Oxy-combustion Power Plants Research Articles

Dynamic modelling and simulation of the Graz Cycle for a renewable energy system

Critical atmospheric carbon dioxide levels and, in response, an increasing shift toward variable renewable energy sources causes the need of transient operation for thermal power plants coupled with carbon capture and storage. In this regard, dynamic process simulations are a valuable tool for predicting the cycling performance of power plants. In this study, the proposed Graz Cycle, an oxy-combustion power plant fired with natural gas, is investigated and modelled in (a) the steady-state design-point (i.e., full-load), (b) steady-state off-design (i.e., part-load), and (c) dynamic conditions. At full loads, the Graz Cycle power plant achieves a maximum net plant efficiency of 54.5%, comparable to the performance results of the competing Allam cycle found in relevant studies. In the off-design simulation, considering for the first time compressor component maps with variable inlet guide vanes, the load is reduced down to 50% achieving improved performance results compared to previous studies. The dynamic simulation boils down to a ramp rate analysis and shows that practical ramp rates of 5.55 %/min for load decrease and 18.18 %/min for load increase can be reached. The results show that the high ramp rates of the Graz Cycle enable balancing services to the electrical grid next to clean and dispatchable power generation. In this study, a systematic first-principle modelling approach has been developed with the final aim to evolve dynamic models for oxy-combustion carbon capture cycles, and a first-of-its-kind analysis of the dynamic operation of the Graz Cycle is presented.

Sustainability assessment of the oxy-combustion coal-fired power plant using low-grade fuel

In line with global efforts to reduce emissions, the integration of coal-fired power generation plants with carbon capture technologies has been investigated. Low-rank coal is gaining interest as coal price is on an increasing trend in recent years, however, an air-combustion of low-rank coal without CO2 capture shows a high specific CO2 emission of 869 kgCO2/MWh. This work presents a comparative assessment of post-combustion CO2 capture and oxy-combustion retrofitted to a low-rank coal-based power plant from the viewpoints of economics and sustainability. Post-combustion CO2 capture leads to an 82.7 % reduction in the specific CO2 emission (of 151 kgCO2/MWh) with a CO2 avoidance cost of 47.5 USD/tonCO2. Oxy-combustion is shown to be more competitive for CO2 capture applications, achieving a 97.3 % reduction in the specific CO2 emission (of 23.8 kgCO2/MWh) with a CO2 avoidance cost of 37.7 USD/tonCO2. As results of sensitivity analysis, the low-rank coal-based oxy-combustion power plant is more economically and environmentally attractive.

Process design and comprehensive comparison of coal- and biomass-fired oxy-combustion power plant

Oxy-combustion is a promising option to achieve large-scale CO2 emission reduction associated with coal-fired power plants. However, its commercial application is greatly restricted due to the large efficiency penalty and high cost of electricity. In this paper, a novel 1000 MW single reheat oxy-combustion power plant is proposed by adopting the heat capacity flowrate matching method to reduce irreversible loss and increase heat recovery of the overall power plant. A quantitative comparison of novel coal- and biomass-fired cases is conducted. The results show that the net electric efficiency of the novel oxy-combustion power plant improves by 0.85% points with a 1.0% points enhancement in the exergy efficiency and a 1.1 $/(MW·h) reduction in the cost of electricity compared with the reference case. When biomass is selected as the fuel, the net electric efficiency of the novel system increases by 1.1% points, and 4.0 MtCO2 is removed from the atmosphere annually. Exergy analysis reveals the energy-saving mechanism of the novel system. Economic analysis indicates that total investment can be recovered within 1.8 years. This work provides an efficient and economic scheme for the design of oxy-combustion power plants.

