Advanced Exergy, Exergoeconomic, and Exergoenvironmental Analyses of Integrated Solar-Assisted Gasification Cycle for Producing Power and Steam from Heavy Refinery Fuels

Abstract

Integrated solar-assisted gasification cycles (ISGC) have emerged as a more flexible and environmentally friendly solution for producing power, steam, and other high-valued by-products from low-cost opportunity fuels. In this light, this paper investigates a new ISGC system for converting heavy refineries fuels into power and steam utilities while enhancing energy efficiency and economic and environmental performance indicators. In this approach, a solar energy field and a two-pressure heat recovery steam generator were integrated into the ISGC system to improve overall economic and environmental plant viability. The ISGC system was modelled in MATLAB software, and the results were validated using Thermoflex software. Conventional and advanced energy, exergy, exergoeconomic, and exergoenvironmental (4E) analyses were implemented to assess the main performance parameters and identify potential system improvements. The ISGC system produced 319.92 MW of power by feeding on 15.5 kg/s of heavy refinery fuel, with a thermal efficiency of 50% and exergy efficiency of 54%. The results also revealed an investment cost of $466 million, evaluated at a system cost rate of 446 $/min and an environmental impact rate of 72,796 pts/min. The conventional and advanced 4E analyses unveiled the process economic and environmental feasibilities, particularly for oil-rich countries with high availability of solar resources.

1. Introduction

Integrated gasification combined cycles (IGCC) have received increased interest over the past few years as a more sustainable solution for the co-generation of power, steam, and other valuable by-products from heavy refinery residues. The high flexibility of IGCC systems on the input feed makes them very attractive for employment in various applications subjected to fuel availability and costs. In this way, a wide range of solid and liquid wastes can be used as base input fuel, including coal, municipal wastes, heavy liquid refinery residues (heavy oil), solid refinery waste (petroleum coke), and biomass, among others [1]. IGCC power systems provide improved economic viability to existing and new processing plants owing to their ability to generate power from syngas and additional high-valued utilities and feedstock chemical co-products (e.g., ammonia, methanol, etc.) from low-cost fuels [2,3]. Additional advantages include low production costs and the potential to meet tighter pollutant emissions standards on SO_x, NO_x, and particulates. IGCC systems also offer the possibility of reducing CO₂ emissions via pre-combustion gas purification, carbon capture and storage (CCS) [4], and gas switching combustion (GSC) technology [5]. Even though recent advances in gasification, syngas cleanup, air separation, and gas turbine technologies have driven process costs down and increased system performance, challenges remain in further enhancing energy and environmental performance requirements. In this context, the integration of renewable energy (particularly solar energy) into IGCC systems emerges as an attractive alternative.

IGCC power systems are composed of three main sections, namely, gasification, clean-up, and combined cycle [6]. The construction, operation, and maintenance of IGCC plants are generally more demanding than conventional power systems, eliciting an increase in capital investment and maintenance expenses and a reduction in reliability and availability [7]. Typically, IGCCs allow obtaining higher thermal efficiency over conventional coal-fired power plants (up to 60% when fueled with natural gas [2,8]), while the carbon emissions are lower than traditional power plants [7]. Another important benefit of IGCCs is the reduction of other pollutants. This is because the cycle allows the syngas to be purified after leaving the gasification reactor while a substantial amount of hydrogen sulphide and carbon dioxide is separated during the process [9]. In some cycles, the latter can be done via humidification, with the advantage of optimizing the amount of hydrogen produced in the syngas stream [10]. In an IGCC plant, oxygen blow technology can also be used in the gasification reactor to prevent nitrogen gas from interfering in the gasification process, by prompting a binding effect in reducing the toxic NO_x pollutant [11].

Nag et al. [12] performed energy and exergy analyses of a combined cycle with a fixed bed gasifier. Their results showed that the gasification reactor unit displayed the highest energy loss among other cycle components. Moreover, their exergy analysis results revealed that the temperature ratio did not influence the highest exergy destruction of the gasification process, whereas the pressure ratio had also a low effect. The authors concluded that the exergy destruction in the combustor can be reduced by increasing temperature and pressure ratios. Emun et al. [13] simulated an IGCC system employing a Texaco gasifier using Aspen Plus^® software. The system was operated via gasification using slurry based on a coal–water mixture (35.5% w/w water). Their results showed that the proposed process can achieve up to 45% thermal efficiency with a substantial decrement in SO_x and CO₂ emissions, reaching 0.15 kg/MWh and 698 kg/MWh, respectively.

Domenichini et al. [14] investigated hydrogen and power generation through a system fueled by refinery waste via pinch analysis. Their proposed approach was based on oxygen blow-entrained bed gasification, which was sized to produce a considerable hydrogen amount and feed gas turbines of the combined cycle unit. The authors focused on the heat integration among syngas cooling and sections of the combined cycle and reported a cost of 34 €/t for avoiding CO₂ emissions. Additionally, they concluded that the cost of electricity was attractive, with a hydrogen price of 9.5 cents/Nm³, highlighting the advantage of the combined production. Morini et al. [15] simulated an IGCC cycle with a 650-MW gasification unit. In addition, the authors considered an air-cooled driven gas turbine, in which the inlet air cooling was achieved using liquid nitrogen spray. They also accounted for actual temperature profiles of various locations for an entire year in the modelling formulation. Their findings indicated that the system presented the highest performance for Johannesburg, when compared to conventional inlet air cooling schemes.

Zhang and Ahn [16] investigated the prospects of two IGCCs in China for achieving near-zero emissions. Their proposed system was based on a pre-combustion gasification process with carbon dioxide adsorbent and sour and sweet shifts. The authors reported that the sweet shift required 4.6-fold more shift steam than the sour one due to the low amount of steam in the syngas after the removal of H₂S. Khoshgoftar Manesh and Jadidi [17] assessed the performance of a biomass-based IGCC fueled with olive pits by applying energy, exergy, exergy-economic, and exergy-environmental (4E) analyses. Their results indicated an output power of the IGCC of approximately 387.3 MW, with a cost of 5.23 US$/s and pollutants emissions of 41.72 mpts/s. Moreover, their results demonstrated that the gasifier had the largest exergy destruction rate, which accounted for a 24% share. The authors also showed that the gasifier and combustion chamber units had the highest avoidable exergy destructions, while the scrubber presented the lowest one. Szima et al. [5] implemented a techno-economic analysis of hydrogen and power production from the IGCC plant. The authors employed the gas switching combustion (GSC) for carbon capture, whereas membrane-assisted water gas shift (MAWGS) reactors were used for hydrogen production.

Table 1. A brief review of the most recent literature on the applications, methods, and practices related to integrated gasification combined cycles (IGCCs).

Year	Authors	Study Summary
2015	Morini et al. [15]	Simulation of a combined cycle with a 650-MW gasification unit.
2015	Jia et al. [18]	Simulation of a gasifier system with atmospheric solid oxide fuel cell, and investigation of the fuel cell electrical efficiency using two types of gasifiers: air and oxygen blower.
2015	Doherty et al. [19]	Simulation of a fuel cell cycle with biomass feed and evaluation of the effect of syngas temperature on the system performance, under four different scenarios.
2015	Chen et al. [20]	Investigation of a coal gasification cycle combined with a fuel cell via exergy destruction evaluation in equipment.
2015	Wang et al. [21]	Investigation of a combined cooling, heating, and power (CCHP) system with a biogas feed gasification system, which uses an absorption chiller system. The largest share of exergy destruction is related to the gasification unit.
2015	Athari et al. [22]	Investigation of a gas turbine cycle with fog cooling and biomass gasification.
2016	Perna et al. [23]	Investigation of combined biomass and solar energy sources in a gasification cycle for hydrogen production.
2016	Yari et al. [24]	Simulation of a solid oxide fuel cell at atmospheric pressure using a heat recovery system, which used a gasification system with biomass feed to produce fuels.
2016	Lv et al. [25]	Assessment of the efficiency of an integrated system with gas turbine and fuel cell-based biomass gasification.
2016	Thattai et al. [26]	Feasibility study on combining up to 70% of biomass resources with a coal feed in a 253-MW cycle.
2016	Khani et al. [27]	Simulation and optimization of a fuel cell and gas turbine using a genetic algorithm.
2018	Park et al. [28]	Modelling and simulation of a gasification cycle under different economic scenarios.
2019	Zhang and Ahn [16]	Investigation of the prospects of gasification power plants in China with near-zero emissions, using pre-combustion gasification with carbon dioxide adsorbent.
2020	Khoshgoftar Manesh and Jadidi [17]	Assessment of biomass-based IGCC with olive pits as feed and implemented 4E analyses.
2021	Szima et al. [5]	Techno-economic analysis of hydrogen and power production from the IGCC plant with the gas switching combustion (GSC) for carbon capture and membrane-assisted water gas shift (MAWGS) reactors to produce hydrogen.
2021	Bany Ata et al. [2]	Heat integration optimization and sensitivity analysis of an IGCC system based on lignite co-gasification and refuse-derived fuels for co-generating methanol and electricity.
2021	Muhammad et al. [3]	Thermodynamic and economic analysis of IGCC system for producing electricity, methane, and ammonia.

displays a brief overview of the most recent literature regarding applications, methodologies, and practices related to IGCCs.

Although previous studies constitute important contributions to the area, none considered energy, environmental, and economic analyses of integrated solar-aided gasification cycles for enhancing energy recovery from low-cost opportunity fuels. It should be noted that solar-aided IGCC systems are among the most efficient and cleanest methods for converting solid wastes and refinery residues into valuable power and heat utilities and other high-value chemical by-products needed by the refineries. For surpassing limitations on preceding research, this paper investigates a new integrated solar-assisted gasification cycle (ISGC) for producing steam and power from heavy refinery fuels while enhancing energy efficiency, economic, and environmental performance indicators. In the proposed cycle, the syngas from the gasifier enters the turbine to produce power after purification and separation of pollutants, and then it is sent to the steam section for thermal energy recovery. In addition, a solar energy field, a two-pressure heat recovery steam generator (HRSG), and CO₂ capture unit are integrated into the plant to enhance the overall system efficiency while reducing carbon emissions. The ISGC system was modelled and simulated in MATLAB software, and the results were validated using Thermoflex software. Conventional and advanced 4E analyses were implemented to assess energy, economic, and environmental ISGC system performances. The 4E analyses allows examining system units with an increased level of detail and thereby prioritize these equipment pieces for future optimization and improvement. Hence, the new approach provides a novel avenue towards dealing with heavy refinery fuels and turning an environmental issue into an opportunity, especially for oil-rich countries that enjoy high solar global irradiances. Major contributions and innovative features introduced by this study are highlighted as follows.

