Natural gas is expected to make up a significant proportion of the future global energy mix. Therefore, reducing greenhouse gas emissions from gas-fired processes is very essential for most countries, before emission reduction targets can be met. This article aims to carry out thermodynamic analysis of combined cycle gas turbine power plant with post-combustion CO2 capture through modelling and simulation. The combined cycle gas turbine power plant and the CO2 capture plant were simulated in Aspen Plus®. The combined cycle gas turbine power plant model was validated with simulation data from GateCycle® and the CO2 capture plant model was validated with experimental data from the pilot plant at the University of Texas at Austin. The CO2 capture plant was scaled up from pilot plant to commercial scale to process flue gas from a 250 MWe combined cycle gas turbine power plant. The integrated model for combined cycle gas turbine and CO2 capture plant was further used for performance study. Exhaust gas recirculation has been proposed to increase CO2 concentration in flue gas and reduce the flue gas flow rate. Its effect on combined cycle gas turbine power plant performance and capture plant sizing has been investigated. The analysis indicated that exhaust gas recirculation can reduce penalty on thermal efficiency without any major modification to the original power plant.
WangMLawalAStephensonP. Post-combustion CO2 capture with chemical absorption: a state-of-the-art review. Chem Eng Res Des2011; 89(9): 1609–1624.
2.
Okuzumi N and Mitchell R. Current status of MHI’s CO2 recovery technology and road map to commercialization for coal-fired power plant application. In: Proceedings of the international conference and exhibition: nitrogen and syngas, Bahrain, 28 February–3 March 2010, www.mhi.co.jp/en/products/pdf/articles_07.pdf (2010, accessed July 2012).
3.
HetlandJKvamsdalHMHaugenG. Integrating a full carbon capture scheme onto a 450 MWe NGCC electric power generation hub for offshore operations: presenting the Sevan GTW concept. Appl Energy2009; 86: 2298–2307.
4.
KvamsdalHMHetlandJHaugenG. Maintaining a neutral water balance in a 450 MWe NGCC–CCS power system with post-combustion carbon dioxide capture aimed at offshore operation. Int J Greenhouse Gas Control2010; 4: 613–622.
5.
KarimiMHillestadMSvendsenHF. Natural gas combined cycle power plant integrated to capture plant. Energy & Fuels2012; 26(3): 1805–1813.
6.
LawalAWangMStephensonP. Demonstrating full-scale post-combustion CO2 capture for coal-fired power plants through dynamic modelling and simulation. Fuel2012; 101: 115–128. DOI: 10.1016/j.fuel.2010.10.056.
7.
KvamsdalHMJakobsenJPHoffKA. Dynamic modelling and simulation of a CO2 absorber column for post-combustion CO2 capture. Chem Eng Process: Process Intensification2009; 48(1): 135–144.
8.
LawalAWangMStephensonP. Dynamic modelling of CO2 absorption for post-combustion capture in coal-fired power plants. Fuel2009; 88(12): 2455–2462.
9.
LawalAWangMStephensonP. Dynamic modeling and simulation of CO2 chemical absorption process for coal-fired power plants. Comput Aided Chem Eng2009; 27: 1725–1730.
10.
LawalAWangMStephensonP. Dynamic modelling and analysis of post-combustion CO2 chemical absorption process for coal-fired power plants. Fuel2010; 89(10): 2791–2801.
11.
BiliyokCLawalAWangM. Dynamic modelling, validation and analysis of post-combustion chemical absorption CO2 capture plant. Int J Greenhouse Gas Control2012; 9: 428–445.
12.
KvamsdalHMRochelleGT. Effects of the temperature bulge in CO2 absorption from flue gas by aqueous monoethanolamine. Ind Eng Chem Res2008; 47(3): 867–875.
13.
ZhangYChenHChenC-C. Rate-based process modelling study of CO2 capture with aqueous monoethanolamine solution. Ind Eng Chem Res2009; 48: 9233–9246.
14.
LiHDitarantoMBerstadD. Technologies for increasing CO2 concentration in exhaust gas from natural gas-fired power production with post-combustion, amine-based CO2 capture. Energy2011; 36(2): 1124–1133.
15.
BollandOMathieuP. Comparison of two CO2 removal options in combined cycle power plants. Energy Convers Manage1998; 39: 1653–1663.