Design strategies for oxy-combustion power plant captured CO2 purification

Abstract This study presents a novel design and techno-economic analysis of processes for the purification of captured CO2 from the flue gas of an oxy-combustion power plant fueled by petroleum coke. Four candidate process designs were analyzed in terms of GHG emissions, thermal efficiency, pipeline CO2 purity, CO2 capture rate, levelized costs of electricity, and cost of CO2 avoided. The candidates were a classic process with flue-gas water removal via condensation, flue-gas water removal via condensation followed by flue-gas oxygen removal through cryogenic distillation, flue-gas water removal followed by catalytic conversion of oxygen in the flue gas to water via reaction with hydrogen, and oxy-combustion in a slightly oxygen-deprived environment with flue-gas water removal and no need for flue gas oxygen removal. The former two were studied in prior works and the latter two concepts are new to this work. The eco-technoeconomic analysis results indicated trade-offs between the four options in terms of cost, efficiency, lifecycle greenhouse gas emissions, costs of CO2 avoided, technical readiness, and captured CO2 quality. The slightly oxygen-deprived process has the lowest costs of CO2 avoided, but requires tolerance of a small amount of H2, CO, and light hydrocarbons in the captured CO2 which may or may not be feasible depending on the CO2 end use. If infeasible, the catalytic de-oxygenation process is the next best choice. Overall, this work is the first study to perform eco-technoeconomic analyses of different techniques for O2 removal from CO2 captured from an oxy-combustion power plant.

A part-load analysis and control strategies for the Graz Cycle

Carbon capture and storage (CCS) plays a uniquely important role in the future clean and dispatchable power generation portfolio to achieve the ambitious goals set at COP21. The Graz Cycle, a zero emission oxy-combustion power plant, is one of the most promising representatives of CCS power generation plants. The present work introduces different control strategies for the Graz Cycle and the corresponding part-load performances. The process simulation is composed of a design-point (full-load) and off-design (part-load) of the cycle. In order to do this, the process simulation tool IPSEpro was used. Individual cycle components were modelled for both investigations, full load and part load, and control strategies were developed in order to achieve optimum performances and operating efficiencies by means of the assumptions given. This work distinguishes from previous studies by the development of different control strategies and comparison of corresponding part-load performances. In the simulation, the Graz Cycle operating at nominal design conditions achieved a net plant efficiency of 53.1%. The part-load simulation generated results down to 40% load by applying three different control strategies. These control operation modes differ from each other in two basic parameters, boiler pressure and turbine inlet temperature. Optimum part-load performances were achieved by control strategy, where the pressure of the heat recovery steam generator is allowed to vary. However, other parameters, e.g. costs, did not appear to be favourable for this operation mode. The comparison with a readily available technology, such as a natural gas combined cycle, showed that the Graz Cycle is more efficient as loads are reduced below 50%.

Life cycle energy-economy-environmental evaluation of coal-based CLC power plant vs. IGCC, USC and oxy-combustion power plants with/without CO2 capture

Coal-based chemical looping combustion (CLC) power plant presents itself as a promising technology due to its low energy penalty which is associated with its inherent CO2 capture process. However, most evaluations and comparisons (energy efficiency, economic, and environmental aspects) of the CLC power plant generally were focused on the power plant operation stage. Life cycle assessment (LCA) method with a “cradle to gate” model involving power plant construction, operation, and decommissioning stage,of coal-based power plants was established. Following that the resource consumption, energy consumption, environmental impact potential, and economic performance in the life cycle, were comprehensively compared between the coal-based CLC power plant and other plants such as IGCC, USC and oxy-combustion power plants with and without (w/o) CO2 capture, to find out the potential and deficiency of the coal-based CLC power plant in a life cycle perspective. Results showed that energy resource consumption accounts for the largest proportion of the total resource consumption (81.88–91.89%) in six coal-fired power plants. Among the environmental impact potentials, smoke and dust potential (SAP) has the highest value while eutrophication potential (EP) resulted in the lowest in six coal-based power plants. CLC presented resource depletion indicator, energy payback ratio and the total life cycle costs, at 4.79 × 10−6 kWh/person/day, 3.22, and 0.138 $/kWh, respectively. These power plants were ranked from highest to lowest according to their sustainability as the following USC, CLC, IGCC, oxy-CCS, USC-CCS, and IGCC-CCS. However, CLC presents the best sustainability in all coal-based power plants with CO2 capture. The CLC power plant will be one of the most attractive options for carbon reduction in coal-based power systems, as the development of CLC technology further improves energy efficiency and economic performance. The results further demonstrated that the coal-based CLC power plant can solve the issues involving CO2 emission reduction and energy utilization in coal to power generation process from lifecycle viewpoint.