(1)

Combined heat and power co-generation from gasification of low-cost heavy refinery fuels for achieving enhanced energy recovery.

(2)

Solar-assisted energy generation via parabolic trough collectors to improve the overall system efficiency while reducing environmental impacts.

(3)

Integration of CO₂ absorber technology for further reducing pollutant emissions.

(4)

Comprehensive conventional and advanced energy, exergy, exergoeconomic, and exergoenvironmental analyses to evaluate main performance parameters and identify potential system improvements.

2. System Description

The integrated solar-gasification cycle is based on the IGCC cycles proposed by Zhang et al. [29] and Khoshgoftar Manesh and Jadidi [17], which provide a suitable base combined-cycle configuration. Yet, the proposed new ISGC system encompasses a partial gasification cycle under oxygen blowing with a pre-combustion chamber, together with a solar energy field (parabolic through collectors), two-pressure heat recovery steam generator (HRSG) and a CO₂ absorber, as depicted in Figure 1. It should also be noted that the study by Zhang et al. [29] used coal, and Khoshgoftar Manesh and Jadidi [17] employed biomass as feed for the IGCC power system. In contrast, the proposed ISGC plant is targeted at using heavy refinery fuel to take advantage of low-cost heavy refinery residues. Furthermore, conventional and advanced exergy, exergoeconomic, and exergoenvironmental evaluation are implemented to better shed light on the ISGC power system.

Table A1. Thermodynamic relations: process operating conditions and unknown parameters used for modelling the different ISGC system components.

Comp.	Relations	Process Conditions	Unknown Parameters
ASU	$$\begin{gathered} W_{ASU-air}={\dot{m}}_{air}(h_{out}-h_{in}) \\ {h}_{out}=h_{in}+v_{in}(P_{out}-P_{in}) \\ {W}_{ASU,O_2}={\dot{m}}_{O_2}(h_{out}-h_{in}) \\ {h}_{out}=h_{in}+v_{in}(P_{out}-P_{in}) \end{gathered}$$	$$\begin{gathered} T_{in}=15°\mathrm{C},P_{in}=1.013 \mathrm{bar} \\ {m}_{air}=121.3 \mathrm{kg}/\mathrm{s} \\ {T}_{out}=129.1 °\mathrm{C}, P_{out}=39 \mathrm{bar} \end{gathered}$$	${\dot{W}}_{ASU}$
Gasifier	$$\begin{gathered} {\displaystyle {\displaystyle \sum }_{in}}{\omega }_{in}\times {\dot{m}}_{in}={\displaystyle {\displaystyle \sum }_{out}}{\omega }_{out}\times {\dot{m}}_{out} \\ {Q}_{in}+{\displaystyle {\displaystyle \sum }_{in}}{\dot{m}}_h=Q_{out}+{\displaystyle {\displaystyle \sum }_{out}}{\dot{m}}_h \\ {\eta }_G=\frac{LH{V}_{syngas}\times {\dot{m}}_{syngas}}{LH{V}_{fuel}\times {\dot{m}}_{fuel}} \end{gathered}$$	$$\begin{gathered} {\displaystyle {\displaystyle \sum }_{in}}\dot{m}=79.6 \mathrm{kg}/\mathrm{s} \\ LH{V}_{fuel}=\mathrm{22,054.8} \mathrm{kJ}/\mathrm{kg} \\ LH{V}_{syngas}=9549.7 \mathrm{kJ}/\mathrm{kg} \end{gathered}$$	$$\begin{gathered} {\eta }_G \\ {\dot{m}}_{syngas} \end{gathered}$$
Humidifier	$$\begin{gathered} {\displaystyle {\displaystyle \sum }_{in}}{\phi }_{in}\times {\dot{m}}_{in}={\displaystyle {\displaystyle \sum }_{out}}{\phi }_{out}\times {\dot{m}}_{out} \\ \phi =\frac{\dot{m}v}{{\dot{m}}_a} \end{gathered}$$	$$\begin{gathered} {\dot{m}}_{in}=124.73 \mathrm{kg}/\mathrm{s} \\ {\phi }_{in}=0.862 \end{gathered}$$	$$\begin{gathered} {\dot{m}}_{out} \\ {\omega }_{out} \end{gathered}$$
Sulfur Remover	$$\begin{gathered} {\displaystyle {\displaystyle \sum }_{in}}{\phi }_{in}\times {\dot{m}}_{in}={\displaystyle {\displaystyle \sum }_{out}}{\phi }_{out}\times {\dot{m}}_{out} \\ \lambda =\frac{{\dot{m}}_{H_{2}S}}{{\dot{m}}_{syngas}} \end{gathered}$$	$$\begin{gathered} {\dot{m}}_{in}=67.15 \mathrm{kg}/\mathrm{s} \\ {\lambda }_{in}=0.0025 \end{gathered}$$	$$\begin{gathered} {\dot{m}}_{out} \\ {\lambda }_{out} \end{gathered}$$
CO2 Capture	$$\begin{gathered} {\dot{m}}_{CO2.in}=\frac{x_{CO2}{M}_{CO2}}{x_{CO2}{M}_{CO2}+x_{O2}{M}_{O2}+x_{H2O}{M}_{H2O}+x_{N2}{M}_{N2}}\times m_{fg} \\ {\dot{m}}_{CO2.out}={\eta }_{CO2Capture}{\dot{m}}_{CO2.in} \\ {Q}_{in,CO2Capture}=4.02\times \left({\eta }_{CO2Capture}\times 100-0.00179\right) \\ E{L}_{CO2Capture}=46.99+0.492\times {\eta }_{CO2Capture}\times 100 \\ {W}_{CO2Capture}=0.44\times \left({\eta }_{CO2Capture}\times 100-0.000179\right) \end{gathered}$$	$$\begin{gathered} T_{36}=T_4=T_{37} \\ {P}_{36}=P_4 \\ {T}_4, P_4 \\ {\eta }_{CO2Capture} \end{gathered}$$	$$\begin{gathered} {\dot{m}}_{CO2.in} \\ {\dot{m}}_{CO2.out} \\ {Q}_{in,CO2Capture} \\ E{L}_{CO2Capture} \\ {W}_{CO2Capture} \end{gathered}$$
Solar Field	$$\begin{gathered} P_{12}=P_9\left(1-d{p}_{SF}\right) \\ {Q}_{SF}=m_9\left(h_{12}-h_9\right) \\ {A}_{SF}=\frac{{\dot{Q}}_{SF}}{{\eta }_{SF}\times G} \end{gathered}$$	$$\begin{gathered} T_S=\left(T_9+T_{12}\right)/2 \\ d{p}_{SF} \\ {\eta }_{SF} \end{gathered}$$	$$\begin{gathered} Q_{SF} \\ {P}_{12} \\ {A}_{SF} \\ {T}_S \end{gathered}$$
Air Compressor	$$\begin{gathered} W_{AC}={\dot{m}}_{air}(h_{out}-h_{in}) \\ {P}_{out}=P_{in}\times r_{p,AC} \\ {h}_{in}=h_{air@T_{in}},h_{ou}=h_{air@T_{out}} \\ {T}_{out}=T_{in}\times \left(1+\frac{1}{{\eta }_{AC}}\left(r_{p,AC}{}^{\frac{{\gamma }_{air}-1}{{\gamma }_{air}}}-1\right)\right) \end{gathered}$$	$$\begin{gathered} T_{in}=25°\mathrm{C} ,P_{in}=1.013 \mathrm{bar} \\ {r}_{p,AC}=15.22 \\ {c}_{air}=1.005 \mathrm{kJ}/\mathrm{kg}·\mathrm{k} \\ {\gamma }_{air}=1.4 \\ {\eta }_{AC}=0.87 \end{gathered}$$	$$\begin{gathered} W_{AC} \\ {P}_2 \end{gathered}$$
Combustion Chamber	$$\begin{gathered} {\dot{m}}_{air}{h}_{air}+{\dot{m}}_{syngas}LH{V}_{syngas}{\eta }_{CC}-{\dot{m}}_{fg}{h}_{fg}=0 \\ {\dot{m}}_{air}+{\dot{m}}_{syngas}-{\dot{m}}_{fg}=0 \\ {P}_{out}=P_{in}(1-\Delta P_{CC}) \end{gathered}$$	$$\begin{gathered} LH{V}_{syngas}=8976.8 \mathrm{kJ}/\mathrm{kg} \\ {T}_{in}=396.9°\mathrm{C},P_{in}=15.426 \mathrm{bar} \\ \Delta P_{CC}=0.04 \\ {\dot{m}}_{air}=492 \mathrm{kg}/\mathrm{s} \\ {\eta }_{CC}=95\% \end{gathered}$$	$$\begin{gathered} T_{out},P_{out} \\ {\dot{m}}_{syngas},{\dot{m}}_{fg} \end{gathered}$$
Gas Turbine	$$\begin{gathered} W_{GT}={\dot{m}}_{fg}\left(h_{in}-h_{out}\right) \\ {T}_{out}=T_{in}\times \left(1-{\eta }_{GT}\left(1-r_{p,GT}{}^{\frac{1-{\gamma }_{air}}{{\gamma }_{air}}}\right)\right) \\ {P}_{out}=P_{in}+{{\displaystyle \sum }}^{ }\Delta P_{HRSG,fg} \\ {W}_{net,gc}=W_{GT}-W_{AC} \end{gathered}$$	$$\begin{gathered} T_3=1300°\mathrm{C},P_3=14.833 \mathrm{bar} \\ {\dot{m}}_{fg}=563.1 \mathrm{kg}/\mathrm{s} \\ {\eta }_{GT}=88\% \\ {r}_{p,GT}=14.52 \end{gathered}$$	$$\begin{gathered} W_{GT} \\ {T}_{20} \end{gathered}$$
Superheater 1	$$\begin{gathered} {\dot{m}}_{fg}\left(h_{35}-h_{23}\right)+{\dot{m}}_{hp}(h_{33}-h_{32})=0 \\ {P}_{23}=P_{35}-\Delta P_{HPSH,fg} \\ {P}_{33}=P_{32}-\Delta P_{HPSH,s} \\ {Q}_{HPSH}={\dot{m}}_{hp}(h_{33}-h_{32}) \\ {h}_{32}=h_{water@T_{32},P_{32}} \end{gathered}$$	$$\begin{gathered} \Delta P_{HPSH,fg}=2.491 \mathrm{millibar} \\ \Delta P_{HPSH,s}=2.41 \mathrm{millibar} \\ {T}_{HPSH}=535°\mathrm{C} \\ {T}_{32}=326.2°\mathrm{C} \\ {P}_{32}=122.4 \mathrm{bar} \end{gathered}$$	$$\begin{gathered} Q_{HPSH} \\ {T}_{23},P_{23} \\ {T}_{33},P_{33} \\ {\dot{m}}_{hp} \end{gathered}$$
Superheater 2	$$\begin{gathered} {\dot{m}}_{fg}\left(h_{15}-h_{13}\right)+{\dot{m}}_{hp}(h_{38}-h_{40})=0 \\ {P}_{38}=P_{40}-\Delta P_{HPSH,fg} \\ {P}_{13}=P_{15}-\Delta P_{HPSH,s} \\ {Q}_{HPSH}={\dot{m}}_{hp}(h_{38}-h_{40}) \end{gathered}$$	$$\begin{gathered} T_{15}=608°\mathrm{C},P_{15}=0.88 \mathrm{bar} \\ \Delta P_{HPSH,fg}=2.491 \mathrm{millibar} \\ \Delta P_{HPSH,s}=2.41 \mathrm{millibar} \\ {T}_{40}=351.28 °\mathrm{C} \\ {P}_{40}=39.78 \mathrm{bar} \end{gathered}$$	$$\begin{gathered} Q_{HPSH} \\ {T}_{13},P_{13} \\ {T}_{38},P_{38} \\ {\dot{m}}_{hp2} \end{gathered}$$
Evaporator	$$\begin{gathered} {\dot{m}}_{fg}\left(h_{23}-h_{30}\right)+{\dot{m}}_{hp}(h_{32}-h_{31})=0 \\ {P}_{30}=P_{23}-\Delta P_{HPEV,fg} \\ {P}_{32}=P_{31}-\Delta P_{HPEV,s} \\ {Q}_{HPEV}={\dot{m}}_{hp}(h_{32}-h_{31}) \end{gathered}$$	$$\begin{gathered} T_{20}=556.8°\mathrm{C},P_{20}=1.0205 \mathrm{bar} \\ \Delta P_{HPEC,fg}=2.4911 \mathrm{millibar} \\ \Delta P_{HPEC,s}=2.4481 \mathrm{milli} \\ {T}_{24}=260°\mathrm{C},P_{24}=122.4 \mathrm{bar} \\ \Delta P_{HPEV,fg}=4.9811 \mathrm{millibar} \end{gathered}$$	$$\begin{gathered} Q_{HPEV} \\ {T}_{23},P_{23} \end{gathered}$$
Economizer 1	$$\begin{gathered} {\dot{m}}_{fg}\left(h_{30}-h_{18}\right)+{\dot{m}}_{hp}(h_{31}-h_{41})=0 \\ {P}_{18}=P_{30}-\Delta P_{HPEC2,fg} \\ {P}_{41}=P_{31}-\Delta P_{HPEC2,s} \\ {T}_{26}=T_{sat@P_{26}} \\ {Q}_{HPEC2}={\dot{m}}_{hp}(h_{24}-h_{26}) \end{gathered}$$	$$\begin{gathered} T_{41}=340.5°\mathrm{C},P_6=1.0155 \mathrm{bar} \\ \Delta P_{HPEC,fg}=2.4911 \mathrm{millibar} \\ \Delta P_{HPEC,s}=2.4481 \mathrm{millibar} \\ {T}_{30}=366.8°\mathrm{C},P_{28}=0.88 \mathrm{bar} \end{gathered}$$	$$\begin{gathered} Q_{HPEC2} \\ {T}_{41},P_{41} \\ {T}_{18},P_{18} \end{gathered}$$
Economizer 2	$$\begin{gathered} {\dot{m}}_{fg}\left(h_{13}-h_{25}\right)+{\dot{m}}_{hp}(h_{11}-h_1)=0 \\ {T}_1=T_{sat@P_1} \\ {Q}_{HPEC2}={\dot{m}}_{hp}(h_{11}-h_1) \end{gathered}$$	$$\begin{gathered} P_{31}=122.4 \mathrm{bar} \\ {T}_{31}=310.4 °\mathrm{C} \\ \Delta P_{HPEC,fg}=2.4911 \mathrm{millibar} \\ \Delta P_{HPEC,s}=2.4481 \mathrm{millibar} \end{gathered}$$	$$\begin{gathered} Q_{HPEC2} \\ {T}_{11, }{P}_{11} \\ {T}_{25},P_{25} \end{gathered}$$
Steam Turbine 1	$$\begin{gathered} {\dot{m}}_{33}{h}_{33}-{\dot{m}}_{27}{h}_{27}-W_{ST1}=0 \\ {h}_{27}=h_{33}-{\eta }_{ST}(h_{33}-h_{27}) \\ {\dot{m}}_{33}-{\dot{m}}_{27}=0 \end{gathered}$$	${\eta }_{ST}=88\%$	$$\begin{gathered} W_{ST1} \\ {T}_{27},P_{27} \end{gathered}$$
Steam Turbine 2	$$\begin{gathered} {\dot{m}}_{38}{h}_{38}-{\dot{m}}_{21}{h}_{21}-W_{ST2}=0 \\ {h}_{21}=h_{38}-{\eta }_{ST}(h_{38}-h_{21s}) \\ {\dot{m}}_{38}-{\dot{m}}_{21}=0 \end{gathered}$$	${\eta }_{ST}=88\%$	$$\begin{gathered} W_{ST2} \\ {T}_{21},P_{21} \end{gathered}$$
Condenser	$$\begin{gathered} {\dot{m}}_{fw}\left(h_{21}-h_{22}\right)+{\dot{m}}_{cw}(h_{39}-h_{29})=0 \\ {Q}_{cond}={\dot{m}}_{fw}(h_{21}-h_{22}) \\ {T}_{39}=T_{29}+\Delta T_{CW} \\ {P}_{39}=P_{29}-\Delta P_{cond} \end{gathered}$$	$$\begin{gathered} T_{21}=38.74°\mathrm{C}, P_{21}=0.07 \mathrm{bar} \\ {T}_{29}=25°\mathrm{C},P_{29}=1.023 \mathrm{bar} \\ \Delta T_{CW}=15.5°\mathrm{C} \end{gathered}$$	$$\begin{gathered} Q_{cond} \\ {\dot{m}}_{cw} \\ {T}_{21},P_{21} \\ {T}_{39},P_{39} \end{gathered}$$
Expander	$W_{EX}=m\times c_p\times \left(T_{28}-T_{16}\right)$	$$\begin{gathered} m=28.29 \mathrm{kg}/\mathrm{s} \\ {T}_{28}=519.05°\mathrm{C} \\ {C}_P=1.62 \mathrm{kJ}/\mathrm{kg}·\mathrm{K} \end{gathered}$$	$$\begin{gathered} W_{EX} \\ {T}_{16} \end{gathered}$$

