the overall and electrical efficiency, since more power is produced in the SOFC and less in the RC, which has a lower efficiency. A peak overall efficiency of 74.26% was calculated for the fuel utilisation factor of 0.9, while lowering it to 0.6 gradually lowered the efficiency to 70.53%, for the base case scenario. Increasing fuel utilisation has a mostly positive effect on the system, increasing its efficiencies and methane conversion in the reformer. The ratio S/C gave some insight into the system operation, showing that increasing it displays better performance, meaning higher efficiencies. The reason being that it raises the inlet temperature into the reactor, and less heat is needed to satisfy its heat demand.
The proposed SOFC-RC with integrated CCUS system shows good electrical and overall efficiencies for a conceptual fully integrated project. It can provide 231 households with hot sanitary water from the surplus heat of CCUS, while mainly producing electricity in the SOFC and modified RC. A possible alteration to the scheme is utilising the WS-3 stream for the generation of additional hot sanitary water. In the future, optimisation of the system should be undertaken, while also considering different alternations to the scheme. To make the system even more reliable, and provide higher energy reliability, short-term battery storage could be considered in the future. An economic analysis of the final system layout would demonstrate its feasibility in large-scale implementation, while the current limitations and assumptions of the hybrid system should also be considered.
Hybrid SOFC systems are still a subject of extensive research, as evidenced by many articles that are published each year. Despite numerous studies, the investments are reported to be high, and several challenges regarding the technology persist. Nevertheless, it is predicted that the investment costs will decrease in future, leading to easier adoption of SOFCs and their hybrid systems. To help with advancement and to drive down investment costs, numerous studies exploring SOFC systems are still needed, while the implementation of such systems can be achieved with a help of subsidies and various funding programmes, granted to green energy alternatives.