Herzog H, Meldon J and Hatton A. Advanced post-combustion CO2 capture. Cambridge, MA: Massachusetts Institute of Technology, web.mit.edu/mitei/docs/reports/herzog-meldon-hatton.pdf (2009, accessed July 2012).
18.
Ong’iroAOUgursalVITaweelAMA. Simulation of combined cycle power plants using the aspen plus shell. Heat Recovery Syst CHP1995; 15(2): 105–113.
19.
Jonsson M, Bolland O, Bcker D, et al. Gas turbine cooling models for evaluation of novel cycles. In: Proceedings of the ECOS, Trondheim, Norway, 20–22 June 2005.
20.
Dugas ER. Pilot plant study of carbon dioxide capture by aqueous monoethanolamine. M.S.E. Thesis, University of Texas, Austin, USA, 2006.
21.
PitzerKS. Thermodynamics of electrolytes. I. Theoretical basis and general equations. J Phys Chem1973; 77: 268–277.
22.
ArcisHRodierLKarineB-B. Modeling of (vapor + liquid) equilibrium and enthalpy of solution of carbon dioxide (CO2) in aqueous ethyldiethanolamine (MDEA) solutions. J Chem Thermodyn2009; 41: 783–789.
23.
FairJRBravoJL. Prediction of mass transfer efficiencies and pressure drop for structured tower packings in vapor/liquid service. Inst Chem Eng Symp Ser A1985; 104: 183–200.
24.
BravoJLRochaJAFairJR. A comprehensive model for the performance of columns containing structured packings. Inst Chem Eng Symp Ser A1992; 129: 439–457.
25.
TaylorRKrishnaR. Multicomponent mass transfer, New York: John Wiley, 1993.
26.
AboudheirATontiwachwuthikulPChakmaA. Kinetics of the reactive absorption of carbon dioxide in high CO2-loaded, concentrated aqueuous monoethanolamine solutions. Chem Eng Sci2003; 58: 5195–5210.
27.
Aspentech. Rate-based model of the CO2 capture process by MEA using Aspen Plus, support.aspentech.com (2011, accessed July 2012).
Ramezan M and Skone TJ. Carbon dioxide capture from existing coal-fired power plants. Report no. DOE/NETL-401/110907, 2007. Morgantown, WV: National Energy Technology Laboratory (NETL).
30.
KangCABrandtARDurlofskyLJ. Optimal operation of an integrated energy system including fossil fuel power generation, CO2 capture and wind. Energy2011; 36(12): 6806–6820. ISSN 0360-5442, DOI: 10.1016/j.energy.2011.10.015.
31.
JonshagenKSipöczNGenrupM. A novel approach of retrofitting a combined cycle with post combustion CO2 Capture. J Eng Gas Turbines Power2011; 133(011703): 1−7–1−7.
32.
Sipöcz N, Jonshagen K, Assadi A, et al. Novel high-performing single pressure combined cycle with CO2 capture. In: Proceedings of the ASME turbo expo, Glasgow, UK, 14–18 June 2010, paper no. GT2010-23259, pp.803–811. New York: ASME.
33.
Jonshagen K, Sipöcz N and Genrup M. (2010), Optimal combined cycle for CO2 capture with EGR. In: Proceedings of the ASME turbo expo, Glasgow, UK, 14–18 June 2010, paper no. GT2010–23420, pp.867–875. New York: ASME.
34.
Jonshagen K, Eriksson P and Genrup M. Low-calorific fuel mix in a large size combined cycle plant. In: Proceedings of the ASME turbo expo, Orlando, FL, 8–12 June 2009, paper no. GT 2009-59329, pp.367–376. New York: ASME.
35.
Ulfsnes R, Karlsen G, Jordal K, et al. Investigation of physical properties of CO2/H2O-mixtures for use in semi-closed O2/CO2 gas turbine cycle with CO2-capture. In: Proceedings of the ECOS, Copenhagen, Denmark, 30 June–2 July 2003.
36.
LoudRLSlaterpryceAA. Gas turbine inlet air treatment, GER-3419A, GE Power Generation, 1991.
37.
EvuletATElKadyAMBrandaAR. On the performance and operability of GE’s dry low NOx combustors utilizing exhaust gas recirculation for post-combustion carbon capture. Energy Procedia2009; 1: 3809–3816.
38.
Elkady AM, Evulet A, Brand A, et al. Application of exhaust gas recirculation in a DLN F-class combustion system for postcombustion carbon capture. ASME GT2008-51152, 2008. New York: ASME.