provides the operating conditions assumed for the different ISGC system units.

In the proposed ISGC system, the air first goes to the air separation unit (ASU), where the pure oxygen product stream (5) enters the gasifier. The superheated water vapor by the solar field is mixed with the heavy refinery fuel stream before entering the gasifier. In the syngas cooler, the heat from the syngas stream is utilized to saturate the water in the steam turbine. It should be observed that the fuel and syngas streams are represented by black lines in the schematic diagram in Figure 1, whilst the water and steam streams are depicted in blue, the flue products in red, and the air stream by red lines. The syngas enters the heat exchanger as stream (6), which is responsible for increasing the temperature of the humidified syngas. In the next section, the syngas goes to the H₂S remover unit in stream (10). Then, the syngas stream enters this unit as stream (4) to capture CO₂. After entering the humidification section, the temperature of the syngas in the mentioned heat exchanger increases. Thereafter, the syngas pressure needs to be synchronized with the compressor outlet pressure. Hence, the syngas pressure is reduced by half of its initial value via an expander and produced energy. Herein, the syngas entered the combustion chamber (CC) as stream number (16). Finally, the combustion gases are sent to the gas turbine (GT) to provide electrical power.

In the HRSG unit, water enters the first cycle economizer as stream (42), and, after being saturated in the evaporator as stream (32), it goes to the first superheater to exchange heat with the flue gases to become superheated. Afterwards, this superheated steam enters the first turbine as stream (33). An additional water stream (1) entered the second economizer, before entering the syngas cooler as stream (11) to change phase from saturated liquid to saturated steam. It is then mixed with stream (27) and enters the second superheater. Here, superheated steam is sent to the second steam turbine (ST) with the stream (38). After power generation, this stream goes to the condenser, and, after condensation, it finally leaves it as a saturated liquid stream (22).

3. Methodology

The integrated solar-gasification cycle (ISGC) system was modelled in MATLAB software, and the thermodynamic results were validated via simulations using the Thermoflex software environment. Accordingly, the thermodynamic system modelling was performed in Thermoflex to obtain the streams pressure, temperature, and enthalpy. The developed code was based on the thermodynamic relations, input parameters (process operating conditions), and calculation of the unknown parameters, as indicated in Table A1 of Appendix A. Figure A1 shows the schematic of the computational procedure for the 4E analyses. The following sections outline the thermodynamic, economic, and environmental formulation used to assess the proposed ISGC system.

3.1. Thermodynamic Analysis

Assuming a steady-state condition, the first law of thermodynamics was applied to all system components. Thus, the following mass balance was required for each equipment k in the system.

$${{\displaystyle \sum }}^{ }{\dot{m}}_{in,k}={{\displaystyle \sum }}^{ }{\dot{m}}_{out,k}$$

(1)

Equation (2) states the energy balance used for modelling each equipment k in the system:

$${\dot{Q}}_k-{\dot{W}}_k={{\displaystyle \sum }}^{ }{\dot{m}}_{out,k}{h}_{out,k}-{{\displaystyle \sum }}^{ }{\dot{m}}_{in,k}{h}_{in,k}$$

(2)

where $\dot{m}$, $\dot{Q}$, $\dot{W}$, and $h$ denote the mass flow rate, heat transfer rate, power, and specific enthalpy, respectively.

For performing the thermodynamic analysis, the following assumptions were considered:

(1)

Pressure drops were disregarded in heat exchangers and pipe network.

(2)

Heat losses were neglected in the equipment.

(3)

Turbines and pumps had isentropic efficiencies.

(4)

Kinetic and potential energy and exergy changes were disregarded.

Additionally, the following assumptions were needed to model the gasifier [29]:

(1)

Heat dissipation was neglected.

(2)

The reactor was fed with heavy refinery fuel.

(3)

The reactor type was an oxygen blower.

(4)

The reactor included a syngas cooling heat exchanger.

(5)

The air separation system was based on a membrane separation process.

