This paper addresses the possibility to burn hydrogen in a large size, heavy-duty gas turbine designed to run on natural gas as a possible short-term measure to reduce greenhouse emissions of the power industry. The process used to produce hydrogen is not discussed here: we mainly focus on the behavior of the gas turbine by analyzing the main operational aspects related to switching from natural gas to hydrogen. We will consider the effects of variations of volume flow rate and of thermophysical properties on the matching between turbine and compressor and on the blade cooling of the hot rows of the gas turbine. In the analysis we will take into account that those effects are largely emphasized by the abundant dilution of the fuel by inert gases (steam or nitrogen), necessary to control the $NOx$ emissions. Three strategies will be considered to adapt the original machine, designed to run on natural gas, to operate properly with diluted hydrogen: variable guide vane (VGV) operations, increased pressure ratio, re-engineered machine. The performance analysis, carried out by a calculation method including a detailed model of the cooled gas turbine expansion, shows that moderate efficiency decays can be predicted with elevated dilution rates (nitrogen is preferable to steam under this point of view). The combined cycle power output substantially increases if not controlled by VGV operations. It represents an opportunity if some moderate re-design is accepted (turbine blade height modifications or high-pressure compressor stages addition).

1.
Kreutz, T. G. et al., 2002, “Production of Hydrogen and Electricity From Coal With CO2 Capture,” Proc. of the Sixth International Conference on “Greenhouse Gas Control Technologies”, Kyoto, Japan.
2.
Lozza, G., and Chiesa, P., 2002, “CO2 Sequestration Techniques for IGCC and Natural Gas Power Plants: A Comparative Estimation of Their Thermodynamic and Economic Performance,” Proc. of the Int’l Conference on Clean Coal Technologies (CCT2002), Chia Laguna, Italy.
3.
Drell, I. L., and Belles, F. E., 1957, “Survey of Hydrogen Combustion Properties,” NACA Report 1383, Research Memorandum E57D24.
4.
Huth, H., Heilos, A., Gaio, G., and Karg, J., “Operation Experiences of Siemens IGCC Gas Turbines Using Gasification Products From Coal and Refinery Residues,” ASME paper 2000-GT-0026.
5.
Todd, D. M., and Battista, R. A., 2000, “Demonstrated Applicability of Hydrogen Fuel for Gas Turbines,” Proc. of the IchemE Gasification 4 Conference, Noordwijk, The Netherlands.
6.
Major, B., and Powers, B., 1999, “Cost Analysis of NOx Control Alternatives for Stationary Gas Turbines,” Contract DE-Fc02-97CHIO877.
7.
Lozza
,
G.
, and
Chiesa
,
P.
,
2002
, “
Natural Gas Decarbonization to Reduce CO2 Emission From Combined Cycles. Part A: Partial Oxidation–Part B: Steam-Methane Reforming
,”
ASME J. Eng. Gas Turbines Power
,
124
(
1
), pp.
82
95
.
8.
Andersen, T., Kvamsdal, H. M., and Bolland, O., 2000, “Gas Turbine CC With CO2 Capture Using Auto-Thermal Reforming of Natural Gas,” ASME paper 2000-GT-0162.
9.
Louis, J. F., 1977, “Systematic Studies of Heat Transfer and Film Cooling Effectiveness,” in AGARD CP-229, Neuilly sur Seine, France.
10.
Chiesa, P., and Macchi, E., 2002, “A Thermodynamic Analysis of Different Options to Break 60% Electric Efficiency in Combined Cycle Power Plants,” ASME paper GT-2002-30663.
11.
Siemens Power Generation website: www.pg.siemens.com
12.
Heilos, A., Huth, M., Bonzani, F., and Pollarollo, G., 1998, “Combustion of Refinery Residual Gas With a Siemens V94.2K Burner,” Power Gen Europe, Milan, Italy.
13.
Huth, M., Vortmeyer, N., Schetter, B., and Karg, J., 1997, “Gas Turbine Experience and Design for Syngas Operation,” Gasification Technology in Practice, Institution of Chemical Engineers, Milan, Italy.
14.
Macchi
,
E.
,
Consonni
,
S.
,
Lozza
,
G.
, and
Chiesa
,
P.
,
1995
, “
An Assessment of the Thermodynamic Performance of Mixed Gas-Steam Cycles. Part A: Intercooled and Steam-Injected Cycles–Part B: Water-Injected and HAT Cycles
,”
ASME J. Eng. Gas Turbines Power
,
117
(
3
), pp.
489
498
.