Performance evaluation of a pressurized oxy-combustion power plant according to wet and dry flue gas recirculation

In a pressurized oxy-combustion (POXY) power plant, it is essential to control the furnace temperature using flue gas recirculation (FGR) as an oxy-combustion environment produces an extremely high temperature in the furnace. However, FGR decreases the plant efficiency as it causes exergy loss in the furnace and increases the power consumption of the FGR booster fan. Therefore, to analyze a POXY plant, the effect of FGR on plant efficiency and performance should be evaluated. In this paper, an advanced supercritical pressure (A-USC) POXY power plant with a distributed pressurized oxy-combustion (DPOC) furnace is simulated and its performance for wet/dry FGR is analyzed. The furnace was modeled using an in-house code, and the whole power plant was simulated using commercial process simulation program. Plant efficiency with the wet FGR is 3.5% higher than that of the dry FGR system owing to the higher latent heat recovery of the FGC and reduction in the exergy loss. In addition, we demonstrated that variation of the plant efficiency for various flowrates of the recirculated gas was not significant in case of the wet FGR system, while considerable decrease in plant efficiency was observed for higher recirculation in the dry FGR cases. Accordingly, we presented an optimal A-USC POXY power plant system with a wet FGR system; the plant net efficiency improved by approximately 10% compared with that of a first-generation oxy-combustion power plant at atmospheric pressure.

Comparative Energy and Emission Analysis of Oxy-Combustion and Conventional Air Combustion

Carbon capture and storage and oxy-fuel combustion have recently become more significant due to global warming as well as green energy solutions. Oxy-combustion power plants fueled with natural gas are compatible with today’s clean energy policies. In this study, effects of oxygen content of reactant mixtures used in oxy-combustion on thermodynamic properties, adiabatic flame temperatures, combustion products and pollutant emissions are analyzed using a novel multi-feature equilibrium combustion model. Using natural gas from most important origins (Russia, USA, Iran, Australia) as fuel, results obtained from oxy-fuel combustion for three different O2 fractions are compared with the results of conventional air–fuel combustion for varying equivalence ratio, inlet temperature and pressure. The accuracy of the results is confirmed by two different popular combustion softwares. According to the results, oxy-fuel combustion of same oxygen content with air causes 24% less entropy production but 40 times less NOx emissions which is an indicator of significant decrease in carbon capture and storage costs. Comparison of natural gas of different origins shows that Russian natural gas is more advantageous in terms of NOx emissions where Australian natural gas is more advantageous in terms of entropy production.

Life cycle water consumption for oxyfuel combustion power generation with carbon capture and storage

To fulfill its commitment to carbon emission reduction and peak carbon emission in 2030, China is expected to conduct large-scale carbon capture and storage deployment in future decades, considering the dominant role of coal-based energy for power generation. As an important carbon emission mitigation technology, oxy-fuel combustion will play a significant role in this process. Meanwhile, the water scarcity in China is also worthy of attention, especially in coal-rich areas which are usually water-scarce. The development and implementation of coal-based carbon capture and storage technology may exacerbate the water shortage situation in these regions. Considering this background, a correct analysis of the water use of oxy-fuel combustion power plants is of great importance, before implementing the large-scale deployment of carbon capture and storage. Therefore, this study aims to assess the life-cycle water consumption of a 600 MW oxy-fuel combustion power plant, retrofitted from a typical 600 MW coal-fired power plant in China. Based on a tiered hybrid method, the direct and indirect water consumption of a typical oxy-combustion CCS project is evaluated. Results show that 4.63 L of water is used for capturing 1 kg of carbon dioxide, while the calculated water intensity for power generation is 3.79 L/kWh. The operation and maintenance processes dominate the total water consumption, in which the cooling mode exerts a great influence on life cycle water consumption. Once-through cooling has lower water consumption than recirculating cooling in the retrofitted oxy-combustion power plant. If we compare water consumption with other power generation technologies, the water intensity of oxy-combustion carbon capture and storage power production is lower than that of bio-power, but beyond that of solar photovoltaic and wind power. Moreover, based on the thermal power production in China in 2017 and the water use calculated in this study, transforming all the thermal power plants to oxy-combustion systems is hardly feasible as the induced water withdrawal will account for 17.26%–827.19% of the total industrial water budget in 2030. Further regional analysis indicates that even to achieve 10 Gt of carbon dioxide abatement, Shanxi province will encounter great difficulties due to reduced water availability.