3.2. Conventional Exergy Analysis

The aim of the conventional exergy analysis is to determine the exergy destruction and exergy efficiency of each component to better understand the irreversibilities of the system. In this study, exergy was divided into physical and chemical exergy, as given by Equation (3) and Equation (4), respectively:

$$e^{PH}=h-h_0-T_0\left(S-S_0\right)$$

(3)

$$e^{CH}={{\displaystyle \sum }}^{ }{x}_i{e}_i^0+R{T}_0{{\displaystyle \sum }}^{ }{x}_{i}ln{x}_i{\gamma }_i$$

(4)

Herein, $h$ is enthalpy, $T$ is temperature, and $S$ denotes entropy. Additionally, $x_i$ is the mole fraction, ${\gamma }_i$ is component i activity coefficients, and $e_i^0$ is the standard chemical exergy, addressed in Ref. [30]. The exergy rate of the i-th stream is obtained by the multiplication of the specific exergy rate by the corresponding mass flow rate:

$${\dot{E}}_i={\dot{m}}_i\times e_i$$

(5)

Exergy destruction is one of the critical parameters of the exergy analysis since it determined the system irreversibility rate. Ideal reversible systems present equal total inlet and outlet exergy flows. However, real systems are characterized by several sources of irreversibilities, including friction losses, transient heating, and chemical reactions, among others. As a result, the total exergy of output flows was lower than the one of the input flows to the system, which is expressed as the system exergy destruction. The Specific Exergy Costing (SPECO) [31] methodology was employed to measure the components’ exergy destruction rate (${\dot{E}}_{D,k}$), as expressed by Equation (6). The method allowed stratifying exergy rates into fuel (${\dot{E}}_{F,k}$) and product (${\dot{E}}_{P,k}$) for each component (as given in

Table A2. Exergy destruction and exergy efficiency formulation [17].

Component	Exergy Destruction	Exergy Efficiency
Air separation unit	$Ex14-Ex5+W_{ASU}$	$\frac{Ex5-Ex14}{W_{ASU}}$
Solar field	$Ex9-Ex12+E{x}_{SF}$	$\frac{Ex12-Ex9}{E{x}_{SF}}$
Gasifier	$Ex5+Ex12+Ex8-E{x}_{gasi}$	$\frac{E{x}_{gasi}}{Ex5+Ex12+Ex8}$
Syngas cooler	$E{x}_{gasi}+Ex11-Ex6-Ex34$	$\frac{Ex34-Ex11}{E{x}_{gasi}-Ex6}$
Heat exchanger	$Ex6+Ex19-Ex10-Ex28$	$\frac{Ex28-Ex19}{Ex6-Ex10}$
H2S remover	$Ex10-Ex17-Ex4$	$\frac{Ex17}{Ex10-Ex4}$
CO2 capture	$Ex4-Ex37-Ex36$	$\frac{Ex37}{Ex4-Ex36}$
Humidifier	$Ex36+Ex7-Ex19-E{x}_{Humidifier}$	$\frac{E{x}_{scr\_out}+Ex19}{Ex7+Ex36}$
Expander	$Ex28-Ex16-W_{exp}$	$\frac{W_{Exp}}{Ex28-Ex16}$
Combustion chamber	$Exacout-Exccout+Ex16$	$\frac{Exccout}{Exacout+Ex16}$
Air compressor	$Ex14-Exacout+W_{AC}$	$\frac{Exacout-Ex14}{W_{AC}}$
Gas turbine	$Exccout-Ex20-W_{GT}$	$\frac{W_{GT}}{Exccout-Ex20}$
Superheater	$Ex35+Ex32-Ex23-Ex33$	$\frac{Ex33-Ex32}{Ex35-Ex23}$
Evaporator	$Ex23+Ex31-Ex30-Ex32$	$\frac{Ex32-Ex31}{Ex23-Ex30}$
HRSG	$Ex42+Ex30-Ex18-Ex31$	$\frac{Ex31-Ex42}{Ex30-Ex18}$
Steam turbine	$Ex33-Ex27-W_{ST}$	$\frac{W_{ST}}{Ex33-Ex27}$
Condenser	$Ex29+Ex21-Ex39-Ex22$	$\frac{Ex39-Ex29}{Ex21-Ex22}$

HRSG: Heat recovery steam generator.

). It should be noted that, unlike other methodologies, the SPECO approach accounts for fuel and product definitions and auxiliary cost equations at the component level, even in the most complex cases involving several exergy components. As a result, these definitions are independent of the entire system setup.

$${\dot{E}}_{D,k}={\dot{E}}_{F,k}-{\dot{E}}_{P,k}$$

(6)

The exergy efficiency is defined by:

$${\epsilon }_k=\frac{\dot{E}{x}_{P,k}}{\dot{E}{x}_{F,k}}$$

(7)

It is noteworthy that the chemical exergy of the fuel contributes to a larger share of the system input exergy:

$$e{x}^{CH}=\beta \times LH{V}_{fuel}$$

(8)

where $\beta$ is the ratio of the exergy of the fuel over its low heating value (LHV), calculated by:

$$\beta =\frac{1.044+0.16\frac{H}{C}-0.34493\frac{O}{C}\left(1+0.0531\frac{H}{C}\right)}{1-0.4142\frac{O}{C}}$$

(9)

where $H/C$ and $O/C$ are the atomic ratios of the fuel. The formulation used for obtaining the exergy destruction and efficiency of system components is listed in Table A2 of Appendix A.

3.3. Conventional Exergoeconomic Analysis

By combining the exergy analysis with economic principles, such as investment, maintenance, and repair costs, the final cost of the exergy destruction can be evaluated for each system component. In this study, the flow costs based on exergoeconomic analysis included the investment cost rate, exergy destruction cost rate of each equipment, and the cost of fuel used in the system. The sum of these input costs represents the total cost of the entire system. Hence, the component cost rate is calculated by Equation (10).

$${\dot{Z}}_k=\frac{{\Phi }_k\times PE{C}_k\times CRF}{3600\times N}$$

(10)

where ${\Phi }_k$ is the maintenance factor (taken as 1.06), N is the annual operating hours (8000 h) [32,33], and CRF is the capital recovery factor given by Equation (11) [33].

$$CRF=\frac{i\times {(1+i)}^n}{{(1+i)}^n-1}$$

(11)

where i is the fractional interest rate per year and n is the plant lifetime (25 years) [32,33]. In addition, $PE{C}_k$ is the purchase equipment cost for each system component, as defined in

Table A3. Purchase equipment cost for the different ISGC system components [17].

Component	Purchase Equipment Cost Relations
ASU	$$\begin{gathered} PE{C}_{ASU}=\left(Ref Cost\right)\times {(\frac{Size}{Ref Size})}^{Scalling Exponent}\times \left(Overal Installation Factor\right) \\ Scalling Exponent=0.5,Overal Installation Factor=1 \\ Ref Cost=141Million US\$Ref Size=52\mathrm{kg} O_2/\mathrm{s} \end{gathered}$$
Solar field	$PE{C}_{Solarfield}=355 \$/{\mathrm{m}}^2$
Gasifier	$$\begin{gathered} PE{C}_{GASI}=\left(Ref Cost\right) \times {\left(\frac{Size}{Ref Size}\right)}^{Scalling Exponent}\times \left(Overal Installation Factor\right) \\ Scalling Exponent=0.7,Overal Installation Factor=1 \\ Ref Cost=395Million US\$,Ref Size=68.5\mathrm{kg} \mathrm{feed}/\mathrm{s} \end{gathered}$$
Syngas cooler	$PE{C}_{Syn\_cooler}=\mathrm{12,000}{(\frac{A}{100})}^{0.6}$
Heat exchanger	$PE{C}_{HX}=\mathrm{12,000}{(\frac{A}{100})}^{0.6}$
H2S/CO2 remover	$$\begin{gathered} PE{C}_{\mathrm{Cleaner}}=\left(Ref Cost\right) \times {\left(\frac{Size}{Ref Size}\right)}^{Scalling Exponent}\times \left(Overal Installation Factor\right)Scalling Exponent=0.63,Overal Installation Factor=1.55 \\ Ref Cost=28.8Million US\$,Ref Size=2.48kmole \mathrm{feed}/\mathrm{s} \end{gathered}$$
Expansion turbine	$PE{C}_{Expander}=W_{Turb}\left(1318.5-98.328 ln\left(W_{Turb}\right)\right)$
Combustion chamber	$PE{C}_{CC}=\frac{{28.98\mathrm{m}}_a}{0.995-\frac{p_{out}}{p_{in}}}.\left({1+\mathrm{e}}^{\left(0.015\left(T_{out}-1540\right)\right)}\right)$
Air compressor	$PE{C}_{Compressor}=44.71m_a.r_{p,AC}.\ln (r_{p,AC}).\frac{1}{0.95-{\eta }_{AC}}$
Gas turbine	$PE{C}_{GT}=479.34\frac{m_{fg}}{0.93-{\eta }_{GT}}.\ln \left(r_{p,GT}\right).\left({1+\mathrm{e}}^{\left({0.036\ast \mathrm{T}}_{in}-54.4\right)}\right)$
HRSG	$PE{C}_{HRSG}=6570[{(\frac{Q_{EC}}{\Delta T_{EC}})}^{0.8}+{(\frac{Q_{EV}}{\Delta T_{EV}})}^{0.8}+\left(\frac{Q_{SH}}{\Delta T_{SH}}{)}^{0.8}\right]+\mathrm{21,276}{m}_w+1184.4m_{fg}^{1.2}$
Steam turbine	$PE{C}_{ST}=2210.{\dot{W}}^{0.7}$
Condenser	$PE{C}_{Cond}=1773.\dot{m}$

HRSG: Heat recovery steam generator.

(see Appendix A).

After computing each component cost rate, the exergoeconomic balance was considered by solving the matrix balance equation for each component:

$${\dot{C}}_{P,k}={\dot{C}}_{F,k}-{\dot{C}}_{L,k}+{\dot{Z}}_k$$

(12)

$${\displaystyle \sum }_e{\dot{C}}_{e,k}+{\dot{C}}_{w,k}={\displaystyle \sum }_i{\dot{C}}_{i,k}+{\dot{C}}_{q,k}{\dot{+Z}}_k$$

(13)

The cost of each stream was obtained by multiplying the specific cost by its exergy rate, as shown in Equation (14).

$${\dot{C}}_i=c_i·{\dot{E}}_i$$

(14)

where ${\dot{C}}_{F,k}$ and ${\dot{C}}_{P,k}$ are the fuel stream and product stream cost rates, respectively. Additionally, the component exergy destruction cost rate was determined by Equation (15):

$${\dot{C}}_{D,k}=c_{F,k}.{\dot{E}}_{D,k}$$

(15)

Finally, the exergoeconomic factor is expressed as [33,34]:

$$f_k=\frac{{\dot{Z}}_k}{{\dot{Z}}_k+c_{f,k}{\dot{E}}_{D,k}}$$

(16)

The exergoeconomic balance equations of the different ISGC system components are presented in

Table A4. Exergoeconomic formulation for the different ISGC system components [17].

