Low Btu Coal Gas Combustion in High Temperature Turbines

Vogt, Roland

doi:10.1115/80-gt-170

Cited by 4 publications

(1 citation statement)

References 5 publications

(7 reference statements)

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“…There is a significant body of literature describing development efforts for syngas combustors, and such combustors have been used in gas turbines dating back into the 1960s (Becker and Schetter, 1993). Vogt (1980) described many of the tradeoffs associated with switching from conventional fuels to syngas in turbines that, at the time, were characterized as high temperature (1427 C or 2600 F). Depending on the heating value of the fuel, Vogt emphasizes that both the volume and mass flow of syngas is a significant portion of the total combustor throughput, so that the temperature of the fuel becomes an important consideration in achieving the desired firing temperature.…”

Section: System Issues With Syngas Production 1027mentioning

confidence: 99%

System Issues and Tradeoffs Associated with Syngas Production and Combustion

Casleton

Breault

Richards

2008

Combustion Science and Technology

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The purpose of this article is to provide an overview of the basic technology of coal gasification for the production of syngas and the utilization of that syngas in power generation. The common gasifier types, fixed=moving bed, fluidized bed, entrained flow, and transport, are described, and accompanying typical product syngas compositions are shown for different coal ranks. Substantial variation in product gas composition is observed with changes in gasifier and coal feed type. Fuel contaminants such as sulfur, nitrogen, ash, as well as heavy metals such as mercury, arsenic, and selenium, can be removed to protect the environment and downstream processes. A variety of methods for syngas utilization for power production are discussed, including both present (gas turbine and internal combustion engines) and future technologies, including oxy-fuel, chemical looping, fuel cells, and hybrids. Goals to improve system efficiencies, further reduce NO x emissions, and provide options for CO 2 sequestration require advancements in many aspects of IGCC plants, including the combustion system. Areas for improvements in combustion technology that could minimize these tradeoffs between cost, complexity, and performance are discussed.

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Section: System Issues With Syngas Production 1027mentioning

confidence: 99%

System Issues and Tradeoffs Associated with Syngas Production and Combustion

Casleton

Breault

Richards

2008

Combustion Science and Technology

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Testing of a Hydrogen Diffusion Flame Array Injector at Gas Turbine Conditions

Weiland

Sidwell

Strakey

2013

Combustion Science and Technology

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NO x Reduction by Air-Side Versus Fuel-Side Dilution in Hydrogen Diffusion Flame Combustors

Weiland

Strakey

2010

Journal of Engineering for Gas Turbines and Power

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Lean-direct-injection (LDI) combustion is being considered at the National Energy Technology Laboratory as a means to attain low NOx emissions in a high-hydrogen gas turbine combustor. Integrated gasification combined cycle (IGCC) plant designs can create a high-hydrogen fuel using a water-gas shift reactor and subsequent CO2 separation. The IGCC’s air separation unit produces a volume of N2 roughly equivalent to the volume of H2 in the gasifier product stream, which can be used to help reduce peak flame temperatures and NOx in the diffusion flame combustor. Placement of this diluent in either the air or fuel streams is a matter of practical importance, and it has not been studied to date for LDI combustion. The current work discusses how diluent placement affects diffusion flame temperatures, residence times, and stability limits, and their resulting effects on NOx emissions. From a peak flame temperature perspective, greater NOx reduction should be attainable with fuel dilution rather than air or independent dilution in any diffusion flame combustor with excess combustion air, due to the complete utilization of the diluent as a heat sink at the flame front, although the importance of this mechanism is shown to diminish as flow conditions approach stoichiometric proportions. For simple LDI combustor designs, residence time scaling relationships yield a lower NOx production potential for fuel-side dilution due to its smaller flame size, whereas air dilution yields a larger air entrainment requirement and a subsequently larger flame, with longer residence times and higher thermal NOx generation. For more complex staged-air LDI combustor designs, the dilution of the primary combustion air at fuel-rich conditions can result in the full utilization of the diluent for reducing the peak flame temperature, while also controlling flame volume and residence time for NOx reduction purposes. However, differential diffusion of hydrogen out of a diluted hydrogen/nitrogen fuel jet can create regions of higher hydrogen content in the immediate vicinity of the fuel injection point than can be attained with the dilution of the air stream, leading to increased flame stability. By this mechanism, fuel-side dilution extends the operating envelope to areas with higher velocities in the experimental configurations tested, where faster mixing rates further reduce flame residence times and NOx emissions. Strategies for accurate computational modeling of LDI combustors’ stability characteristics are also discussed.

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Low Btu Coal Gas Combustion in High Temperature Turbines

Cited by 4 publications

References 5 publications

System Issues and Tradeoffs Associated with Syngas Production and Combustion

System Issues and Tradeoffs Associated with Syngas Production and Combustion

Testing of a Hydrogen Diffusion Flame Array Injector at Gas Turbine Conditions

NO x Reduction by Air-Side Versus Fuel-Side Dilution in Hydrogen Diffusion Flame Combustors

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