Techno-economic assessment of coal- or biomass-fired oxy-combustion power plants with supercritical carbon dioxide cycle

Oxy-fuel combustion is regarded as a feasible technology that can contribute towards decarbonisation of the power industry. Although it has been shown that oxy-fuel combustion results in lower carbon dioxide emissions at a lower cost of carbon dioxide captured compared to the mature amine scrubbing process, its implementation still results in high economic penalties. This study proposes to replace the conventional steam cycle in the state-of-the-art oxy-combustion coal-fired power plants with the supercritical carbon dioxide cycle to reduce both economic and efficiency penalties. In addition, in order to further reduce carbon dioxide emissions, biomass is considered as a replacement fuel for coal in the oxy-fuel combustion power plant and the proposed process becomes a type of bio-energy with carbon capture and storage. The process models were developed in Aspen Plus™ to assess techno-economic feasibility of the considered processes. The results showed that on replacement of the conventional steam cycle with the supercritical carbon dioxide cycle, the efficiency penalties were reduced by up to 2% points and the levelised cost of electricity was reduced up to 4.6% (4.1 €/MWh). Moreover, when biomass was used as a fuel, the net efficiency penalties increased by 0.5% points and the levelised cost of electricity increased by 24.4 €/MWh. Although techno-economic performance in this case was less favourable under no carbon tax conditions, using biomass resulted in significant negative carbon dioxide emissions (-3.70 megatonnes of carbon dioxide per annum). Such negative emissions can offset carbon dioxide emissions from other sources that are relatively difficult to decarbonise. If the carbon tax is above 24 € per tonne of carbon dioxide, bio-energy with carbon capture and storage became more economically feasible than fossil fuel with carbon capture and storage.

Thermodynamic and economic performance of oxy-combustion power plants integrating chemical looping air separation

Abstract Oxygen supply from cryogenic air separation unit (ASU) causes high economic cost and energy penalty, which hinders the practicability of oxy-combustion technology. Chemical looping air separation (CLAS) as a thermodynamic-efficient and cost-effective approach can satisfy the oxygen demands for oxy-combustion power plants. To optimize process configuration and identify the effect of recycling position for oxy-combustion power plants integrating CLAS (i.e. OXY-CLAS), the paper focuses on process simulation, thermodynamic analysis and techno-economic evaluation of two typical OXY-CLAS systems. For sastifying the oxygen concentration demand in oxy-combustion, the mixture of recycled flue gas and steam is adopted as the reduction medium in CLAS. For OXY-CCLAS (using cold recycled flue gas as oxygen releasing medium in CLAS), its net efficiency and exergy efficiency are 4.80 and 4.54% points higher than those of oxy-combustion coupled with cryogenic ASU, respectively. Meanwhile, its cost of electricity is reduced about 12.18% whilst its CO2 avoidance cost and CO2 capture cost decrease about 48.14% and 39.34%, respectively. When compared between two OXY-CLAS systems, OXY-WCLAS (utilizing warm recycled flue gas in CLAS) exhibits better performance both on thermodynamic and economic aspects. The exergy efficiency of WCLAS system is 1.29% points higher than that of CCLAS system.

Techno-economic analysis of ultra-supercritical power plants using air- and oxy-combustion circulating fluidized bed with and without CO2 capture

The adoption of oxy-combustion in a circulating fluidized bed (CFB) producing ultra-supercritical (USC) steam has been investigated to increase energy efficiency and reduce CO2 emissions of coal-fired power plants. This paper presents a techno-economic analysis for 500 MWe USC-CFB power plants with air- and oxy-combustion in the presence of CO2 capture. An amine absorber unit (AAU) and a CO2 processing unit (CPU) were used to capture CO2 in the air- and oxy-combustion power plants, respectively. The air-combustion power plant without CO2 capture (Case 1) showed the highest net electricity efficiency (46%), whereas the introduction of an AAU in the air-combustion power plant (Case 2) reduced the net efficiency to 36%. The net efficiency (39%) of the oxy-combustion power plant with CPU (Case 3) was higher than that of Case 2 owing to the recycling of hot flue gas. The levelized cost of electricity (LCOE) of Case 3 (59 $/MWh) was lower than that of Case 2 (64 $/MWh), which demonstrated that oxy-combustion was advantageous compared to air-combustion in a scenario with CO2 capture. The sensitivity analyses of the electricity price and CO2 credit showed economic situations where Cases 2 and 3 would be profitable.