Component	Exergoeconomic Balance
Air separation unit	${\dot{Z}}_{ASU}=C5\times Ex5-C_{GT}\times W_{ASU}$
Solar field	${\dot{Z}}_{QSF}=C12\times Ex12$
Gasifier	${\dot{Z}}_{GASI}+C8\times Ex8=C_{GASI}\times E{x}_{GASI}-C5\times Ex5-C12\times Ex12$
Syngas cooler	${\dot{Z}}_{syn-cooler}+C_{GASI}\left(E{x}_{GASI}-Ex6\right)=C34\times Ex34$
Heat exchanger	${\dot{Z}}_{HX}=C_{GASI}\left(Ex10-Ex4\right)-C19\times Ex19+C28\times Ex28$
H2S remover	${\dot{Z}}_{H_{2}S\_\mathrm{Re}mover}=C_{GASI}\left(Ex17-Ex10\right)+C4\times Ex4$
CO2 capture	${\dot{Z}}_{C{O}_2\_Capture}=C4\left(Ex37-Ex4\right)+C36\times Ex36$
Humidifier	${\dot{Z}}_{SCR}=C19\times Ex19-C36\times Ex36$
Expander	${\dot{Z}}_{EXP}=C28\left(Ex16-Ex28\right)+C_{EXP}\times W_{EXP}$
Combustion chamber	${\dot{Z}}_{CC}=C_{ccout}\times E{x}_{ccout}-C28\times Ex16-C_{acout}\times E{x}_{acout}$
Air compressor	${\dot{Z}}_{AC}=C_{acout}\times E{x}_{acout}-C_{GT}\times W_{AC}$
Gas turbine	${\dot{Z}}_{GT}=C_{ccout}\left(Ex20-E{x}_{ccout}\right)+C_{GT}\times W_{GT}$
Superheater	${\dot{Z}}_{SH}+C20\left(Ex35-Ex23\right)=C33\times Ex33-C32\times Ex32$
Evaporator	${\dot{Z}}_{EV}+C20\left(Ex23-Ex30\right)=C32\times Ex32-C31\times Ex31$
HRSG	${\dot{Z}}_{Eco}+C20\times Ex30=C31\times Ex31$
Steam turbine	${\dot{Z}}_{ST}=C33\left(Ex27-Ex31\right)+C_{ST}\times W_{ST}$
Condenser	${\dot{Z}}_{Cond}=C38\left(Ex22-Ex21\right)+C39\times Ex39$

HRSG: Heat recovery steam generator.

of Appendix A.

3.4. Conventional Exergoenvironmental Analysis

The life cycle assessment (LCA) is an environmental analysis methodology broadly used for products, processes, and services. The LCA can be carried out after technical and economic analyses. In this study, LCA was implemented within the exergoenvironmental analysis. In this way, the exergoenvironmental analysis was performed via three phases: (1) exergy analysis of each process stream; (2) estimation of environmental impacts related to the manufacturing process of each system component; and, finally, (3) the exergoenvironmental formulation was used to estimate the environmental impacts of streams based on the exergy analysis. The exergoenvironmental analysis was carried out via the following equations.

The relationship between exergy and environmental impact for each stream i is provided by Equation (17).

$${\dot{B}}_i=b_i {\dot{E}}_i$$

(17)

where ${\dot{B}}_i$ is the environmental impact rate (given in pts/s), $b_i$ is the exergoenvironmental impact (pts/kJ), and ${\dot{E}}_i$ the stream exergy rate (kW). Similarly to the exergoeconomic analysis, the following balance is required for the exergoenvironmental analysis:

$${{\displaystyle \sum }}^{ }{\dot{B}}_{in,k}-{{\displaystyle \sum }}^{ }{\dot{B}}_{out,k}+{\dot{Y}}_k=0$$

(18)

where ${\dot{Y}}_k$ is the k-th component environmental impact rate, defined through ECO-Indicator 99 [35]. This parameter is obtained by Equation (19) [36].

$${\dot{Y}}_k=b{m}_k·w_k$$

(19)

where $b{m}_k$ and $w_k$ are the per weight environmental impact (mpts/kg) and the kth component weight (tons), respectively. The latter is given in

Table A5. Weight of different system components [36,41].

Component	Weight (tons)
Air separation unit	$W_{ASU}=0.0061\times {\dot{W}}_{{\mathit{ASU}}_{\mathit{Total}}}^{0.95} ;\dot{\mathrm{W}} \mathrm{in} \mathrm{kw}$
Solar field	$W_{coll}=0.0626. L\left(length\right) ;\mathrm{L} \mathrm{in} \mathrm{m}$
Gasifier	$$\begin{gathered} W_{Gasifier}=\frac{100\times P_e\times d_{Gasifier}\times F{S}_{Gasifier}}{2\times {\sigma }_{Gasifier}} \\ {\mathrm{FS}}_{Gasifier}=2: \mathrm{safety} \mathrm{factor}\mathrm{of} Gasifier \\ {\sigma }_{Gasifier}=45: \mathrm{rupturing} \mathrm{stress} \mathrm{of} Gasifier\mathrm{in} \mathrm{MPa} \\ {d}_{\mathit{Gasifier}}:\mathrm{diameter} \mathrm{considering}\dot{\mathrm{m}} \mathrm{and} \mathrm{velocity}=6.2 \mathrm{m}/\mathrm{s} \end{gathered}$$
Syngas cooler	$W_{\mathrm{syn}\_\mathrm{cooler}}=13.91\ast {(Q_{\mathrm{syn}\_\mathrm{cooler}}/1000)}^{0.68};$
Heat exchanger	$W_{HX}=2.989\times {\dot{Q}}_{HX}^{0.97};\dot{\mathrm{Q}}\mathrm{in}\mathrm{MW}$
H2S/CO2 remover	$W_{\mathrm{remover}}=2.49\times m_{syn}{}^{0.7}$
Expander	$$\begin{gathered} W_{EXP}=\frac{100\times P_e\times d_{EXP}\times F{S}_{EXP}}{2\times {\sigma }_{EXP}} \\ {\mathrm{FS}}_{EXP}=2: \mathrm{safety} \mathrm{factor} \mathrm{of} EXP \\ {\sigma }_{EXP}=6: \mathrm{rupturing} \mathrm{stress} \mathrm{of} EXP \mathrm{in} \mathrm{MPa} \\ {d}_{\mathit{EXP}}:\mathrm{diameter} \mathrm{considering}\dot{\mathrm{m}} \mathrm{and} \mathrm{velocity}=13 \mathrm{m}/\mathrm{s} \end{gathered}$$
Combustion chamber	$$\begin{gathered} W_{CC}=\frac{100\times P_e\times d_{CC}\times F{S}_{CC}}{2\times {\sigma }_{CC}} \\ {\mathrm{FS}}_{CC}=2: \mathrm{safety} \mathrm{factor} \mathrm{of} \mathrm{CC} \\ {\sigma }_{CC}=45: \mathrm{rupturing} \mathrm{stress} \mathrm{of} \mathrm{CC} \mathrm{in} \mathrm{MPa} \\ {d}_{\mathit{CC}}:\mathrm{diameter} \mathrm{considering}\dot{\mathrm{m}} \mathrm{and} \mathrm{velocity}=6.2 \mathrm{m}/\mathrm{s} \end{gathered}$$
Air compressor	$$\begin{gathered} W_{AC}=\frac{100\times P_e\times d_{AC}\times F{S}_{AC}}{2\times {\sigma }_{AC}} \\ {\mathrm{FS}}_{AC}=2: \mathrm{safety} \mathrm{factor} \mathrm{of} \mathrm{AC} \\ {\sigma }_{AC}=16: \mathrm{rupturing} \mathrm{stress} \mathrm{of} \mathrm{AC} \mathrm{in} \mathrm{MPa} \\ {d}_{\mathit{AC}}:\mathrm{diameter} \mathrm{considering}\dot{\mathrm{m}} \mathrm{and} \mathrm{velocity}=15 \mathrm{m}/\mathrm{s} \end{gathered}$$
Gas turbine	$$\begin{gathered} W_{GT}=\frac{100\times P_e\times d_{GT}\times F{S}_{GT}}{2\times {\sigma }_{GT}} \\ {\mathrm{FS}}_{GT}=2: \mathrm{safety} \mathrm{factor} \mathrm{of} \mathrm{GT} \\ {\sigma }_{GT}=6: \mathrm{rupturing} \mathrm{stress} \mathrm{of} \mathrm{GT} \mathrm{in} \mathrm{MPa} \\ {d}_{\mathit{GT}}:\mathrm{diameter} \mathrm{considering}\dot{\mathrm{m}} \mathrm{and} \mathrm{velocity}=13 \mathrm{m}/\mathrm{s} \end{gathered}$$
Superheater	$W_{SH}=8.424\times {\dot{Q}}_{SH}^{0.87};\dot{\mathrm{Q}}\mathrm{in}\mathrm{MW}$
Evaporator	$W_{EV}=13.91\times {\dot{Q}}_{EV}^{0.68};\dot{\mathrm{Q}}\mathrm{in}\mathrm{MW}$
HRSG	$W_{EC}=2.989\times {\dot{Q}}_{EC}^{0.97};\dot{\mathrm{Q}}\mathrm{in}\mathrm{MW}$
Steam turbine	$W_{ST}=4.9\times {\dot{W}}_{ST}^{0.73}$
Condenser	$W_{\mathit{cond}}=0.073\times {\dot{Q}}^{0.99};\dot{\mathrm{Q}}\mathrm{in}\mathrm{MW}$

HRSG: Heat recovery steam generator.

of Appendix A for the different system components.

The environmental impact associated with the exergy destruction of the k-th component is written as:

$${\dot{B}}_{D,k}={\dot{E}}_{D,k}{b}_{F,k}$$

(20)

The cumulative environmental impact rate (${\dot{B}}_{T,k}$) for the k-th component is denoted as [37]:

$${\dot{B}}_{T,k}={\dot{B}}_{D,k}+{\dot{Y}}_k$$

(21)

The corresponding balance equations for the environmental impact rate of system components are listed in

Table A6. Environmental impact rate formulation for the different ISGC system components [17].

