Co-firing of natural gas and Biomass gas in biomass integrated gasification/combined cycle systems

Rodrigues, Moacyr Tadeu Vicente; Faaij, André

doi:10.1016/s0360-5442(03)00087-2

Cited by 79 publications

(32 citation statements)

References 7 publications

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“…A trace amount of natural gas (stream 22) was required for achieving a stable operating region and to refrain from modification of the gas turbine combustor [40]. The resulting Wobbe Index of the gas turbine (measure of interchangeability of fuel gases and for comparing the combustion energy among fuel gases with different compositions) was validated against industrial study by Shah et al [41], in order to ensure that it was within ±10% of the stable combustion region.…”

Section: Process Simulation and Sensitivity Studiesmentioning

confidence: 99%

“…Air was supplied to the gas turbine combustor (GTCOMB), after compression to 14 bar via AIRCOMP. GTCOMB, operating at 1200°C and 14 bar, did not require de-rating (reduction in burning temperature and compressor power ratio to allow a stable combustion), because the LHV of the gas feed into the combustor was found to be greater than 6 MJ/m 3 [38,40]. The exit temperature and pressure of the exhaust gas from the GASTURB are approximately 740°C and 2 bar, respectively.…”

Section: Process Simulation and Sensitivity Studiesmentioning

confidence: 99%

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Process integration and economic analysis of bio-oil platform for the production of methanol and combined heat and power

Sadhukhan

2011

Biomass and Bioenergy

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Section: Process Simulation and Sensitivity Studiesmentioning

confidence: 99%

Section: Process Simulation and Sensitivity Studiesmentioning

confidence: 99%

Process integration and economic analysis of bio-oil platform for the production of methanol and combined heat and power

Sadhukhan

2011

Biomass and Bioenergy

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“…Feed costs for short rotation forestry wood and conventional forestry wood have been reported by Aberdeen University [39] and also by Kaltschmitt [40] for various European countries.…”

Section: Operating Costsmentioning

confidence: 99%

Heat Integration Strategy for Economic Production of Combined Heat and Power from Biomass Waste

Sadhukhan¹,

Ng²,

Shah³

et al. 2009

Energy Fuels

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The objective of this work was to design heat integrated, cost-effective and cleaner combined heat and power (CHP) generation plant from low cost 4 th generation biomass waste feedstocks. The novelty lies in the development of systematic site-wide heat recovery and integration strategies amongst biomass integrated gasification combined cycle processes so as to offset the low heating value of the biomass waste feedstocks. For the biomass waste based CHP plant technical and economic analysis, the process was based on low cost agricultural wastes like straws as the biomass feedstock and further established for a more predominant biomass feedstock, wood. The process was modeled using the ASPEN simulator. Three conceptual flowsheets were proposed, based on the integration of the flue gas from the char combustor, which was separately carried out from the steam gasification of biomass volatalised gases and tars, and carbon dioxide removal strategies. The cost of energy production included detailed levelised discounted cash flow analysis and was found to be strongly influenced by the cost of feedstock. Based on a combined energy generation of ~340-370 MW using straw wastes priced at 35.3 £/t or 40 Euro/t, with 8.5% and 8.61% by mass moisture and ash contents respectively, the cost of electricity generation was 4.59 p/kWh and 5.14 p/kWh for the cases without and with carbon capture respectively, with a 10% internal rate of return and 25 years of plant life. Based on the carbon capture value assigned by Carbon Credits Trading scheme, a much constrained viable price of 22 £/t of such agricultural waste feedstocks for CHP generation was obtained, while up to 60 £/t of waste feedstocks can be economically viable under the UK Climate Change Levy, respectively.

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“…Firing low caloric value (LCV) fuels in a natural gas designed gas turbine requires modification of the gas turbine. According to Rodrigues et al (2003a) co-firing gasified biofuel with natural gas prevents the need for significant combustion chamber modifications. The nature of such modifications depends on the LHV of the fuel and the type of turbine.…”

Section: Economic Performance Indicatormentioning

confidence: 99%

The role of policy instruments for promoting combined heat and power production with low CO2 emissions in district heating systems

Marbe¹,

Harvey²

2005

Int. J. Energy Res.

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SUMMARYPolicy instruments clearly influence the choice of production technologies and fuels in large energy systems, including district heating networks. Current Swedish policy instruments aim at promoting the use of biofuel in district heating systems, and at promoting electric power generation from renewable energy sources. However, there is increasing pressure to harmonize energy policy instruments within the EU. In addition, natural gas based combined cycle technology has emerged as the technology of choice in the power generation sector in the EU. This study aims at exploring the role of policy instruments for promoting the use of low CO 2 emissions fuels in high performance combined heat and power systems in the district heating sector. The paper presents the results of a case study for a Swedish district heating network where new large size natural gas combined cycle (NGCC) combined heat and power (CHP) is being built. Given the aim of current Swedish energy policy, it is assumed that it could be of interest in the future to integrate a biofuel gasifier to the CHP plant and co-fire the gasified biofuel in the gas turbine unit, thereby reducing usage of fossil fuel. The goals of the study are to evaluate which policy instruments promote construction of the planned NGCC CHP unit, the technical performance of an integrated biofuelled pressurized gasifier with or without dryer on plant site, and which combination of policy instruments promote integration of a biofuel gasifier to the planned CHP unit. The power plant simulation program GateCycle was used for plant performance evaluation. The results show that current Swedish energy policy instruments favour investing in the NGCC CHP unit. The corresponding cost of electricity (COE) from the NGCC CHP unit is estimated at 253 SEK MWh À1, which is lower than the reference power price of 284 SEK MWh À1. Investing in the NGCC CHP unit is also shown to be attractive if a CO 2 trading system is implemented. If the value of tradable emission permits (TEP) in such as system is 250 SEK tonne À1 , COE is 353 SEK MWh À1 compared to the reference power price of 384 SEK MWh À1. It is possible to integrate a pressurized biofuel gasifier to the NGCC CHP plant without any major re-design of the combined cycle provided that the maximum degree of co-firing is limited to 27-38% (energy basis) product gas, depending on the design of the gasifier system. There are many parameters that affect the economic performance of an integrated biofuel gasifier for product gas co-firing of a NGCC CHP plant. The premium value of the co-generated renewable electricity and the value of TEPs are very important parameters. Assuming a future CO 2 trading system with a TEP value of 250 SEK tonne À1 and a premium value of renewable electricity of 200 SEK MWh À1 COE from a CHP plant with an integrated biofuelled gasifier could be 336 SEK MWh À1, which is lower than

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Co-firing of natural gas and Biomass gas in biomass integrated gasification/combined cycle systems

Cited by 79 publications

References 7 publications

Process integration and economic analysis of bio-oil platform for the production of methanol and combined heat and power

Process integration and economic analysis of bio-oil platform for the production of methanol and combined heat and power

Heat Integration Strategy for Economic Production of Combined Heat and Power from Biomass Waste

The role of policy instruments for promoting combined heat and power production with low CO2 emissions in district heating systems

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