Optimal Flue Gas Treatment for Oxy-Combustion-Based Pulverized Coal Power Plants

Oxy-combustion is recognized as the cleanest technology which uses coal as an energy source. Flue gas clean-up is essential for sustainable operation. In this work, the optimal selection of the flue gas treatment technologies in oxy-combustion power plants is determined. A two-stage procedure combining heuristics and mathematical programming is used to evaluate the technologies involved including the boiler, denitrification, electrostatic precipitation, sulfur dioxide removal, and carbon capture. For plant operation, the coal feed has to be selected. An extended blending problem is solved to evaluate the coal type to be purchased based on its cost and composition. The optimal flue gas processing consists of electrostatic precipitation, followed by dry SO2 removal, and CO2 purification using zeolites. No specific denitrification method is required due to the low concentration levels of NOx generated in oxy-combustion. This flowsheet is used to select one among a mixture of three different types of coal: national, imported, and crude coal tar. However, no mixture is recommended as crude coal tar was the one selected. Even though the processing costs are higher, it is outweighed by the lower cost of the raw material.

New approach to materials behaviour studies in high-speed flue gas from oxy-steam combustion

Some new proposals are being considered aiming at improving the efficiency and operability of oxy-combustion power plants, such as the so-called oxy-steam combustion. This process consists in replacing the carbon dioxide by steam in the firing atmosphere. One of the main uncertainties for the feasibility of the oxy-steam technology is the materials resistance to steam corrosion at high temperature, mainly due to chromium vaporization. The novel approach to the issue presented in this work is the generation of realistic flue gas velocity (20 m·s−1) in flames produced with a thermal spray gun using H2 as fuel. Gas composition was selected to match expected final H2O content after combustion: 40 and 60% H2O in CO2 with excess of O2. A set of metallic steels and alloys (SS304, SS310, I800HT, Kanthal and IN617) was preoxidised in air to generate external oxide scales. After preoxidation, the samples were treated under steam flames at 700 °C, placed in a position either parallel or perpendicular to the flame axis. Surface oxides composition was compared to that obtained in a quasi-static furnace, where metallic samples were exposed to steam atmosphere at 700 °C for 20 h (50% steam, 45% CO2 and 5% O2). The characterisation of the surfaces was performed using low-angle XRD and SEM-EDX for a precise measuring of the variation of oxide amount and chromium content. The analyses showed that mixed Cr-Mn and Cr-Fe external oxides formed during the preoxidation stage suffered the depletion of the surface chromium when they were exposed parallel to the steam flame axis, as a simulation of the lateral flue gas pass in the heat-exchanger tubing. Cr depletion was also observed in the windside of tubes (perpendicular to flame axis) but in minor extent. The reduction in the Cr amount of the samples when tested in the vapour furnace was negligible compared to the Cr loss found after treatment under high velocity flames. The presence of external (Mn,Cr)3O4 in preoxidised SS310 and SS304 did not provide an effective protection against Cr volatilization in the steam flame treatment, whereas surface alumina in Kanthal seemed to prevent Cr volatilization.

Experimental Investigation and Process Simulation of Oxy-fuel Flue Gas Denitrification in CO2 Compression Process

In oxy-combustion power plants, flue gas impurities such as NOx must be removed before CO2 recovery. Currently, sorbents or catalysts as well as a flue gas treatment device are required for the app...

Process optimization and working fluid mixture design for organic Rankine cycles (ORCs) recovering compression heat in oxy-combustion power plants

In this study, an Organic Rankine Cycle (ORC) is proposed to be integrated with the flue gas pre-compression process to reduce the energy cost resulting from Carbon Capture and Storage (CCS). An equation-based flowsheet optimization model is developed considering the mixture working fluid design, ORC operating conditions and the compression process simultaneously. The optimal number of stages of CO2 compression, the working fluid composition and the optimal operating conditions of ORCs and the compression train can be determined simultaneously using the proposed mathematical model. Proper heat integration can boost the power output of the ORC system significantly. The heat integration model considering variable process streams is extended to the integrated ORC and flue gas compression train process. The results show that the optimal number of stages is 4 and a pure working fluid could perform better than a mixture working fluid if operating conditions are chosen properly. The integration of ORCs can reduce the energy penalty by 7.9% compared with the original optimal design that did not include ORCs. In addition, one compressor stage is avoided.