Component	Environmental Impact Rate Balances
Air separation unit	$W_{ASU}=b5\times Ex5-b_{GT}\times {\dot{W}}_{ASU}$
Solar field	$W_{SolarField}=b12\times Ex12$
Gasifier	$W_{GASI}+b8\times Ex8=b_{GASI}\times E{x}_{GASI}-b5\times Ex5-b12\times Ex12$
Syngas cooler	$W_{syn-cooler}+b_{GASI}\left(E{x}_{GASI}-Ex6\right)=b34\times Ex34$
Heat exchanger	$W_{HX}=b_{GASI}\left(Ex10-Ex4\right)-b19\times Ex19+b28\times Ex28$
H2S remover	$W_{H_{2}S\_\mathrm{Re}mover}=b_{GASI}\left(Ex17-Ex10\right)+b4\times Ex4$
CO2 capture	$W_{C{O}_2\_Capture}=b4\left(Ex37-Ex4\right)+b36\times Ex36$
Humidifier	$W_{SCR}=b19\times Ex19-b36\times Ex36$
Expander	$W_{EXP}=b28\left(Ex16-Ex28\right)+b_{EXP}\times {\dot{W}}_{EXP}$
Combustion chamber	$W_{CC}=b_{ccout}\times E{x}_{ccout}-b28\times Ex16-b_{acout}\times E{x}_{acout}$
Air compressor	$W_{AC}=b_{acout}\times E{x}_{acout}-b_{GT}\times {\dot{W}}_{AC}$
Gas turbine	$W_{GT}=b_{ccout}\left(Ex20-E{x}_{ccout}\right)+b_{GT}\times {\dot{W}}_{GT}$
Superheater	$W_{SH}+b20\left(Ex35-Ex23\right)=b33\times Ex33-b32\times Ex32$
Evaporator	$W_{EV}+b20\left(Ex23-Ex30\right)=b32\times Ex32-b31\times Ex31$
HRSG	$W_{Eco}+b20\times Ex30=b31\times Ex31$
Steam turbine	$W_{ST}=b33\left(Ex27-Ex31\right)+b_{ST}\times {\dot{W}}_{ST}$
Condenser	$W_{Cond}=b38\left(Ex22-Ex21\right)+b39\times Ex39$

HRSG: Heat recovery steam generator.

(see Appendix A).

The exergoenvironmental factor shown in Equation (22) is an important criterion that expresses the ratio of the equipment component-related environmental impact to the sum of the component-related and operational-related environmental impact. An exergoenvironmental factor value around 1 indicates that the component environmental effects are greater than the operational-related environmental impact.

$$f_{b,k}=\frac{{\dot{Y}}_k}{{\dot{Y}}_k+b_{f,k}\dot{E}{x}_{D,k}}$$

(22)

3.5. Advanced Exergy Analysis

Advanced exergy analysis can be used to evaluate the exergy destruction sources, thereby leading to potential improvements in the system. In advanced exergy analysis, the equipment irreversibilities are evaluated within two different viewpoints: (1) source of irreversibility and (2) ability to eliminate such irreversibility. From the source perspective, equipment unit irreversibilities are divided into endogenous and exogenous. From the ability to eliminate standpoint, the irreversibility of each system component is categorized as avoidable and unavoidable [38,39]. The former stratification is grounded on theoretical methods, while the latter is calculated grounded on the maximum energy-efficient system commercially available.

3.5.1. Avoidable and Unavoidable Exergy Destruction

Unavoidable exergy destruction in system components relates to the limitations imposed by the thermodynamic and physical conditions and technological and economic constraints. In most cases, unavoidable exergy destruction is determined by the authors’ knowledge and experience on potentially unavoidable system irreversibilities. The avoidable exergy destruction can be obtained from the unavoidable one by the following equation.

$${\dot{E}}_{D,k}={\dot{E}}^{UN}{}_{D,k}+{\dot{E}}^{AV}{}_{D,k}$$

(23)

3.5.2. Endogenous and Exogenous Exergy Destruction

Endogenous exergy destruction of system components is associated to the irreversibility of each unit itself. The exogenous exergy destruction is given by the difference between the exergy destruction of the system operating at actual conditions and the endogenous exergy destruction as expressed as follows.

$${\dot{E}}_{D,k}={\dot{E}}^{EN}{}_{D,k}+{\dot{E}}^{EX}{}_{D,k}$$

(24)

The engineering approach proposed by Kelly et al. [40] was used in this study, which can be implemented for the equipment that performs chemical reactions, including combustion chambers and gasifiers. Thus, Equation (25) is implemented to obtain endogenous and exogenous exergy destruction.

$${\dot{E}}_{D,tot}={\dot{E}}_{D,k}^{EN}+{\dot{E}}_{D,k}^{EX}+{\dot{E}}_{D,others}$$

(25)

where ${\dot{E}}_{D,others}$ is the summation of the exergy destruction in the system components other than the k-th component under analysis.

4. Results and Discussion

The results obtained from the conventional and advanced thermodynamics, exergy, exergoeconomic, and exergoenvironmental analyses are presented in the following sections.

4.1. Validation of Thermodynamic Modelling Results

This section compares the modelling results for mass flow rate, temperature, and pressure of process streams obtained from MATLAB to those from the simulations performed in Thermoflex software, which are based on real plant data information. The results comparison is shown in

Table 2. Stream data obtained from simulations in MATLAB and Thermoflex software.

	$\dot{\mathit{m} }\left[\mathbf{k}\mathbf{g}/\mathbf{s}\right]$			$\mathit{T} [°\mathbf{C}]$			$\mathit{P} \left[\mathbf{bar}\right]$
Stream	MATLAB	Thermoflex	Error [%]	MATLAB	Thermoflex	Error [%]	MATLAB	Thermoflex	Error [%]
1	9.35	9.351	0	25	25	0	40.58	40.58	0
2	0.14	0.14	0	100	100	0	1.013	1.0135	0
3	182.1	182	0.05	35	35	0	0.92	0.9214	0
4	28.11	28.11	0.01	400	400	0	35.61	35.61	0
5	8.01	8.01	0	142.5	142.5	0	39	39	0
6	28.53	28.53	0	718.94	700	2.63	37.05	37.05	0
7	17.4	17.4	0	100	100	0	40	40	0
8	15.5	15.5	0	25	25	0	37.92	37.92	0
9	5.16	5.16	0	25	25	0	1.014	1.014	0
10	28.53	28.53	0	400	400	0	36.32	36.32	0
11	9.35	9.35	0	250	250	0	39.78	39.78	0
12	5.16	5.16	0	150	150	0	0.921	0.9218	0.01
13	110.29	110.3	0.01	353.9	353.55	0.1	0.88	0.88	0
14	523.2	523.2	0	25	25	0	0.87	0.87	0
15	110.3	110.3	0	608.9	608.9	0	0.88	0.88	0
16	28.3	28.29	0.03	473.95	474.1	0.01	24.11	24.12	0.04
17	0.416	0.413	0.72	400	400	0	1.013	1.013	0
18	441.19	444.2	0.002	171.42	169.6	1.06	0.87	0.87	0
19	28.3	28.29	0.03	206.73	205.2	0.74	35.43	35.43	0
20	551.48	551.5	0.01	608.9	608.9	0	0.88	0.88	0.01
21	74.351	74.35	0.01	38.74	38.74	0	0.068	0.068	0
22	74.351	74.35	0.01	38.7	38.74	0.1	0.068	0.068	0
23	441.19	441.2	0.01	512.47	512.9	0.08	0.88	0.88	0.01
24	182	182	0	25	25	0	1.013	1.013	0
25	110.29	110.3	0.01	278.16	278.2	0.01	0. 87	0.87	0
26	33.36	33.36	0	25	25	0	0.87	0.87	0
27	65	65	0	368.6	368.6	0	39.78	39.78	0
28	28.29	28.29	0.02	519.05	522	0.18	34.73	34.74	0.03
29	3238.5	3238.5	0	25	25	0	1.013	1.013	0
30	441.19	441.2	0.01	346.08	344.6	0.42	0.88	0.88	0
31	65	65	0	310	310	0	122.4	122.4	0.01
32	65	65	0	326.19	326.2	0.01	122.4	122.4	0.01
33	65	65	0	535	535	0	119.95	120	0.04
34	9.351	9.351	0	250.03	250	0.01	39.78	39.78	0.01
35	441.19	441.2	0.01	608.9	608.9	0	0.88	0.88	0.01
36	27.24	27.25	0.03	400	400	0	35.43	35.43	0
37	0.865	0.867	0.23	400	395.1	1.22	0.87	0.87	0
38	74.35	74.35	0.01	536.8	536.8	0	38.98	39	0.05
39	3238.5	3238.5	0	37.08	37.08	0	0.66	0.66	0.7
40	74.35	74.35	0.01	351.28	351.2	0.02	39.78	39.78	0
42	65	65	0	25	25	0	124.85	124.85	0

. For all streams, the simulated results showed an error lower than 1%, presenting an appropriate agreement with each other.

Table 3. Power and heat transfer rates for different components obtained from simulations in MATLAB and Thermoflex software.

Parameter	MATLAB	Thermoflex	Error [%]
$W_{GT Pack} \left[\mathrm{MW}\right]$	229.55	229.55	0.00
$W_{AC} \left[\mathrm{MW}\right]$	219.66	213.55	2.78
$W_{GT} \left[\mathrm{MW}\right]$	458.86	444.73	3.07
$Q_{SH1} \left[\mathrm{MW}\right]$	49.16	49.20	0.085
$Q_{EV} \left[\mathrm{MW}\right]$	82.50	83.55	1.27
$Q_{EC1} \left[\mathrm{MW}\right]$	82.69	83.34	0.78
$Q_{SH2} \left[\mathrm{MW}\right]$	32.01	32.05	0.12
$Q_{EC2} \left[\mathrm{MW}\right]$	9.07	9.13	0.74
$W_{ASU} \left[\mathrm{MW}\right]$	9.12	9.13	0.08
$W_{EXP} \left[\mathrm{kW}\right]$	2.67	2.79	4.37
$W_{ST1}$	19.70	19.48	1.15
$W_{ST2}$	87.30	87.04	0.29

displays the output parameters for the power and heat transfer rates of the different system components obtained from Thermoflex (based on real plant data information) and MATLAB simulations. In all cases, the simulated results presented an error lower than 4.5% and, therefore, an appropriate agreement with each other.

Table 4. Comparison between the obtained ISGC modelling results with those from Zhang et al. [29].

Parameter	Present Study	Zhang et al. [29]
Exergy input (MW)	678.99	861.06
Exergy destruction (MW)	366.57	488.81
Net output power (MW)	319.92	389.77
Thermal efficiency (%)	50.01	49.94
$E{X}_D/E{X}_{input}(\%)$	53.98	56.7

exhibits the main results of the proposed ISGC modelling approach compared to those found by Zhang et al. [29], including the exergy input to the system, exergy destruction, net output power, thermal efficiency, and the ratio of exergy destruction to total input exergy. The results showed a similar thermal efficiency of around 50% for both studies. Even though the pre-combustion chamber was omitted in the present system (compared to Zhang et al. [29]), the ratio of exergy destruction to total input exergy was decreased by 4.8% (from 56.7% to 53.98%). Therefore, in the output power scale of the cycle, this configuration also reduced the investment cost. It should be noted that the main goal in the study was to increase exergoeconomic efficiency; therefore, expressing the increase in thermal efficiency from 49.5% to 50% indicated that replacing the coal fuel feed with heavy refinery fuel in cycle did not reduce the relative thermal efficiency but also caused a slight improvement. Furthermore, the system produced 319.92 MW of power by feeding on 15.5 kg/s of heavy refinery fuel. This occurred at a thermal efficiency of 50.01% and exergy efficiency of 53.98%.

4.2. Conventional Exergy-Based Analyses

Table 5. Stream specifications obtained from conventional exergy-based analyses.

Stream	$\dot{\mathit{m}} \left[\mathbf{k}\mathbf{g}/\mathbf{s}\right]$	$\mathit{T} \left[°\mathbf{C}\right]$	$\mathit{P} \left[\mathbf{bar}\right]$	$\dot{\mathit{E}\mathit{x} }\left[\mathbf{MW}\right]$	$\mathit{c} \left[\mathbf{\$}/\mathbf{G}\mathbf{J}\right]$	$\dot{\mathit{C}} \left[\mathbf{\$}/\mathbf{h}\right]$	$\mathit{b} \left[\mathbf{p}\mathbf{t}\mathbf{s}/\mathbf{G}\mathbf{J}\right]$	$\mathit{B} \left[\mathbf{p}\mathbf{t}\mathbf{s}/\mathbf{h}\right]$
1	9.35	25.00	40.58	0.037	0.000	0.000	0.00	0.000
2	0.14	100.00	1.013	0.000	0.000	0.000	0.00	0.000
3	182.1	35.00	0.92	0.000	0.000	0.000	0.00	0.000
4	28.11	400.00	35.61	587.25	5.21	11,027.18	1,600	3,382,571.52
5	8.01	142.5	39.00	3.48	140.83	1766.34	22,200	278,361.36
6	28.53	718.94	37.05	601.89	4.94	10,721.34	1500	3,250,206
7	17.40	100.00	40.00	0.65	0.00	0.000	0.000	0.000
8	15.50	25.00	37.92	678.99	2.28	5592.70	14.00	34,221.09
9	5.16	25.00	1.014	0.000	0.00	0.00	0.000	0.000
10	28.53	400.00	36.32	589.38	4.94	9623.63	1500	3,182,652
11	9.35	250.00	39.78	2.40	51.50	446.31	29,400	254,756.88
12	5.16	150.00	0.921	2.58	16.92	157.28	241,400	2,243,861.28
13	110.29	353.90	0.88	12.11	9.97	434.79	3,800	165,719.52
14	523.2	25.00	0.87	0.00	0.00	0.00	0.000	0.000
15	110.3	608.9	0.88	30.40	9.97	1091.26	3800	415,926.72
16	28.30	473.95	24.11	589.11	5.49	11,644.23	1,800	3,499,313.4
17	0.41	400.00	1.013	0.069	0.00	0.00	0.000	0.000
18	441.19	171.42	0.87	12.08	0.00	0.00	0.000	0.000
19	28.30	206.73	35.43	583.37	5.46	11,473.02	1700	3,570,224.4
20	551.48	608.9	0.88	152.29	9.97	5465.99	3,800	2,083,327.2
21	74.35	38.74	0.068	7.26	11.85	309.71	12,500	326.7
22	74.35	38.70	0.068	0.08	11.85	3.79	12,500	4,000.5
23	441.19	512.47	0.88	91.80	9.97	3295.06	3,800	1,255,892.4
24	182.00	25.00	1.013	0.00	0.00	0.00	0.000	0.000
25	110.29	278.16	0.87	7.81	0.00	0.00	0.000	0.000
26	33.36	25.00	0.87	0.00	0.00	0.00	0.000	0.000
27	65.00	368.6	39.78	75.30	13.06	3542.75	12,500	3,388,770
28	28.29	519.05	34.73	592.29	5.49	11,706.01	1800	3,838,039.2
29	3,238.5	25.00	1.013	0.043	0.00	0.00	0.000	0.000
30	441.19	346.08	0.88	46.65	9.97	1674.46	3,800	638,213.04
31	65.00	310.00	122.40	26.48	18.00	1721.94	14,800	1,411,120.8
32	65.00	326.19	122.40	68.32	13.78	3390.84	12,300	3,025,342.44
33	65.00	535.00	119.95	96.02	13.08	4523.55	12,500	4,320,990
34	9.35	250.03	39.78	9.30	6.312	211.46	11,800	395,318.88
35	441.19	608.9	0.88	121.83	9.970	4,372.72	3800	1,666,634.4
36	27.24	400.00	35.43	587.09	5.427	11,470.07	1600	3,381,638.4
37	0.86	400.00	0.87	0.127	0.000	0.00	0.000	0.000
38	74.35	536.8	38.98	103.02	11.85	4394.83	12,500	4,635,900
39	3,238.5	37.08	0.66	3.156	27.20	309.08	32,100	364,707.36
40	74.35	351.28	39.78	84.46	6.98	2124.84	7100	2,158,899.84
41	65.00	25.00	124.85	0.805	0.00	0.00	0.000	0.000

shows the results obtained for the conventional exergy, exergoeconomic, and exergoenvironmental analyses for each process stream through system simulations using MATLAB software environment.

Table 6. Results obtained from conventional exergy, exergoeconomic, and exergoenvironmental analyses for the different system components.

Equipment	$\dot{\mathit{Z} }\left[\mathbf{\$}/\mathbf{h}\right]$	$\mathit{f} [\mathbf{\%}]$	$\mathit{r} [\mathbf{\%}]$	${\dot{\mathit{C}}}_{\mathit{D}} \left[\mathit{U}\mathit{S}\mathbf{\$}/\mathit{h}\right]$	$\dot{\mathit{Y} }\left[\mathit{p}\mathit{t}\mathit{s}/\mathit{h}\right]$	$\mathit{f}\mathit{b}[\mathbf{\%}]$	$\mathit{r}\mathit{b}[\mathbf{\%}]$	${\dot{\mathit{B}}}_{\mathit{D}}\left[\mathit{p}\mathit{t}\mathit{s}/\mathbf{h}\right]$	$\mathit{\epsilon } [\mathbf{\%}]$
ASU	1,341.72	83.66	991.04	262.08	415.08	0.48	162.71	87,654.6	38.18
Solar field	157.32	100	-	0	1190.52	100	-	0	20.09
Gasifier	340.92	81.26	62.35	786.6	11,100.24	3.98	12.17	267,465.6	89.54
Syngas cooler	6.84	7.76	72.09	81.72	211.68	00.83	67.05	25,318	60.06
Heat exchanger	9.36	12.7	46.16	64.08	110.16	00.55	40.53	19,833.4	71.28
H2S remover	529.2	93.53	5.41	36.72	59.76	0.53	00.35	11,345	99.65
CO2 capture	445.68	83.55	150.04	87.84	59.76	0.32	24.46	18,383.4	80.2
Humidifier	3.96	5.16	0.68	73.44	57.96	0.26	00.65	21,995.2	99.36
Expander	35.28	77.95	85.37	10.08	11,642.4	78.41	87.17	3205.8	84.16
Combustion chamber	5.4	0.12	25.23	4550.4	7364.16	0.46	25.32	1,603,906.9	79.87
Air compressor	756.36	44.88	18.17	929.16	1319.04	0.42	10.06	310,375	90.9
Gas turbine	4174.92	86.05	29.46	677.16	9908.28	3.74	4.27	255,060	96.05
Superheater (1)	48.96	0.09	13.31	83.52	13,113.36	29.42	11.9	31,462.9	99.25
Evaporator	28.87	36.88	11.14	118.8	644.76	1.42	8.03	44,807	92.66
Economizer (1)	47.52	9.92	38.45	430.92	499.32	0.31	34.74	162,280.8	74.28
Superheater (2)	23.04	2.53	39.15	888.12	9,027.72	1.25	38.64	710,712	72.38
Economizer (2)	11.52	5.65	86.02	194.76	58.68	0.079	81.24	73,389.6	55.2
Steam turbine (1)	71.64	60.22	12.85	47.52	13,113.36	4.81	5.37	45,468	95.14
Steam turbine (2)	180.72	33.36	14.54	360.72	6807.96	1.75	9.86	381,528	91.17
Condenser	3.19	1.81	132.81	173.16	26.28	1.81	130.42	183,060	43.4

ASU: air separation unit.

displays the exergy, exergoeconomic, and exergoenvironmental analyses’ results for each equipment piece in the cycle. The results show that the exergy efficiency of the solar field and the condenser was approximately 20% and 43%, respectively. One reason for such exergy efficiency values is the relatively low efficiency in the air separation unit (38%). The latter value was owed to using a membrane-based oxygen separation system, which required high-power-consuming compressors.

In addition, the results revealed that the combustion chamber had the highest exergy destruction cost. The combustion chamber also presented higher cost and environmental impacts of the exergy destruction when compared to other equipment units. Therefore, its performance should be improved to mitigate its exergy destruction. Heat recovery equipment had the lowest exergoenvironmental coefficient, which indicated that the exergy destruction of this equipment had high adverse effects on the environment. This is affected by thermodynamic factors and other reasons, for instance, the equipment weight, which means that it should be optimally designed from thermodynamic and structure to prevent adverse environmental effects. A practical suggestion to reduce these effects in the heat recovery equipment could be to couple them to a solar energy field to increase the temperature of the water entering the system. In the investment cost section, the highest amount was related to the gas turbines, and the lowest was presented by the condenser.

To better understand the critical parameters of the system, the share of exergy destruction in the system components is depicted in Figure 2. Hence, the combustion chamber, the gasifier, and the HRSG unit had the highest share of exergy destruction. The rate of exergy destruction in the combustion chamber was 43%, which can be reduced by implementing an optimal design approach. Compared to other similar cycles, a noteworthy point in the present system is the relatively low exergy destruction share of the gasifier (25%), which was due to the employment of the air separation unit and, thereby, the injection of pure oxygen.

Figure 3 displays the cost flow diagram of the proposed system. As observed, the amount of exergoeconomic destruction of the combustion chamber, HRSG, and gasifier was higher than other equipment. Moreover, in terms of equipment cost rate, the highest cost was related to the gasifier, followed by the gas turbine. The remarkable point in this figure that distinguishes this system from other conventional cycles is that the total exergy destruction costs were lower than the total equipment costs. This is owed to the inexpensiveness of the fuel employed in this system, which was a direct function of the exergoeconomic destruction of the equipment.