The effects of scale-up and coal-biomass blending on supercritical coal oxy-combustion power plants

Carbon Capture and Storage (CCS) with biomass is called to be one of the most important technologies to reduce the climate change all over the world. In addition, supercritical pulverized coal plants have been pointed out as interesting power installations because its high efficiency. In this work, the effects of plants scaling and biomass-coal co-firing level on net present value (NPV), cost of energy (COE) and cost of CO2 avoided (CCA) have been studied on a supercritical pulverized combusting coal/biomass blends. Aspen Plus© was used to implement technical simulations. Finally, the main factors affecting plants viability were identified by a sensitivity analysis. The results obtained revealed that the use of biomass reduces the NPV in (−0.23,−1.75) M€/MWe, and increases the COE by (0.007,0.263) M€/MWe. However, plant scaling was found to be a more important factor, by reaching an impact of 4.32 M€/MWe on NPV variation in best case. The reduction of oxy-plants viability by biomass using as raw material could be compensated by an increasing of the designed scale-up. Finally, 300 MWe power plants with 40–50% biomass co-firing level were identified as a compromise solution between economy and risk, improving in this way the interest for potential investment.

Techno-economic Optimization of First Generation Oxy-fired Pulverized-coal Power Plant

In this paper, a holistic approach taking into account process economics is employed in order to assess the true potential of first generation oxy-fired power plants. The proposed methodology is carried out in two-steps. The first step consists in the minimization of the energy penalty: an exergy analysis is performed on a conventional base-case oxy-fired power plant in order to identify the possible improvement paths, including structural modifications and thermal integrations. At the end of this step, the process layout leading to a minimized energy penalty is obtained. However, as the introduction of a process modification impacts the plant's CAPEX, each modification highlighted in the previous step is characterized by a techno-economic criterion in order to determine its profitability in a second step. The marginal cost of electricity production, defined as the ratio between additional CAPEX and the net production increase is used for the process modification assessment.This procedure has been applied on state-of-the-art processes in order to estimate the potential of first generation oxy-combustion power plant. The optimization solely based on an energetic criterion leads to a plant layout with an energy penalty of 6.0%-pts, which represents a 38% reduction (the energy penalty of the base case plant is 9.4%-pts). However, the consideration of economic aspects has highlighted that some of the considered process modifications were not justified on an economic stand point. The optimal oxy-fired power plant, from a techno-economic point of view, exhibits an energy penalty of 6.9%-pts and allows a 20% reduction of the CO2 avoidance cost compared to the base-case oxy-fired plant.

Conceptual design and modelling of an industrial scale power to gas-oxy-combustion power plant

The intermittent nature of renewable energy sources is a key challenge to their integration into the electricity grid. The aim of this paper is to introduce an advanced concept of Power-to-Gas (PtG) plant, which is designed to bring a closed-loop solution able to absorb electricity surplus and to restore it later, via the transient storage of energy carriers. After a brief conceptual overview of the studied unit and its individual components, the paper introduces the key results of the steady state model used to assess process flowsheets as well as operating conditions of the industrial scale unit. These results indicate that during the storage phase, a 200 MW power supply to the electrolysis process leads to a corresponding 155 MW of Synthetic Natural Gas (SNG) produced in a thermally integrated methanation process with an efficiency of 83.1%. By producing and storing enough amount of SNG and oxygen, an Oxy-combustion power plant can be subsequently used to recover up to 480 MW electric power as well as to produce CO2 rich gas with an overall efficiency of 51.8%. Lastly, a thorough sensitivity analysis was conducted to show that the Electrolysis-Methanation-Oxy-combustion (EMO) unit performance can be further improved by adjusting key design parameters accordingly.

Numerical Modeling and Simulation of Oxy-Combustion Exhaust Gas Recycling for Fuel Reforming

Different pragmatic approaches have recently been adopted in Paris Agreement of 2015 on the reduction of greenhouse gases, especially carbon dioxide (CO2). A viable option toward reduction of CO2 emission is to couple an exhaust gas fuel reforming reactor to an oxy-combustion power plant for in situ recycling and utilization of unwanted CO2 emission for fuel upgrade. In such a system, steam and dry fuel reforming take place simultaneously with the exhaust gases that are mainly water vapor and carbon dioxide. This study was carried out to explore the advantage of using the gas turbine high exhaust temperature and utilize the unwanted CO2 for fuel upgrade via methane-exhaust gas reforming. A numerical model was developed to study the effect of reforming temperature, gas hourly space velocity (GHSV) and reformer gas ratio (CO2/H2O) on the following performance metrics: methane conversion, fuel upgrade, and hydrogen yield in an exhaust gas-reforming reactor. Results show that the methane conversion increases ...