The total cost of exergy destruction was equal to 164.27 US$/min, whereby the highest rate was related to the combustion chamber with 46.17% share, followed by the HRSG with 17.41%. Besides, in the equipment cost rate section, out of the total 188.52 $/min, the highest, with 43.46%, was related to the gasifier, followed by the purifying section at 9.05%. The sum of these costs caused the rate of total cycle exergy destruction at 446.02 $/min.

The system environmental impacts, including the environmental impact rate of the equipment, exergy destruction, and the fuel entering the cycle, are displayed in Figure 4. The summation of these effects led to the total environmental impact rate of the system. As observed in this figure, the environmental impact rate of exergy destruction of the combustion chamber, HRSG, and the gasifier was higher when compared to other equipment pieces in the system. It is noteworthy that the total environmental impact rate of exergy destruction of each piece of equipment was less than the environmental impact rates of the equipment. The reason behind this is the high calorific value of the fuel used in this system, which was a direct function of the exergoenvironmental exergy destruction of the equipment.

The total rate of environmental exergy destruction effects was 70,961 pts/min, in which the highest rate was related to the combustion chamber, with a 37.67% share, followed by the HRSG unit, with 24.02%. The total equipment environmental impact rate amounted to 22.2 pts/min, among which the HRSG had the highest cost rate, with a 30.75% share, followed by the gasifier, with 17.2%. The sum of these environmental effects led to the total cycle environmental impact rate of 72,796 pts/min.

4.3. Advanced Exergy-Dased Analyses

Figure 5 displays the advanced exergy analysis, namely, avoidable, unavoidable, endogenous, and exogenous exergy destruction in each system equipment. The highest avoidable exergy destruction was related to the condenser, followed by the syngas cooler and the gas turbine. Moreover, the highest endogenous exergy destruction was associated with the solar field, followed by the combustion chamber and the CO₂ capture unit. To increase the exergy efficiency, system components with high avoidable exergy destruction such as the condenser, syngas heat exchanger, and gas turbine can be prioritized for modifications. Based on avoidable exergy destruction, the steam turbines 1 and 2, air compressor, and CO₂ capture unit had the minimum potential for improvement. Hence, these components do not require any modifications or improvement. In addition, steam turbines 1 and 2 and condenser had minimum endogenous exergy destruction.

Figure 6 depicts the advanced exergoeconomic destruction share of each system equipment. As shown, the condenser also had the highest avoidable exergoeconomic destruction share, while the steam turbines had the lowest. Therefore, components with high avoidable exergy destruction such as the condenser can be prioritized for modification to increase the exergoeconomic efficiency. This modification can include changing the type of equipment used, regardless of the cost of exergy destruction. In addition, the syngas cooler, gas turbine, economizer, scrubber, and CO₂ capture are in the following priority for improvement. However, steam turbines 1 and 2 presented minimum potential for improvement based on the avoidable parameter. Based on the endogenous parts of the cost of exergy destruction, the combustion chamber, gas turbine, air separation unit, H₂S removal, and CO₂ capture had the highest rates.

The advanced exergoenvironmental destruction share of equipment is shown in Figure 7. Similarly to the previous results, the condenser had the highest avoidable exergoenvironmental destruction share among the equipment units. Moreover, it is noticeable that the components unavoidable exergoenvironmental destruction share in all equipment was higher than avoidable (except for the condenser). In addition, components with high avoidable exergy destruction such as the condenser, syngas cooler, Economizer 2, and GT can be prioritized for modification to increase the exergoenvironmental efficiency. In this case, this modification can be grounded on the type of equipment used in terms of manufacturing processes and lower weight.

Table 7. Ranking of equipment obtained from conventional and advanced exergy analyses.

	Conventional (MW)					Advanced (MW)
Equipment	${\dot{\mathit{E}}}_{\mathit{D},\mathit{k}}$	${\dot{\mathit{C}}}_{\mathit{D},\mathit{k}}$	${\dot{\mathit{C}}}_{\mathit{D},\mathit{k}}$$+{\dot{\mathit{Z}}}_{\mathit{k}}$	${\dot{\mathit{B}}}_{\mathit{D},\mathit{k}}$	${\dot{\mathit{B}}}_{\mathit{T},\mathit{k}}$	${\dot{\mathit{E}}}_{\mathit{D},\mathit{k}}^{\mathit{A}\mathit{V}}$	${\dot{\mathit{E}}}_{\mathit{D},\mathit{k}}^{\mathit{E}\mathit{N}}$	${\dot{\mathit{C}}}_{\mathit{D},\mathit{k}}^{\mathit{E}\mathit{N}}$	${\dot{\mathit{B}}}_{\mathit{D},\mathit{k}}^{\mathit{A}\mathit{V}}$	${\dot{\mathit{B}}}_{\mathit{D},\mathit{k}}^{\mathit{E}\mathit{N}}$
Air separation unit	9	8	5	9	9	13	12	12	14	12
Solar field	6	20	14	20	20	15	1	2	15	2
Gasifier	2	4	3	5	5	12	8	8	11	7
Syngas cooler	1	13	17	14	14	2	13	15	2	15
Heat exchanger	13	15	19	16	16	9	14	13	9	13
H2S remover	16	17	7	18	19	17	6	3	16	3
CO2 capture	20	12	9	17	17	17	3	5	8	4
Humidifier	12	15	18	15	15	6	11	7	7	9
Expander	19	19	20	19	18	14	5	10	13	10
Combustion chamber	1	1	2	1	1	8	2	1	6	1
Air compressor	4	2	4	4	4	18	7	6	18	6
Gas turbine	5	5	1	6	6	3	4	4	3	5
Superheater (1)	15	13	15	13	13	16	9	11	17	11
Evaporator	14	11	13	12	12	11	10	9	12	8
Economizer (1)	7	6	10	8	8	10	15	14	10	14
Superheater (2)	3	3	6	2	2	5	17	17	5	17
Economizer (2)	17	9	11	10	10	4	16	16	4	16
Steam turbine (1)	18	18	16	11	11	19	20	19	19	19
Steam turbine (2)	8	7	8	3	3	20	19	20	20	20
Condenser	11	10	12	7	7	1	18	18	1	18

presents the ranking of the impact of exergy, exergoeconomic, and exergoenvironmental destruction rate parameters in the conventional and advanced analyses for each equipment used in the ISGC system. This table helps determine the distribution and extent of the maximum exergy destructions and identify the effects in the cost and environmental sections to minimize the exergy losses in the optimization step in terms of the least amount of time and cost.

As shown in the conventional results in Table 7, the highest exergy destruction was related to the CO₂ capture unit, while the lowest rate was associated with the syngas cooler and combustion chamber, simultaneously. Regarding the exergoeconomic destruction rate, the highest value was associated with the solar field (20 MW) and the lowest with the combustion chamber (1 MW). For the sum of exergoeconomic destruction and investment cost, the highest amount was related to the expander (20 MW), whereas the lowest one was to the gas turbine (1 MW). For exergoenvironmental impact rate, the solar field had the highest value (20 MW), while the combustion chamber (1 MW) presented the lowest. Finally, for the sum of component and operational exergoenvironmental impact rate, the highest and lowest values were pertinent to the combustion chamber and solar field, respectively. The highest and lowest values herein indicate the strengths and weaknesses of the present cycle that can be used for optimization and future work, where equipment pieces with lower exergy efficiency can be the focal point for future optimization analysis.

In the advanced analysis section, the highest amount of avoidable exergy destruction was associated with the steam turbine 2 (20 MW), while the lowest was attributed to the condenser (1 MW). The steam turbine 1 (20 MW) had the highest endogenous exergy destruction, whereas the solar energy field showed the lowest one. In addition, the highest rate of endogenous exergoeconomic destruction was related to the steam turbine 2 (20 MW), whereas the combustion chamber (1 MW) presented the lowest rate. The highest avoidable exergoenvironmental impact rate was related to the steam turbine 2 (20 MW), while the lowest was associated with the condenser (1 MW). Finally, the highest rate of endogenous exergoenvironmental impact rate was related to the steam turbine 2 (20 MW), whereas the lowest one was to the combustion chamber.

5. Conclusions

This paper investigates a new integrated solar-assisted gasification cycle (ISGC) for producing steam and power utilities from low-cost heavy refinery fuels while enhancing energy efficiency and economic and environmental performance indicators. In the proposed ISGC system, syngas from the gasifier enters the turbine to produce power after purification and separation of pollutants. Then, it is sent to the steam section for thermal energy recovery. In addition, a solar energy field and a two-pressure heat recovery steam generator (HRSG) are integrated into the plant to enhance the overall economic and environmental plant viability. In this new study, the ISGC system was modelled in MATLAB software, and the results were validated using Thermoflex software. Conventional and advanced energy, exergy, exergy-economic, and exergy-environmental (4E) analyses were implemented to evaluate the economic and environmental system performance. In addition, the 4E analyses allowed for the detailed examination of the different system units and the determination of a prioritization order for future optimization and improvement.

The results obtained from the 4E analyses revealed that replacing the coal fuel feed with heavy refinery fuel allows for a slight improvement in the thermal efficiency, from 49.5% to 50%. Moreover, the ratio of exergy destruction to total input exergy was decreased by 4.8% compared to results for the conventional cycle in the literature. The latter result indicated that the proposed ISGC configuration can also reduce the plant investment cost. Besides, the system produced 319.92 MW of power by feeding on 15.5 kg/s of heavy refinery fuel, at a thermal efficiency of 50.01% and exergy efficiency of 53.98%. The results also showed an investment cost of $466 million, gauged at a system cost rate of 446 $/min and an environmental impact rate of 72,796 pts/min. To sum up, these results demonstrate that the proposed ISGC is theoretically viable for converting heavy refinery fuels into syngas and producing power. Therefore, the new approach provides a feasible solution towards reducing environmental impacts related to heavy refinery fuels, particularly for oil-rich countries with high availability of solar resources.

The thermodynamic simulation results show that the computer code developed in MATLAB has high accuracy compared with the Thermoflex software (with overall errors lower than 4.5%). This verification of results is acceptable for steady-state conditions, and high-accuracy is achieved. However, for dynamic and transient analyses, these assumptions are not enough. In this case, the kinetic model must be considered for the gasifier. Additionally, part-load conditions for turbines and compressors should be implemented.

Some recommendations for future research include adding a set of solar collectors to the entrance of the HRSG unit for preheating the inlet water, which could further improve energy efficiency; using pure oxygen produced in the high-pressure air separation unit to feed the combustion chamber (instead of atmospheric air) while eliminating the air compressor since this alternative could lead to higher combustion efficiency and a decrease in investment costs; using different carbon capture technologies; optimizing main design and operating parameters; using a gasifier system with higher temperature and pressure tolerance; and, finally, comprehensive footprint assessment can be performed for improving environmental analysis of a proposed system.